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Home My WebLink About100-268 ~ STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMIS~~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: OilL GasD Plugged D Abandone~~ Suspended D WAGD 1 b. Well Class: 20AAC 25.105 ~ 20AAC 25.110 Development 0 Exploratory D GINJD WINJD WDSPLD No. of Completions Other Service D Stratigraphic TestD 2. Operator Name: 5. Date Comp., Susp., or 12~iII Number: Ii Union Oil Company of California Aband.: 9/5/04 17-1 JOf) - ,;)."c¿š' 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 nla 50-133-20241-01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1959 FSL, 1987 FWL, Sec 8 TIN R9W nla SCU 33A-08 Top of Productive Horizon: nla 8. KB Elevation (ft): 15. Field/Pool(s): 17' Swanson River FieldlHemlock Total Depth: 2946 FSL, 1664 FWL, Sec 8 T7N R9W 9. Plug Back Depth(MD+ TVD): 10,889/10,670 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: X = 340,347 Y = 2,454,088 11,086/10,850 Swanson River Field TPI: nla 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: X = 340,726, Y = 2,453,212 nla A-028996 18. Directional Survey: Yes l.::.,No U 19. Water Depth, if Offshore: 20. Thickness of Permafrost: nla feet MSL nla 21. Logs Run: nla 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD I AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 18" Driven 10-3/4" 40.5 23' 58' 23' 58' 15" see schematic for detail / 7-5/8" 26.4# N-80. S-95 3,332' 3,332' 23' 3332' 9-7/8" 5-1/2" 20# N-80 9,631' 11,178' 9,631' 11,178' I I 23. Perforations open to Production (MD + TVD ofTop and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) see schematic for detail 2-7/8" 10,764' 10,739' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) T AMOUNT AND KIND OF/MATERIAL USED see schematic for full detail 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): nla n/a Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: IGaS-Oil Ratio: Test Period .... Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate ..... 27. CORE DATA Brief description 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". nla ~_JlA (,fv Form 10-407 Revised 12/2003 CONTINUED ON REVERSE dT'\ r)af)~ ,~ . ..itA\< ,,- ,\A c\V'\ ~ NAME GEOLOGIC MARKERS ~ MD 29. ORMATION TESTS 28 TVD Include and briefly sumr ! test results. List intervals tested, and attach detailed supporting data é:o~ 11ecessary. If no tests were conducted, state "None". none RE:C£/\/f::. . OCT 1 ~ 2004 Alaska Oil & Gas Anch(¡t,..,,~ V'-" "",!or; '. , "JCI 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Tyler 263-7649 Title: Drilling Manager Signature: -z..:.. c- Phone: 907-276-7600 Date: 10/18/2004 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 ~ UNOCAL@> ~oldotna Creek Unit Nell No. 33A-8 Actual Completion 09/04/04 CASING AND TUBING DETAIL 10 To Btm Hole Cmt Cmt To 23' 58' Driven 10.050 23' 3,332' 15" 2218 It Lead 8urf + 150sx G 33.7 BTC 6.765 23' 85' 26.4 N-80 BTC 6.969 85' 3,940' 33.7 BTC x 8rd 6.765 3940' 3,958' 323sx w/2.4% gel 5,926' 7-5/8" 29.7 8rd 6.875 3,958' 6,905' 9-Va" CBL 33.7 8-95 8rd 6.765 6,905' 7,332' DV Collar 7,332' 7,334' 33.7 8-95 8rd 6.765 7,334' 9,631' Lead 320sx G w/2.4% gel 8,736' + 100sxofG CBL 20 N-80 4.778 9,631' 11,178' 74 bbls of class "G" 10,792' CBL PERFORATION HISTORY Interval Accum Zooe Top Btrn Ant (ft) spf Con . ,Ients 4æ 490' 4' 4' TLtJing po..nch, 47 ~s œrert purped 3,424' 3,430' 6 2.5 TLtJing pulCh, 50 ~s œrert purped H-2 10,836' 10,856' 2fJ 4 H-2 10,001' 10,871' 1(J 8 H4 10,914' 10,930' 16 4 19J1åed H-5 10,938' 10,946' B 4 19J1åed H-5 10,002' 10,970 B 4 19J1åed Size 18" 10-3/4" 16 17 H-2 SWS Posi Set Plug @ 10,889' H-4 H-5 H-5 Wt Grade Conn 40.5 K-55 JEWELRY DETAIL NO. Depth ID aD Item 17' Shaffer, 3-1/2", 5M, Single Tubing Hanger CIW Type 'H' BPVP 510' 7-5/8" Cavins Bridge Plug 3,459 7-5/8" Cavins Bridge Plug 3 5.540' 2.35 4.75 McMurry Macco. 2-7/8" SMO-1 GLM, BK-2 wi Dummy 4 6,729' 2.35 4.75 McMurry Macco, 2-7/8" SMO-1 GLM, BK-2 wi Dummy 5 7,757' 2.35 4.75 McMurry Macco, 2-7/8" SMO-1 GLM, BK-2 w/ Dummy 6 8,593' 2.35 4.75 McMurry Macco, 2-7/8" SMO-1 GLM, BK-2 w/ Dummy 7 9,180' 2.35 4.75 McMurry Macco, 2-7/8" SMO-1 GLM, BK-2 wi Dummy 8 9,727' 2.35 4.5 McMurry Macco, 2-7/8" SMOR-1 GLM S.C. BK-2 Empty 9 10,242' 2.35 4.5 McMurry Macco, 2-7/8" SMOR-1 GLM S.C. BK-2 Empty 10 10,725' 2.35 4.5 McMurry Macco, 2-7/8" SMOR-1 GLM S.C. BK-2 Empty 11 10,763' 2.38 4 Anchor Seal Assembly, E-22, 2.77' The following were set on E"Llne 10/31/90. 12 10,739' 3 4.44 Packer, 2-7/8 x 7-5/8" Baker Mod. 'F-1' 13 10,741' Millou! Extension, 5.63' Long 14 10,747' 1 Jt. 2-7/8" 6.5#, N-80, EVE 8 rd 15 10,778' 2.3 Otis 'XN' Nipple, 2-7/8" EVE 8rd, 2.313 w/2.25" N.G. w/ Plug in place. 16 10,779' 1 Pup Jt., 2-7/8", 6.5#, N-80. EVE 8rd 17 10,783' WLREG PBTD = 10,889' TD = 11,086' MAX HOLE ANGLE = 27 deg. GPS Reading 60.42 degrees 82 N, 150.53 degrees 62W 137', 33A-8Final093004 REVISED: 8/20/98 - ded >ll'IformatioPi >Well >Directional Surveys >Ful~ey ~ Select Well: SCU 33A-O8 -~~~ Report Name Well Date Created Position Log SCU 33A-08 10/18/2004 Well Name CURRENT STATUS API KB Surf X Surf Y (ft) (ft) (ft) r-Interpolatel SCU 33A-08 OIL 501332024101 154 340,347 2,454,088 MD TVD SSTVD X Off Y Off X Y Inc Azimuth (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg) (deg) 0 0 154 0 0 340,347 2,454,088 0.0 0 100 99 55 0 0 340,347 2,454,088 0.3 270 200 199 -45 0 0 340,347 2,454,088 0.3 258 300 299 -145 -1 0 340,346 2,454,088 0.3 262 400 399 -245 -1 0 340,346 2,454,088 0.2 282 500 499 -345 -2 0 340,345 2,454,088 0.7 318 600 599 -445 -2 1 340,345 2,454,089 0.3 343 700 699 -545 -2 1 340,345 2,454,089 0.4 41 800 799 -645 -1 2 340,346 2,454,090 0.7 37 900 899 -745 -1 3 340,346 2,454,091 0.6 17 1,000 999 -845 0 4 340,347 2,454,092 0.8 27 1,100 1,099 -945 0 5 340,347 2,454,093 0.9 356 1,200 1,199 -1,045 0 7 340,347 2,454,095 0.7 16 1,300 1,299 -1,145 0 8 340,347 2,454,096 0.9 3 1,400 1,399 -1,245 0 10 340,347 2,454,098 0.7 355 1,500 1,499 -1,345 0 11 340,347 2,454,099 0.8 12 1,600 1,599 -1,445 0 12 340,347 2,454,100 0.6 334 1,700 1,699 -1,545 0 13 340,347 2,454,101 0.4 319 1,800 1,799 -1,645 -1 13 340,346 2,454,101 0.6 274 1,900 1,899 -1,745 -2 14 340,345 2,454,102 0.6 293 2,000 1,999 -1,845 -3 14 340,344 2,454,102 0.3 286 2,100 2,099 -1,945 -3 14 340,344 2,454,102 0.3 274 2,200 2,199 -2,045 -4 14 340,343 2,454,102 0.3 286 2,300 2,299 -2,145 -4 14 340,343 2,454,102 0.4 304 2,400 2,399 -2,245 -5 15 340,342 2,454,103 0.3 313 2,500 2,499 -2,345 -5 15 340,342 2,454,103 0.4 302 2,600 2,599 -2,445 -6 15 340,341 2,454,103 0.3 295 2,700 2,699 -2,545 -6 16 340,341 2,454,104 0.5 272 2,800 2,799 -2,645 -7 16 340,340 2,454,104 0.6 291 2,900 2,899 -2,745 -8 16 340,339 2,454,104 0.3 301 3,000 2,999 -2,845 -8 16 340,339 2,454,104 0.1 233 3,100 3,099 -2,945 -9 16 340,338 2,454,104 0.1 253 3,200 3,199 -3,045 -9 16 340,338 2,454,104 0.1 286 3,300 3,299 -3,145 -9 16 340,338 2,454,104 0.1 330 3,400 3,399 -3,245 -9 16 340,338 2,454,104 0.1 295 3,500 3,499 -3,345 -9 16 340,338 2,454,104 0.1 125 3,600 3,599 -3,445 -9 16 340,338 2,454,104 0.3 65 3,700 3,699 -3,545 -8 17 340,339 2,454,105 0.4 45 3,800 3,799 -3,645 -8 17 340,339 2,454,105 0.4 61 3,900 3,899 -3,745 -7 17 340,340 2,454,105 0.6 38 4,000 3,999 -3,845 -7 18 340,340 2,454,106 0.3 14 4,100 4,099 -3,945 -6 19 340,341 2,454,107 0.8 13 4,200 4,199 -4,045 -6 21 340,341 2,454,109 1.0 348 4,300 4,299 -4,145 -7 22 340,340 2,454,110 1.0 339 4,400 4,399 -4,245 -7 24 340,340 2,454,112 1.0 358 4,500 4,499 -4,345 -7 26 ~40 2,454,114 1.3 360 ~ 4,600 4,599 -4,445 -7 28 :hv,340 2,454,116 1.2 352 4,700 4,699 -4,545 -7 30 340,340 2,454,118 0.9 3 4,800 4,799 -4,645 -7 32 340,340 2,454,120 1.1 3 4,900 4,899 -4,745 -7 34 340,340 2,454,122 1.1 2 5,000 4,999 -4,845 -7 36 340,340 2,454,124 1.1 356 5,100 5,099 -4,945 -7 38 340,340 2,454,126 1.1 359 5,200 5,199 -5,045 -7 40 340,340 2,454,128 1.4 5 5,300 5,299 -5,145 -7 42 340,340 2,454,130 1.7 9 5,400 5,399 -5,245 -6 45 340,341 2,454,133 1.8 10 5,500 5,499 -5,345 -6 49 340,341 2,454,137 1.9 10 5,600 5,599 -5,445 -5 52 340,342 2,454,140 2.0 13 5,700 5,699 -5,545 -4 56 340,343 2,454,144 2.2 12 5,800 5,799 -5,645 -3 60 340,344 2,454,148 2.5 19 5,900 5,899 -5,745 -1 64 340,346 2,454,152 2.9 20 6,000 5,999 -5,845 0 69 340,347 2,454,157 3.4 17 6,100 6,098 -5,944 1 75 340,348 2,454,163 3.3 22 6,200 6,198 -6,044 4 80 340,351 2,454,168 2.9 22 6,300 6,298 -6,144 6 84 340,353 2,454,172 2.7 25 6,400 6,398 -6,244 8 89 340,355 2,454,177 2.8 23 6,500 6,498 -6,344 10 93 340,357 2,454,181 2.9 25 6,600 6,598 -6,444 12 98 340,359 2,454,186 3.1 25 6,700 6,698 -6,544 14 103 340,361 2,454,191 3.0 20 6,800 6,797 -6,643 16 108 340,363 2,454,196 3.1 22 6,900 6,897 -6,743 18 113 340,365 2,454,201 3.3 22 7,000 6,997 -6,843 20 118 340,367 2,454,206 3.2 23 7,100 7,097 -6,943 22 123 340,369 2,454,211 3.2 19 7,200 7,197 -7,043 24 128 340,371 2,454,216 3.2 22 7,300 7,297 -7,143 27 133 340,374 2,454,221 3.3 22 7,400 7,397 -7,243 29 139 340,376 2,454,227 3.3 20 7,500 7,496 -7,342 31 144 340,378 2,454,232 4.0 26 7,600 7,596 -7,442 36 151 340,383 2,454,239 5.6 39 7,700 7,695 -7,541 45 156 340,392 2,454,244 6.8 85 7,750 7,745 -7,591 51 156 340,398 2,454,244 7.6 93 7,800 7,795 -7,641 58 155 340,405 2,454,243 7.8 105 7,900 7,894 -7,740 70 148 340,417 2,454,236 8.0 137 7,950 7,943 -7,789 73 143 340,420 2,454,231 7.0 148 8,000 7,993 -7,839 76 137 340,423 2,454,225 6.4 160 8,100 8,092 -7,938 80 128 340,427 2,454,216 5.7 155 8,200 8,192 -8,038 86 119 340,433 2,454,207 7.2 132 8,300 8,291 -8,137 98 111 340,445 2,454,199 9.1 114 8,400 8,389 -8,235 113 102 340,460 2,454,190 10.4 122 8,450 8,438 -8,284 120 96 340,467 2,454,184 10.7 139 8,500 8,487 -8,333 125 88 340,472 2,454,176 11.0 156 8,550 8,536 -8,382 128 79 340,475 2,454,167 12.9 166 8,600 8,585 -8,431 130 67 340,477 2,454,155 14.6 169 8,650 8,633 -8,479 133 54 340,480 2,454,142 16.0 169 8,700 8,681 -8,527 135 40 340,482 2,454,128 16.8 171 8,800 8,776 -8,622 137 10 340,484 2,454,098 18.6 178 8,900 8,871 -8,717 136 -22 340,483 2,454,066 20.1 184 9,000 8,964 -8,810 132 -58 340,479 2,454,030 22.2 187 9,100 9,056 -8,902 125 -97 340,472 2,453,991 24.5 192 9,200 9,147 -8,993 119 -138 340,466 2,453,950 24.8 183 9,300 9,237 -9,083 120 -181 340,467 2,453,907 25.6 175 9,400 9,327 -9,173 123 -224 340,470 2,453,864 25.6 175 9,500 9,418 -9,264 125 -267 340,472 2,453,821 25.5 177 9,600 9,508 -9,354 127 -309 ~74 2,453,779 24.7 176 ~ 9,700 9,599 -9,445 129 -351 3"Tv,476 2,453,737 24.8 177 9,800 9,690 -9,536 130 -392 340,477 2,453,696 24.3 179 9,900 9,781 -9,627 130 -435 340,477 2,453,653 25.7 180 9,977 9,850 -9,696 131 -469 340,478 2,453,619 26.8 173 10,056 9,920 -9,766 140 -503 340,487 2,453,585 27.1 159 10,087 9,948 -9,794 145 -516 340,492 2,453,572 27.3 154 10,125 9,981 -9,827 153 -532 340,500 2,453,556 27.3 152 10,251 10,094 -9,940 180 -582 340,527 2,453,506 26.2 149 10,345 10,178 -10,024 201 -617 340,548 2,453,471 26.1 149 10,409 10,236 -10,082 216 -642 340,563 2,453,446 26.1 149 10,535 10,349 -10,195 243 -689 340,590 2,453,399 25.5 148 10,630 10,435 -10,281 265 -723 340,612 2,453,365 25.0 147 10,713 10,510 -10,356 284 -753 340,631 2,453,335 25.0 145 11,007 10,777 -10,623 359 -852 340,706 2,453,236 25.0 139 11,120 10,881 -10,727 388 -886 340,735 2,453,202 22.0 139 11,178 10,934 -10,780 402 -903 340,749 2,453,185 21.5 139 11,228 10,981 -10,827 414 -917 340,761 2,453,171 21.5 139 r---. ~ 8/18/104 Rest crew. SIMOP's with production and construction. PTSM with Peak crew. Back fill hole on pad and grade pad around cellar. Lay felt and pit liner. Pull grating from well head. Put Tyler work platform together. Checked well head tree valves out. . Schlumberger crew Scheduled for this morning to perform MIT on 7 5/8" casing and leak off or injection rates on 10 3/4" shoe. 8/19/104 Crew rest. SIMOP's. PTSM with peak crew. Albin Hale out looking over projects. Got word from agencies on waiving witness on MIT and injection test on surface csg shoe. Safety meeting and rig up iron on 10 3/4" X 7 5/8" annulus (surface casing) to Schlumberger pump. Went over pump procedure with Schlumberger and Peak Vac truck operator. PJSM. Hydro Test lines to 3000# all OK. Put new gauges on surface csg and tubing. Lubricate 31 Bbls of 8.36# drill water into 10 3/4" surface casing. Shut down at 150# and bleed gas. Pump 4 Bbls more at 0.5 BPM rate and reach 1500# max target. Shut down. Call town about squeeze pressures and get new max pressure allowance of 2000#. While conversing with town the shoe broke down and pressure starting dropping. Pumped 5 Bbls at 0.5 BPM rate at average of 1100#. Pumped 5 Bbls at 1.0 BPM rate at average of 1090#. Pumped 5 Bbls at 1.5 BPM rate with a average pressure of 1100#. Pumped 5 Bbls of 8.36# drill water at 2.0 BPM rate with average squeeze pressure of 1110# on 10 3/4" casing shoe. Shut down pump with Initial Shut In Pressure of 1035#. Pressure dropped to 950# in first five minutes. Bleed down surface piping and rigged up on 7 5/8" X 27/8" tubing annulus (production casing) Put gauge in surface casing to monitor. Pressure test surface lines to 3000# all OK. Pump 1.7 Bbls into production casing and get 1700# on tubing and production casing. Shut down and bleed tubing and production casing of gas. All water returns. Pump 1.1 Bbls and get 2014# on 2 7/8" Tbg bad 7 5/8" production casing. Shut down pump and valve off for 1/2 hour MIT. . During 1/2 hour test pressure dropped from 2010# to 1959# (2.5 percent pressure drop over 1/2 hour). Bleed down and rig down Schlumberger. Shut down for night. 8/22/104 Move equipment from SRU 34-28 and spot on location. Hold tailgate safety meeting and discuss job. Rig up on well. RIH with 2.3" gauge ring and set down in master valve. Unable to get down. POOH. Make wire brush and run in hole to tubing hanger. Unable to get deeper. POOH. Review files and talk with Steve Tyler to see if anything was put in well head. Make up wire hook and hand line fish around hanger and pulled a 3" metal ring from top of hanger. Fish around a again pull another metal ring from on top of hanger. Pull third piece doing same which ended up being a oil seal rubber with backup spring. After looking at all three pieces it was identified as a 3" mechanical oil seal? (See pictures sent with report. Pick up 2.3" Gauge Ring and RIH to 5471' RKB and set down. No SCU 33A-08 Plug and Abandon Summary, last revised 10/18/2004 ~ ~ abnormalities other than the fish in tree. POOH. Rig down do paper work and send Pollard home. 8/25//04 Sim-Ops mtg. with Plant personnel. Preliminary work for 33A-08. Lined up EL to perform cut. Moved in Alaska Pipe Recovery spotted EL equipment, rigged up on well picked up 2.25" JRC Jet cutter went in hole to 4,032' No.2 GLM tied in with mandrel picked up to 3,529' RKB made cut, indication tubing cut. Rigged down and secured well. 8/27//04 No Activity. Sim-Ops meeting with Plant personnel. Moved in offloaded BOPE, Koomey Sytem and Handling tools. Tubing pressure zero, casing zero. Vetco Grey installed two way check valve. Removed wellhead. Installed 9" 5-M X 11" 5- M single studded spool adaptor, nippled up 11' 5-M BOPE Stack. Picked up Tyler sub-structure, spotted over well, layed liner for 500-bbls. Frac tank spotted choke manifold and frac tank. Made up hard lines from BOP's to Choke manifold. Set beaver slide, and cat walk. Picked up and placed grading and hand rails for structure. Pressure Tested BOPE to Unocal specification, 250-psi Low, 3,500-psi high. Picked up 2-718" lift joint screwed into tubing hanger, backed out tie-down pins. Picked up to 19,500-K hanger cleared bowl inspected seals on hanger OK landed same. Closed pipe rams manually, installed TIW and secured well for the night. 8/28/104 No Activity. Opened well a-psi on tubing and casing. Opened pipe rams overide. Picked up Weatherford tubing tongs, spotted power pack. Chained Tyler structure down to Stack. Latched tubing picked up with 20-K Ibs. broke out hanger Pulled 71-joints of 2-718" 6.5# BTS tubing and laid down same. Crane shutdown wouldn't start, pulled starter worked on same started back up. Finished laying down 2-7/8" 6.5# BTS Tubing (110-joints 2-7/8", 1-cut piece, 3-pup joints, 1-GLM, & 3-1/2" 8RD X 2-7/8" BTS Hanger). Laid down handling tools, rigged up Pollard S/L Picked up 6.73" Gauge ring, junk basket ran in hole to 3,533' SLM, (3,540 RKB).POOH. Picked up 7-5/8" Cavin Bridge plug wlrunning tool, ran in hole to 3,452' SLM (3,459' RKB) picked up set plug, pulled out of hole all indication plug set successful. Secured well for the night. 8/29/104 No Activity. Sim-Ops meeting with Plant personnel. Informed BLM and left message for AOGCC we was pumping cement. Moved in rigged up APRS picked up 2.125" Ceramic Pod 180-degree phase w/16 shots perforating gun. Ran in hole place shots across 3,424' to 3,430' RKB. Moved in rigged up Schlumberger SCU 33A-08 Plug and Abandon Summary, last revised 10/18/2004 ~ .~ cementers to 2-7/8" Landing joint, pressured tested lines to SOO-psi. Pressure up on 7 -S/8" casing to SOO-psi fired guns pressure dropped immediately to 1 SO-psi Pulled up to 90' RKB bled off pressure no flow. RID APRS. Broke circulation down 7-S/8" casing taking returns up 10-3/4" surface casing as followed: (1-bpm, wI 220-psi, 2-bpm, w/311-psi, 3-bpm, w/38S-psi, 4-bpm w/460-psi, S-bæ:O- psi shutdown after pumping 26-bbls. Getting returns. Mixed & pumpe 0- s. Of 1S.6-PPG G-Neat cement displaced with 160-bbls. Fresh water hi pressure 1,340-psi, ISIP 960-psi closed TIW valve. Secured well for the Night. Called BLM for witness of TOC 8/301104. ---- 8/30/104 No Activity. Sim-Ops Meeting with Plant personnel. Held JSA Moved in Slickline picked up 6.73" gauge ring went in hole and tagged @ 3,191' SLM (3,198' RKB). POOH Witnessed by AOGCC. Picked up 7-S/8" Cavin bridge plug, stood back, rigged up test line to 10-3/4" surface casing pressure up to 480-psi, rigged up to 7-S/8" production casing pressure up to 1 ,SOO-psi after 30-minutes Surface Csg. 460-psi, Casing 1,480-psi. Good test witnessed by AOGCC. Rigged up to 10-3/4" pressured up to 1 ,SOO-psi 7 -S/8" 230-psi 10-3/4" appeared to be leaking tested several times same results, eventually found pressure leaking back through pump changed out valve and re-pressured with no problems. 7-S/8" 23S-psi, 10- 3/4" 1,4S0-psi 30-minute test Good test. Finished rigging up SL ran in hole to S03' SLM (S10' RKB) set bridge plug had 2S0-lbs. extra pull, pulled free POOH. Rigged up EL picked up 2.12S" ceramic perforating gun with 16-shots (3/8" ~ holes). Ran in hole and perforated @ 486'-490' RKB. POOH. Rigged up Schlumberger cementer Held JSA broke circulation down 7 -S/8" with 2-bpm rate 10-psi. Shutdown afte~2- . Pumped. Mixed and pumped 1S.8-PPG cement got back 1S.S-PPG afte 4'Z bbls. Pumped. Rigged down Schlumberger, Slickline and EL. Cleaned up c with Supervac. Lined up trucks to start de-mobe. Loaded out Weatherford casing tongs for Rig. -- 8/31/104 No Activity. Sim-Ops meeting with Plant Personnel. Nippled down BOPE stack, (Hydrill, Pipe Rams, Blinds and Valves) loaded on WBI truck sent to Weatherford. Broke down and loaded out Swaco Koomey system sent to Anchorage. Loaded out tubulars (3-1/2" EUE 8-Rd x 2-718" 6.4# Buttress Hanger, 110-joints 2-7/8 6.4# Tubing, 3-2-7/8" Pup joints, 1-GLM, and cut piece onto WBI trailor. Ensure all protectors on joints ends. Gauge TOC in 7 -S/8" Casing (2S' from casing flange) gathered all Unocal cement equipment ordered out cement none to be found. Lined up BLM, AOGCC, and Unocal Remediation Department to witness this AM. Moved frac tank, cleaned up location around well cellar, preparing to top 7-S/8" casing with cement.Finished loaded trailor with wellhead and casing spool. 9/1/104 SCU 33A-08 Plug and Abandon Summary, last revised 10118/2004 ~ /"'"' , No Activity. Sim-Ops meeting with Plant personnel. BLM Representative on site, ¿e. up 30' 1.5" PVC tripped in hole 25' tagged cement. Mixed and pumped - 1.2 bls. 15.5-PPG G Neat cement got cement returns up 7-5/8" shutdown to let ment heal. De-mobe cement equipment to SRU-41-33. 9/2/104 No Activity. Moved from SRU 41-33 WD. Layed liners down made two containments to hold dirt from around cellar. Steamed clean cellar culvert, dug up soil around culvert and removed culvert with track-hoe. Broke up cellar cement bottom with track-hoe and place in containment. Started slopping banks, preparing hole for personnel to safely cut cason. 9/3/104 No Activity. Sim-Ops meeting with Plant Personnel. Finished preparing well for abandonment. Separated debris from dirt from both containments, put debris in dumpster. Order out second dumpster No.1 heavy with concrete. Layed liner over No.1 & No 2 containments. Attempted to pull piling with Crane and Trackhoe pulled 38,OOO-lbs. didn't move, will need to cut off 3' below oringinal ground level. Plans are to cut the 4-piling after well is cut and capped. 9/4/104 No Activity. Moved in rigged up Casing cutter, Notified AOGCC & BLM. Made cut 18" conductor, 10-314",7-5/8" made cut, took pictures sent to Town. Welded / plate on top. Moved to SRU 41-33 WD. 9/5/104 No Activity. Dug out around columns made cuts on all four. Well cap 6.6'. Dug dirt out inside columns 1/2' put cement inside on all four columns. Started back filling hole with dirt from No.1 & 2 containments. See below details. Well was cut 6-1/2' Below Ground Level, Columns 8.1',8.4',8.0',7.8' below ground level. GPS Reading 60.42 degrees 82 N, 150.53 degrees 62W 137'. SCU 33A-08 Plug and Abandon Summary, last revised 10/18/2004 2004-0830 _P&A- seD _33A-08 _lg.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg,. 'Ke,ra q( ¡,JI¡ DATE: August 31,2004 P. I. Supervisor ( l '1V THRU: FROM: Lou Grimaldi, Petroleum Inspector SUBJECT: Plug and Abandonment SCU 33A-08 PTD #100-268 (304-109) Soldotna Creek Unit Swanson River Field Mondav. Auaust 30. 2004; I witnessed P & A procedures on Unocal's well SCU 33A-08 in the Swanson River Field. I arrived to witness the cement plug tag inside the 7" casing by Wireline at 3198' (RKB ). The plug's in the 7"and 7" x 10 % annulus were pressured tested separately to 1500 psi checking for plug and string integrity. Both plugs passed their pressure test. A 7" Cavins cement retainer was set at 510'. The 7" casing was perforated at 486' thru 490" with 4/spf. 45 Barrel's of "neat" G cement was pumped down the 7" with returns taken from the 10 %, a 15.5 ppg cement sample was observed taken from the 10 %. I left location at this time. S<;ANNED OCT 0 9 2004 2004-0830 _P&A - SCU _33A-08 Jg.doc lof3 2004-0830 _P&A _seD - 33A-08 _lg.doc Saturday. September 4. 2004: I returned today to check the cutoff and marker for this well. The cut-off work had progressed more quickly than anticipated and I approved welding the cap on before I arrived. Dan Macdonald (Unocal) had taken some good pictures of the cut-off stub. I arrived to find the cap welded on and the stub to be approximately 6" below final grade. There were still 4 steel pilings driven in around the well, I advised Dan that these be cut off and capped if they could not be pulled easily. Attachments: SCU 33-08 marker plate.JPG SCU 33-08 pilings.JPG SCU 33-08 Cemented pilings.jpg NON-CONFIDENTIAL Cc; Tim Lawlor (BLM) SCANNED OCT 0 9 2004 2004-0830 _P &A - SCU - 33A-08 _lg.doc 2of3 2004-0830 _P&A - seu _33A-08 _lg.doc Soldotna Creek Unit 33A-08 (Unocal) Suñace Abandonment Inspection Photos from AOGCC Inspector Lou Grimaldi August 30-31 , 2004 seu 33A-08 Marker Plate Installed seu 33A-08 Pilings seu 33A-08 Piling eemented SCANNED OCT 0 9 2004 2004-0830 _P &A - SCU _33A-08 Jg.doc 30f3 jcPI. /119 UNOCALi> -Alaska Philip J. Krueger Drilling Manger Unocal Alaska Tel 907.263.7628 Fax 907.263.7884 Cell 907.250.2712 E-mail PKrueger@unocal.com August 23, 2004 Winton Aubert AOGCC 333 West th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Swanson River SCU 33A-08 P&A BOPE Configuration RECEIVED AUG 2.( 2004 Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Aubert: We are requesting a variance of 20 MC 25.285 (c) (9) and (10). (9) (c) J(/(})(lJ) We are preparing to perform a surface casing shoe abandonment on SCU 33A-08, utilizing a crane and work platform. We have reviewed the conventional BOPE rig up and equipment and have augmented it for this well to satisfy our internal standards. The proposed well control system will exceed the safety standards for the expected pressure and flow regimes in the wellbore. The Hemlock production interval was previously abandoned on 8/16/01. This provides the benefit of working in a closed wellbore. The well has no open perforations and is not capable of flowing any fluids. The well control system, as proposed, will facilitate the pulling of 3500' of tubing from the wellbore and allows the conclusion of the abandonment process for this well. We consider the application of this, and all BOP configurations, to be specific for each individual well. We do not intend or desire to consider this as an area wide or unilaterally applied configuration. We are greatly appreciative of your review of this proposal and look forward to meeting with you to discuss any issues. Attached you will find a brief description of the BOP configuration and a layout schematic. Please contact Steve Tyler at 263-7649 or tvlersl@unocal.com for any questions you may have. , - Best regards, ~/~,- Philip J. Krueger Drilling Manager cc: Steve Tyler 4rr I ~' Attachments ~ Union Oil Company of California I Unocal Alaska 909 West 9th Avenue. Anchorage. Alaska 99501 http://www.unocal.com BOP Configuration Reservoir The highest anticipated BHP, at this time, is 1530 psi @ 3,500 TVD which is equivalent to a .4368 psi/ft gradient or a 8.4 ppg EMW. Fully evacuated, the MASP would be as follows: 1530 psi BHP - (3500' TVD x .1 psi/ft Gas Gradient) = 1,180 psi MASP. /' Proposed Confiauration BOP's Annular,5K 11" Hydril Studded Top and Flanged Bottom. Double gate, 5K, 11" Shaffer LWS DBL Mud Cross, 11" Drilling Spool Accumulator Swaco Koomey, 3000 psi, 140 gallon, 14 ea. 11 gallon, 210 gallon fluid reservoir, 4 ea. nitrogen back up bottles, air operated pump. Pump The pump is an 10,000 psi Schlumberger cementer pump truck. Kill Line The Kill Line/Circulating Line will consist of 2",10,000 psi Iron with integral Fig 1502 Unions. /' Kill Line Valves ~ The kill line valves will consist of, at a minimum, 2 ea. .. nuall operated, 2-1/16", 5K valves attached to the mud cross. . Choke Line Valves The choke line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16". 5k valves that will be attached to the mud cross. Choke Line The choke line will consist of either 2", 10,000 psi Iron or 2" 5,000 psi hose with integral Fig 1502 Unions. Choke Manifold The choke manifold is 2-1/16", 5K with two manual chokes and five valves. There are two valves upstream of each choke. Choke Return Line/Gas Buster Line The gas buster line will consist of 2",5000 psi hose with threaded Fig 1502 Unions. The line will run from the choke manifold to the gas buster. Gas Buster The gas buster is located in the 300 bbl flow-back tank. Soldotna Creek Unit Well No. 33A-8 Actual Completion 8/18/98 UNOCAL~ 1 Temporary Abandoned on 8/16/011 3 CASING AND TUBING DETAIL Size Wt Grade Conn ID To Btm Hole Cmt Cmt To 18" 17' 58' Driven 10-3/4" 40.5 K-55 10.050 17' 3,332' 15" 2218 It Lead Surf + 150sx G 33.7 BTC 6.765 17' 85' 26.4 N-80 BTC 6.969 85' 3,940' 33.7 BTC x 8rd 6.765 3940' 3,958' 323sx w/2.4% gel 5,926' 7-5/8" 29.7 8rd 6.875 3,958' 6,905' 9-Yo" CBl 33.7 S-95 8rd 6.765 6,905' 7.332' DV Collar 7,332' 7,334' 33.7 S-95 8rd 6.765 7,334' 9,631' Lead 320sx G w/2.4% gel 8,736' + 100sxofG CBl 20 N-80 4.778 9,631' 11,178' 74 bbls of class 'G" 10.792' CBl 2 JEWELRY DETAIL NO. Depth ID OD Item 17' Shaffer, 3-1/2", 5M, Single Tubing Hanger CIW Type 'H' Collapsed Tbg @ BPVP 7,651' I 2,239' 2.347 4.750 McMuny Macco, 2-7/8" SMO-I GLM, BK-2 wI Dummy Tagged on 7/16/01 2 4,032' 2.347 4.750 McMuny Macco, 2-7/8" SMO-I GLM, BK-2 wI Dummy 3 5,540' 2.347 4.750 McMuny Macco, 2-7/8" SMO-I GLM, BK-2 wI Dummy 4 6,729' 2.347 4.750 McMuny Macco, 2-7/8" SMO-I GLM, BK-2 w/ Dummy 5 7,757' 2.347 4.750 McMuny Macco, 2-7/8" SMO-I GLM, BK-2 w/Dummy 6 8,593' 2.347 4.750 McMuny Macco, 2-7/8" SMO-I GLM, BK-2 wI Dummy 7 9,180' 2.347 4.750 McMuny Macco, 2-7/8" SMO-I GLM, BK-2 wI Dummy 8 9,727' 2.347 4.500 McMuny Macco, 2-7/8" SMOR-I GLM S.c. BK-2 Empty 9 10,242' 2.347 4.500 McMuny Macco, 2-7/8" SMOR-I GLM S.C. BK-2 Empty 10 10,725' 2.347 4.500 McMuny Macco, 2-7/8" SMOR-I GLM S.C. BK-2 Empty 11 10,763' 2.375 4.00 Anchor Seal Assembly, E-22, 2.77' The following were set on E-Line 10/31/90. 12 10,739' 3.000 4.437 Packer, 2-7/8 x 7-5/8" Baker Mod. 'F-I' 13 10,741' Millout Extension, 5.63' Long 14 10,747' I Jt. 2-7/8" 6.5#, N-80, EVE 8 rd 15 10,778' 2.250 Otis 'XN' Nipple, 2-7/8" EVE 8rd, 2.313 wI 2.25" N.G. w/ Plug in place. 16 10,779' I Pup Jt., 2-7/8", 6.5#, N-80, EVE 8rd 17 10,783' WLREG XN 16 H-2 PERFORA nON HISTORY IntervaI Aœmn. Date Zone Top Btm Am: spf Cormmts 7/1/93 H-2 10,836' 10,856' 2CY 4 7/1/93 H-2 10,861' 10,871' 10' 8 10/90 H4 10,914' 10,930' 16' 4 Isolated 10/90 H-5 10,938' 10,946' 8' 4 Isolated 10/90 H-5 10.962' 10.970' R' 4 T~ated 17 SWS Posi Set Plug@ 10,889' 8-4 H-5 H-5 PBTD = 10,889' TD = 11,086' MAX HOLE ANGLE = 27 deg. 33A-8Current8-18-01.doc DRAWN BY: tcb REVISED: 8/20/98 UNOCAL SWANSON RIVER SCU 33A-OS STACK HEIGHT S'g" . WeatB1on1' ~ Ç: 112718 Pipe II ::J C II II Blinds OJ 11" 5M Hydril Annular 5M Studded Top and Flanged Bottom 47 3/4" Tall ~m11" 5M Shaffer lWS DBl ~ 33" Tall x 89 1/4" Wide x 54" Thick ~ 311"5MDrillingSpool I 4" 5M OTl wI 2 ea 24" Tall / 3" 5M HCR 3" 5m MGV rn œ rn 1 11" 5M Hydril Annular BOP 2 11" 5M Shaffer lWS Double BOP 3 11" 5M Drilling Spool w/2 ea 4" 5M OTl 4 3" 5M Hydraulic Gate Valve 5 3" 5M Manual Gate Valve 6 DSA 4" 5M x 3" 5M 7 DSA 4" 5M x 2" 5M 821/16 5M Manual Gate Valve CIW 921/16 5M Manual Gate Valve CIW DII~DD[J] 0 2' 5M MGV 2" 5M MGV rr;ñanual rn rn rn ~hoke 12" 10m Chiksan Iron. I 2" Sm High Pressure hose. To Flow Back Tank sell 33:\-08 I 0 0 - Uo f( 7~ 01 - / c q Phase # 2 &3 P&A 1. Workover Summary: 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. Prep-Work- RU pump truck to 7-5/8" x 10-3/4" annulus. Establish injection rates & pressures down/out 10-3/4" shoe. Prep-Work- RU pump truck to 2-7/8" x 7-5/8" annulus. MIT to 2,000 psi f/ 30 min. Mobe 45 ton crane to Location. Spot Crane, Pipe Racks & accessory equipment on liner. Berm in same. SpotlRU work platform NU BOPE. Pressure test same RU Eline. RIH cut tbg @ :t3,500'. POOH & LD same. RU Slickline. RIH set Cavins BP @ :f:3450'. Dump bail 5' of cmt on top of BP. RD/Demobe crane, work platform and BOPE's. Jug test well to 1500 psi. RU Eline, cementers, cement head and junk tank. RIH w/ Eline. Perforate 3430':t & 3230':f: w/5' x 2.5" PowerJet HC guns. Establish circulation/sqz rates & pressures down 7-5/8" and out 7-5/8" x 10-3/4" annuli to junk tank. RD Eline. Sqz/circulate/spot 50 bbls of G-neat cmt (250 sx) in 7-5/8" x 10-3/4" annuli. Displace cmt w/ 7-5/8" wiper plug & 160 bbls of lease water. Trap pressure on 7-5/8" csg. WOC for 12 hrs. RU pump to 7-5/8" x 10-3/4" annulus. MIT 10-3/4" shoe. RU slickline. Set Cavins BP @ 510':f:. Dump bail 5' of cmt. RU Eline. Perf circulation holes @ 490':1:. Establish circulation down 7-5/8" and out 7-5/8" x 10-3/4" annuli to junk tank. RD Eline. Circulate/fill 7-5/8" csg & 7-5/8" x 10-3/4" annuli with 50 bbls of G-neat cmt to surface. RD cementers. Excavate/remove cellar. Continue excavating around well a 12' x 8' hole. RU csg cutters on 18" conductor pipe. Cut surface csg tubulars off 3' below orginal ground level. Weld surface abandonment plate onto conductor. Record GPS reading of well. Backfill hole. Lt, Ct l-l'Y ç 1\.'1) Ilr \.-' II {j 1l-0( E - Þ<ü"t- / / ~ I &/ 7£,'4 l;Jé? /\-cL.L.._.Lt;- SClI 33A-(JS Phase#2&3 P&A Procedure Re\'O (l7-Ü~ Page 5 of 5 Revision # 0 8/3/200-1 Soldotlltl Creek 1I nit '''ell No. 33.'\-8 Actual Conlpletion 8/18/98 UNOCALe I Temporary Abandoned on 8/16/011 C\SIi\G :\~D lTBIi\G DET.\IL Orig. RKB = IT Size Wt Grade Conn 10 Top 8tm Hole Cmt Cmt Top ~-..". 18" 17' 58' Driven ,,,,-- 1-'" 2218 ¡I\ead I"'.. 10-314 - 405 K-55 10050 17' 3.332' 15" Surf ..~I J"."'-. - + 150sx G -..' ,,,,-. ..~I 337 BTC 6765 17' 85' ,,,,-. 1-'" 26.4 BTC 6.969 85' 3940' ..,.. N-80 1-'" ,,,,-. 337 BTC x 8rd 6765 3940' 3,958' 5,926' 1-'" 323sx w/2 4"0 gel I~.. (8 297 8rd 6875 3.958' 6.905' CBL ..~I 2 7 -5/8 - 9-~ÍI" ,,,,-. 1-'" 337 S-95 8rd 6765 6,905' ì,332' 11f-. ..... DV Collar 7,332' 7,334' ~ - 33.7 5-95 8rd 6.765 7,334' 9,631' Lead 320sx G w/2 4û~ gel 8.736' + 100sx of G CBL 5- 112" 20 N-80 4778 9.631' 11.178' 74 bbls of class "G" 1 0,792' J TOC in Tbg ,~' CBL S,548' Tagged eon 8 I ~ ('I Tubing 2-7/8" I 64 I L-80 I BTC SC I 2441 I 17' I 10,764'~~ ~(). .Benth II) IT Ce,llJp,ed Tbg ,~' 7.651 2.239' T J!!ged on 7 I (i ,) I 2.347 2 ..L032 , 2.347 3 5,,540' 2.347 4 6.729' 2.347 5 7,751' 2.347 6 8593' 2.347 7 9.ISO' 2.347 8 9,7"21' 2.347 9 IO,,2-t2' 2.347 10 10" 7"25' 2.347 II 10,,763' 2.375 12 10,739' 3.000 13 10,741" ~ 14 10,7-11' 15 10,77S' 2.1511 16 10.779" 17 10,783" 12 13 14 15 ,'\1';, ~- l 16 ~. ~ r ~ U 1'" ~ ...-- r"'-. ..~ = ,,/'. - ..., 1':SII~. - .-., r..J I~. Co ..., I- I~. ..., ',/'. 1-" ,,/' 1-" ,,/'. I.:\, ~~~-><~ ,,/'. .-., ,,/'. .-., ',/'. .-., ,,/'. .-., '... ..., ,,/'. rj.) .-., '... ~ 17 33A-8CulTem8-18-0 I-I.doc .JEWEI.!:tY DETAIL Irem Shaffer. 3-112". 5~1. Single Tubing Hanger CIW Type "H' BPVP 4.750 I\kMul1)'l\lacco. 2-7/S" S~10-1 GLI\1. BK-2 wI Dummy .U50 I\lcl\lul1)' I\lacco. 2-7/S" SI\IO-I GUI, BK-2 wI Dumm~ 4.750 1\1cl\1urry I\lacco. 2-7:8" S~10-1 GLI\1. BK-2 wI Dummy 4.750 I\lcl\lul1)' I\lacco. 2-7/8" S1\.10-1 GLI\I, BK-2 wI Dummy 4.750 I\lcl\lul1) I\lacco. 2-7/S" S~10-1 GLI\I, BK-2 wI Dummy 4.750 1\1cl\lurry I\lacco, 2-7/8" S~10-1 GLI\1. BK-2 wI Dummy 4.750 1\lcl\lul1)'l\lacco, 2-7/S" S1\10-1 GLI\1. BK-2 wI Dummy 4.500 1\lcl\.lul1)'l\.lacco, 2-7/S" SI\IOR-I GLI\I S.C BK-2 Empty 4.500 1\1cl\lulT) I\lacco. 2-7/8" S~10R-1 GUI S.C BK-2 Empt~' 4.500 1\.1cl\1urry I\lacco, '2-7/S" S1\10R-1 GUI S.c. BK-2 Empty 4.00 .\nchor Seal Assembly, E-22. 2.71' on 4.437 The folloning were set on E-Line 10/31/90. Packer, 2-7'8 x 7-5/8" Baker I\lod. "F-I' 1\ liIIollt Extension, 5.63" Long I .II. '2-7/S" 6.5#. N-80. EUE S rd Otis '~"N' Nipple. 2-7/S" EUE Srd, 2.3 IJ \\,' 2.25" N.G. wI Plug in place. I Pup Jt.. 2-7/S". 6.5#, N-80. EUE Srd \\'LREG - H-2 PERFORATION HISTORY Interval Arcum Date Zone Top Btm .-\rrf spf 7:'193 H-2 10,836' 10.856' 20' 4 7i1,93 H-2 10,861' 10,87 \' 10' 8 10.90 H~ 10.914' 10,930' 16' 4 1090 H-5 10.938' 10,9-16' 8' 4 10 90 H-5 I 0.9ó2' 10.970' R' 4 lsolata:l lsolatal l<nlatal C.on...rnts S\\'S PO;,I Sct Plu~ ':~, I') :s89 H-4 H-5 H-5 PBTD = 10,889' TD = 11,086' l\IAX HOLE ANGLE = 27 deg. -~ DRA\VN BY: tcb REVISED: 8/20/98 UNOCAL8 t,. --.........' "oi."oi."."."."."."oi.iii,."j(ÏI'"8' :~~~~-t'-t~-t~-t~-t~-t~-t~-t~-t~~~-t- ~-t~ --''''_~'_'''_'_'''-'''-'''-'''-'''-'''-'''.''' ".-~".-- --.. .~-"oi."-"-"oi-'"8-"oi-"M"oi~.'"8' .".-- "'~JI_'JI_'JI_'JI_'JI_'JI_'JI.5'.~-_"'-1I ~,;.~: ~_II. - .-11.- ~,;.~~ BP ~ 5 I O' --.., .-... :«~ ~ot~ ~~-t~ ~~~ '..-- ,,,.-- .-"oi' .-"oi' ,,,.-- .".-- --"oi. --"oi. .".-- ."... :,;.~';;'':.';;'':.';;'':.';;'':.';;'~';;'!.';;'':.SE~'! ..~~ :-:.~-t!-t!-t!-t!Cement.~-J - -- -- -- -":'.-""'--= -- BP (~, .1450' Toe In Tbg ,~' ~.5.8' T Jgged c'l' 8 I g ,) I Proposed Abandonment #2 Soldotn3 Creek Un it '''ell No. 33:\-8 Actual Conlpletion 8/18/98 C.\SII\G '\~D lTBll\G DETAIL Size Wt Grade Conn 10 Top Btm Hole Cmt Cmt Top 18" - 20' 58' Driven 10-3/4" 405 K-55 10050 20' 3,332' 15" 2218 ft)Lead Surf + 150sx G 337 BTC 6765 20' 85' 264 N-80 BTC 6969 85' 3,940' 337 BTC x 8rd 6765 3940' 3.958' 323sx w/2.4~o gel 5,926' 7.5/8" 297 8rd 6875 3.958' 6.905' 9"~ÍI" CBL 337 S-95 8rd 6.765 6.905' 7.332' DV Collar 7,332' 7.334' 337 S-95 8rd 6765 7,334' 9,631' l'Õ'ad 320sx G w/2 4Q~ gel 8,736' + 100sx of G CBL 5-112" 20 N-80 4778 9.631' 11,178' 74 bbls of class "G" 10,792' CBL Tubing 2-7/8" 1 6.4 I L-80 I BTC SC I 2.441 1 3500' 110.764' ~~~~ J£\\'ELI~\' DETAIL C ollJpsed TI:-g ',~' NO. D('')( II ill OD 1(('111 ., 6~ I' IT - - Sh3lTer. 3-1/2"". 51\1. Single Tubmg Hanger CI\\' Type 'H' BPVP TJn:ed on" 1601 3 5 SHY 2.347 4.750 1\1c1\IUIT)' Macco. 2-7/S" S!\IO-I GL1\1. BK-2 wI Dummy 4 6.729' 2.347 ..USO 1\lcl\lulT)'1\lacco. 2-7/8" S1\10-1 GL1\1. BK-1 wI Dummy 5 7,751' 2.347 ,U50 !\1c!\lurry 1\lacco. 2-7/8" SI\IO-I GUI. BK-2 wI Dumm~' 6 8.593' 2.J47 4.750 1\1c1\lurry !\Iacco, 2-7/8" S!\IO-I GL1\1. BK-2 wI Dummy 7 9.180' 2.347 4.750 1\lc!\luIT)' !\Iacco. 2-7/8" SI\IO-I GL1\1. BK-2 wI Dummy S 9.721' 2.347 ..1.500 !\1c!\lulT)' Macco. 2-7/S" SI\IOR-I GUI S.c. BK-2 Empty 9 10,242' 2.347 4.500 !\lcMurry 1\13CCO. 2-7/S" S1\10R-1 GLl\r S.c. BK-2 Empty 10 10.725' 2347 4.500 !\1c!\lulT)' Macco. 2-7/8"' S!\IOR-I GUI S.c. BK-2 Empt~' II 10.763' 2.375 4.00 Anchor Seal Assembly. E-22. 2.71' The following were ~et on E-Line J0/3J/90. 12 10.739' 3.000 4,437 Packer. 2-7:8 x 7-5/8" Baker 1\lod. 'F-I' \.3 10.741' - - !\Iillout Extension, 5.63" Long 14 10.741' - - I .It. 2-7/S"' 6.5#, N-SO. EUE 8 I'd ~ 15 10.778' 2.:~ 50 - Otis '\.'N' Nipple, 2-7/8" EUE Srd. 2.313 wi 2.25"' N.G. wI Plug in pl3ce. 16 10.779' - - I Pup.ll.. 2-7/8", 6.5#. N-80. EUE Srd 17 10.783" - - \\'LREG 16 ;"1 7 0w- l""-. .... = ,-,/'- - .-., ¡'~'I 1"'- C r';:'~ 0 .-., I- '-,/'. .-., '-,/'. .-., ~~., '-,/'. ~~~----- ----- 5\\'5 P0,1 S~l Plug"l' !(,,¡::g9' r~~-- ------~ H-4- 1-" 1.-. r';:'~ H-'=i .-., - ,-,/'- .-., ~~~ H-5 ,-,/'. .-., '-,/'- .-., ,-,/'- ~ 17 - H-2 ~ 33A-S Proposed P&A-I.doc Date PERFORA TION HISTORY I Inten'aI I ,.\ccwn I I I Zone Top Btm i Ant spf, COIm1 lbg I~,"l'h ,NO' I ..e)(,' b' .. i ."'opt)' I (ÌI'c¡~(.l 3.230' 3.2:15' 5' .. PrO'lC)1 (jrcJSql: 3...00' 3.4-'5' 5' .. Propo~ H-2 10.836' 10.856' 20.' 4 H-2 I 0.861' I 10.871' 10.' 8 H-4 10.914' I 10.,930.' 16' 4 ! Isolara H-5 10.938' IO.~' 8' 4 ! lsolata H-5 10.962' 10.970.' I 8' 4 Ilsolatð 7/1.']993 7/1,'93 10..'90 10.'90 Ill'9Q PBTD = 10,889' TD = 11,086' !\lAX HOLE ANGLE = 27 deg. DRA\VN B'Y: tcb REVISED: 8/10/98 '0 Abandon ~ Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99516 7. KB Elevation (ft): 17' KB 1. Type of Request: 8. Property Designation: Swanson River Unit 11. Total Depth MD (ft): 11086' Casing Structural ITotal Depth TVD (ft): 10855' Length Conductor Surface 38' 3,315' 9,614' Intermediate Production Perforate U Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 100-268 / 6. API Number: ~ 50-133~1 Zo '24/-01 STATE OF ALASKA r"\ A~A OIL AND GAS CONSERVATION COM. .;SION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development [2] Stratigraphic 0 Suspend U Repair well 0 Pull Tubing 0 Exploratory 0 Service 0 9. Well Name and Number: SCU 33A-08 /' 10. Field/Pools(s): Swanson River Field/Hemlock PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10870' 10,659' Size MD TVD \f-J ~'"' "1 ( I I t-,",v"T t) V:f 1l-/ f? ( 1- Annular Dispos. U Other 0 PIU9S (measured): 5,548' Burst JUnk (measured): none Collapse 18" 58' 58' 3,332' 9,537 10-3/4" 7-5/8" 3,332' 9,631' 5/23/2004 Date: 11,178' 10,939' Tubing Size: ITUbing Grade: 2-7/8" L-80 Packers and SSSV MD (ft): 10,739' 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas 0 Plugged WAG 0 GINJ 0 WINJ 1,253' 5-1/2" Perforation Depth TVD (ft): 10,629 to 10,660 Liner Perforation Depth MD (ft): 10,836 to 10,871' Packers and SSSV Type: 2-7/8 x 7-5/8 Baker Mod F-1 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Philip J. Krueger Title Drilling Manager Signature ~ / Á - Phone 907-276-7600 Date /". ~'I r COMMISSION USE ONLY 629 psi 602 psi 1,580 psi 3,400 psi 466 psi 8,830 psi Tubing MD (ft): 10,641' 0 Service 0 0 Abandoned 0 0 WDSPL 0 Contact Steve Tyler 907-263-7649 SUndry Number: 3 ô ~ ./ D 9 [if RECEIVED APR - 7 2004 A'aska Oil & Gas Cons. Commission Anchorage D'œlÍ~f Submit in Duplicate Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Other: t (9 - c..J 07 Approved by Mechanical Integrity Test 0 Location Clearance COMMISSIONER BY ORDER OF THE COMMISSION .--- "';~ONS °lJRVT~'" 4/1/2004 Proposed Abandonment #2 ~ Soldotna Creek Unit Well No. 33A-8 Actual Completion 8/18/98 ,-..., UNOCAL8 /1 CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm Hole Cmt Cmt Top 18" 23' 58' Dnven 10-3/4" 40.5 K-55 10.050 23' 3,332' 15" 2218 tt'Lead Surf + 150sx G 33.7 BTC 6.765 23' 85' ..1M.... N-80 BTC 6.969 85' 3,940' 33.7 BTC x 8rd 6.765 3940' 3,958' 323sx w/2.4% gel 5,926' 7-5/8" 29.7 8rd 6.875 3,958' 6,905' 9-%" CBL 33.7 S-95 8rd 6.765 6,905' 7,332' DV Collar 7,332' 7,334' 33.7 S-95 8rd 6.765 7,334' 9,631' Lead 320sx G w/2.4% gel 8,736' + 100sxofG CBL TOCIl1Tbg~ 5-1/2" 20 N-80 4.778 9,631' 11,178' 74 bbls of class 'G" 10,792' 5,548' CBL Tagged on 8/18/01 Tubing 2-7/8" I 6.4 I L-80 I BTC SC I 2.441 I 17' I 10,764' I JEWELRY DETAIL I Collapsed Tbg @ I NO. Deoth ID OD .Item 7,651' 17' Shaffer, 3-1/2", 5M, Single Tubing Hanger CIW Type 'H' BPVP Tagged on 7/16/01 3 5,540' 2.347 4.750 MeMurry Maceo, 2-7/8" SMO-l GLM, BK-2 wi Dummy 4 6,729' 2.347 4.750 MeMurry Macco, 2-7/8" SMO-l GLM, BK-2 wi Dummy 5 7,757' 2.347 4.750 MeMurry Macco, 2-7/8" SMO-I GLM, BK-2 wi Dummy 6 8,593' 2.347 4.750 McMurry Macco, 2-7/8" SMO-l GLM, BK-2 wi Dummy 7 9,180' 2.347 4.750 McMurry Macco, 2-7/8" SMO-l GLM, BK-2 wi Dummy 8 9,727' 2.347 4.500 McMurry Maeeo, 2-7/8" SMOR-l GLM S.C. BK-2 Empty 9 10,242' 2.347 4.500 McMurry Maeeo, 2-7/8" SMOR-l GLM S.C. BK-2 Empty 10 10,725' 2.347 4.500 McMurry Maeeo, 2-7/8" SMOR-l GLM S.C. BK-2 Empty 11 10,763' 2.375 4.00 Anehor Seal Assembly, E-22, 2.77' The following were set on E-Line 10/31/90. 12 10,739' 3.000 4.437 Packer, 2-7/8 x 7-5/8" Baker Mod. 'F-l' 13 10,741' Millout Extension, 5.63' Long 14 10,747' I J1. 2-7/8" 6.5#, N-80, EVE 8 rd ~ 15 10,778' 2.250 Otis 'XN' Nipple, 2-7 IS" EVE 8rd, 2.313 w/ 2.25" N.G. wi Plug in place. 16 10,779' 1 Pup Jt., 2-7/8", 6.5#, N-SO, EVE Srd 17 10,783' WLREG ,XN 16 H-4 H-5 PERFORA nON HISTORY Interval Accwn. Date Zone Top Btm Ant spf Comœnts 7/1/93 H-2 10,836' 10,856' 2rJ 4 7/1193 H-2 10,861' 10,871' 10' 8 10/90 H4 10,914' 10,930' 16' 4 Isolated 10/90 H-5 10,938' 10,946' 8' 4 Isolated ]0/90 H-5 ]0.962' ]0.970' R' 4 Toolated 17 - H-2 SWS POSt Set Plug @ 10,889' H-5 PBTD = 10,889' TD = 11,086' MAX HOLE ANGLE = 27 deg. 33A-8 Proposed P&A DRAWN BY: tcb REVISED: 8/20/98 UNOCAL8 Orig. RKB = 17' 58,J 3.332' - .. ~ ,XN 17 33A-8 Proposed P&A r--... L Proposed Abandonment #2 ~ Soldotna Creek Unit Well No. 33A-8 Actual Completion 8/18/98 Proposed Procedure . Jet cut tbg @ 5530' (10' above #3 GLM). /' . Girculate/~pot an EW A.G volume of 10 ppg brine. /' . - Jug test well~ore to 1500 psi. /' . POOH wI tbg & LD same.J RU SL. RIH set Cavins Bridge Plug @ 3500'. RD SL. /' . . RU Eline. RIH Perf csg @ 3340'. Establish circulation down 7-Sfa" csg, while taking returns out 10-%" x 7-%" csg annuli. "..... . /' RU cementers. Circulate cement down 7-5/8" csg.!!!! c.!!!,t r~s are @ surface. -r. . RU csg cutter. Cut 18", lO-%" & 7-%" csgjust above bottom of cellar. POOH LD csg stubs. . Top off surface plug wI cement as necessary. Utilize a 2" PVC pipe to convey cmt down. /' . Weld abandonment plate onto conductor. Record GPS reading of well's position on morning report. /' . Dig out and remove cellar. Back fill hole to pad level. DRAWN BY: tcb REVISED: 8120/98 . UNOCAL8 """,, ~ Soldotna Creek Unit Well No. 33A-8 Actual Completion 8/18/98 ':;;: ~ ,....." ~«.t: ...(Sß '...... ..". ,....." ..". ~~,,:; ~~ ¡'!'~ @ ~~ '...... ..". '..... æ - 2 i XN 16 17 33 A -8Current8-18-0 1 I Temporary Abandoned on 8/16/011 /' CASING AND TUBING DETAIL - 17' Size Wt Grade Conn ID Top Btm Hole Cmt Cmt Top L 18" 17' 58' Driven 10-3/4" 40.5 K-55 10.050 17' 3,332' 15" 2218 tt'Lead 5urt + 150sx G .2li.. BTC 6.765 17' 85' 26.4 N-80 BTC 6.969 85' 3,940' ..11L BTCx8rd 6.765 3940' 3,958' 323sx w/2.4% gel 5,926' 7-5/8" 29.7 8rd 6.875 3,958' 6,905' 9-Va" CBl 33.7 5-95 8rd 6.765 6,905' 7,332' DV Collar 7,332' 7,334' - 33.7 5-95 8rd 6.765 7,334' 9,631' Lead 320sx G w/2.4% gel 8,736' + 100sxofG CBl 5-1/2" 20 N-80 4.778 9,631' 11,178' 74 bbls of class "G" 10,792' CBl Tubing 2-7/8" I 6.4 l-80 I BTC 5C I 2.441 17' I 10,764' ~ JEWELRY DETAIL NO, Depth ID OD Item 17' Shaffer, 3-1/2", 5M, Single Tubing Hanger CIW Type 'W Collapsed Tbg @ I BPVP 7,651' I 2,239' 2.347 4.750 MeMurry Maeeo, 2-7/8" SMO-I GLM, BK-2 wi Dummy Tagged on 7116/01 2 4,032' 2.347 4.750 MeMurry Maeeo, 2-7/8" SMO-I GLM, BK-2 wi Dummy 3 5,540' 2.347 4.750 MeMurry Maeeo, 2-7/8" SMO-I GLM, BK-2 wi Dummy 4 6,729' 2.347 4.750 MeMurry Maeeo, 2-7/8" SMO-I GLM, BK-2 wi Dummy 5 7,757' 2.347 4.750 MeMurry Maeeo, 2-7/8" SMO-I GLM, BK-2 wI Dummy 6 8,593' 2.347 4.750 MeMurry Maeeo, 2-7/8" SMO-I GLM, BK-2 wI Dummy 7 9,180' 2.347 4.750 MeMurry Maeeo, 2-7/8" SMO-I GLM, BK-2 wi Dummy 8 9,727' 2.347 4.500 MeMurry Macco, 2-7/8" SMOR-I GLM S.C. BK-2 Empty 9 10,242' 2.347 4.500 McMurry Macco, 2-7/8" SMOR-I GLM S.C. BK-2 Empty 10 10,725' 2.347 4.500 McMurry Macco, 2-7/8" SMOR-I GLM S.c. BK-2 Empty 11 10,763' 2.375 4.00 Anchor Seal Assembly, E-22, 2.77' The following were set on E-Line 10/31/90. 12 10,739' 3.000 4.437 Packer, 2-7/8 x 7-5/8" Baker Mod. 'F-I' 13 10,741' Millout Extension, 5.63' Long 14 10,747' I Jt. 2-7/8" 6.5#, N-80, EVE 8 rd 15 10,778' 2.256 Otis ')(N' Nipple, 2-7/8" EVE 8rd, 2.313 wI 2.25" N.G. wI Plug in place. 16 10,779' I Pup Jt., 2-7/8", 6.5#, N-80, EVE 8rd 17 10,783' WLREG - H-2 PERFORATION HISTORY Interval Aœwn Date Zone Top Btm Ani; spf 7/1/93 H-2 10,836' 10,856' 2(J 4 7/1/93 H-2 10,861' 10,871' 1(J 8 10/90 H4 10,914' 10,930' 16' 4 10190 H-5 10,938' 10,946' 8' 4 ]0/90 H-5 10.962' 10.970' 8' 4 Isolated Isolated Isolated Cornnents SWS POS! Set Plug@ 10,889' H-4 H-5 H-5 PBTD = 10,889' TD = 11,086' MAX HOLE ANGLE = 27 deg. DRAWN BY: tcb REVISED: 8/20/98 SCU 33A-8 Subject: $CU 33A-8 Date: Fri, 3 Aug 2001 09:34:06 -0800 From: "Bill Penrose" <bill@fairweather.com> To: "Tom Maunder $E-mail$" <tom_maunder@admin.state.ak. us> Tom, This is to condense the lengthy discussion we had this morning concerning Unocal's plans for the subject well. As indicated in the Sundry Notice, the plan is solely to place sufficient cement to isolate the pressure coming from the formation opposite the casing collapse and to abandon the bottom part of the hole below the collapse. There is no intent to P&A or suspend the well as there may be potential for future use of the remaining wellbore and we'd like to keep that option open. (This well was the second best producer in Swanson River before its mechanical problems caused it to be shut in.) SCU 33A-8 is one of three wells on the same pad and, whether or not the wellbore is used in the future, it is anticipated that it's P&A will be ultimately integrated into the P&A plans for the others. As for the pressured interval at the depth of the casing collapse, I've been doing some checking around. The drilling people who've drilled in SWanson River over the years tell me that there has always been a spotty pressured zone at about that depth. It isn't always encountered and, when it is, it can even vary slightly in depth. The anecdotal evidence indicates the pressured interval having been present before any waterflood was initiated, so it must be a natural phenomenon. If I can answer any additional questions, please let me know. Regards, Bill I of I 8/3/01 10:28 AM (c) The provisions of 20 AAC 25.112(a) - (c) and (e) - (i) apply to plugging a well branch. (d) This section does not apply to the temporary plugging of a well branch for production control purposes. History - Eft. 11/7/99, Register 152 Authority - AS 31.05.030 20 AAC 25.110 SUSPENDED WELLS. (a) If allowed under 20 AAC 25.'105, the commission will, upon application by the operator under (b) of this section, approve the suspension of a well if (1) the well (A) encounters hydrocarbons of sufficient quality and quantity to indicate that the well is capable of producing in paying quantities, as reasonably demonstrated by well tests or interpretive formation evaluation data; for purposes of this paragraph, "paying quantities" means quantities sufficient to yield a return in excess of operating costs; -,~ (B) is a candidate for redrilling; ' ~' (C) has potential value as a service well; or ........ ~ (D) is located on a pad or platform with active producing or service wells; and (2) the operator justifies to the commission's satisfaction why the well should not be abandoned, and, if the well is not completed, why the well should not be completed; sufficient reasons include the (A) unavailability of surface production or transportation facilities; (B) imprudence of security maintenance of a completed well in a shut-in status; (C) need for po°l delineation and evaluation to determine the prudence of pool development. (b) An Application for Sundry Approvals (Form 10-403) must be submitted to and approved by the commission before plugging operations are begun in a well for which suspension is proposed, except that oral approval may be obtained from the commission if it is followed within three days by the submission of an Application for Sundry Approvals for final approval by the commission. Approval will be conditioned as necessary to protect freshwater and hydrocarbon resources. An Application for Sundry Approvals must include (1) the reason for suspending the well and information showing that the applicable criteria for suspension under (a) of this section have been met; and (2) a statement of proposed work, including 40 I I I I I I i I I I I I ! I I I I I I ~ (A) information on abnormally geo-pressured strata; ~ (B) the manner of placement, kind, size, and location, by measured depth, of existing and proposed plugs; (C) plans for cementing, shooting, testing, and removing casing; (D) if the Application for Sundry Approvals is submitted after beginning work, the name of the representative of the commission who provided oral approval, and the date of the approval; and (E) other information pertinent to suspension of the well. (c) At the operator's request accompanying the submission, information submitted to show that the applicable criteria for well suspension under (a) of this section have been met will be kept confidential (1) for the period specified under AS 31.05.035(c), if the information is described in 20 AAC 25.071(b); or (2) for the time that the information has value as a trade secret, if the information is not described in 20 AAC 25.071 (b) but is determined by the commission to constitute a trade secret under AS 45.50.940. (d) A well approved for suspension must be plugged in accordance with the requirements of 20 AAC 25.112, except that the requirements of 20 AAC 25.112(d) do not apply if .-~---~ (1) a wellhead is installed or the well is capped with a mechanical device to seal the opening; and (2) a bridge plug capped with 50 feet of cement or a continuous cement plug extending 200 feet within the interior casing string is placed at or above 300 feet below the surface; the commission will waive the requirement of this paragraph for a development well drilled from a pad or platform, if the commission determines that the level of activity on the pad or platform assures adequate surveillance of that development well. (e) Until a suspended well has been abandoned or re-entered, the operator shall maintain the integrity of the location, provide the commission with a well status report every five years, and clear the location in accordance with 20 AAC 25.170(a)(2) or (b) or with 20 AAC 25.172(c)(2) or (d), as applicable. History - Eft. 4/2/86, Register 97; am 11/7/99, Register 152 Authority - AS 31.05.030 20 AAC 25.112 WELL PLUGGING REQUIREMENTS. (a) Plugging of the uncased portion of a wellbore must be performed in a manner that ensures that all hydrocarbons and freshwater are c6nfined to their respective I 41 Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager 8/2/01 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Application for Sundry Approval; SCU 33A-8 Suspension Swanson River Field, Alaska Dear Commissioner Heusser: Unocal Alaska Resources hereby submits an Application for Sundry Approval for its plan to set a cement plug in Well SCU 33A-8 in order to isolate a casing leak. Previously, we had planned to convert this well to a rod pump completion. However, the well was recently found to contain collapsed casing and tubing. The collapsed casing has an attendant leak allowing formation pressure into the tubing x casing annulus. Please find enclosed an Application for Sundry Approval (Form 403), a summary plugging procedure and a wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 250-3113. S' cerely, Z~ Dan Williamson Drilling Manager RECEIVED /lU6 0 2 OOl Alaska Oil & Gas Cons. Commission Anchorage AOGCC Sundry Cover Ltr ORIGINAL Bill Penrose STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [ ] Abandon '~Suspend [X] Plugging [ ] Alter Casing [] Repair Well ] Pull Tubing [ ] Change Approved Program [ ] Operation Shutdown ] Re- Enter Suspended Well . 12. Name of Operator UNOCAL ALASKA RESOURCES Address 909 W. 9th Avenue, P.O. Box 196247, Anchorage, AK 99519-6247 Location of well at surface 1959' FNL, 1987' FEL, Sec. 8, T7N, R9W, SM At top of productive interval 2533' FSL, 1655' FEL, Sec. 8, T7N, R9W, SM At effective depth At total depth 2430' FSL, 1563' FEL, Sec. 8, T7N, R9W, SM 5. Type of well: [X] Development [ ] Exploratory [ ] Stratigraphic [ ] Service Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural N/A Conductor 38' Surface 3,315' Intermediate 9,614' Production N/A Liner 1,253' 11,086 feet 10,855 feet 10,870 feet 10,659 feet Plugs (measured) Junk (measured) ] Time Extension [ ] Perforate ] Variance [ ] Other ] Stimulate 6. Datum Elevation (DF or KB) 17' AGL 7. Unit or Property Name Soldotna Creek Unit 8. Well Number 33A-8 9. Permit Number 100-268 10. APl Number 50-133-2e2.5~ 11. Field and Pool Swanson River: Hemlock 10,870' (TOC, 19' cmt plug on bridge plug) None Size Cemented MD TVD 18" 55' 55' 10-3/4" 3,332' to surface 3,332' 3,332' 7-5/8" 643 sx in 2 stages 9,631' 9,537' 5-1/2" TD to liner top 11,178' 10,939' Perforation depth: measured True vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 10,836' - 10,856' and 10,861'- 10,871' 10,629' - 10,647' and 10,651' - 10,660' 2-7/8", L-80 at 10,783' RECEIVED / U6 0 2' 2001 Alaska Oil & (?as Cons. Commission Anchorage 5-1/2" Baker Model F-1 permanent packer at 10,739' 13. Attachments [X] Description of Sumary Proposal 14. Estimated date for commencing operation 8/8/2001 16. If proposal was verbally approved Name of approver N/A Date Approved Contact Engineer Name/Number: Bill Penrose, 250-3113 ] Detailed Operations Program [ ] BOP Sketch 15. Status of well classification as: IX] Oil [ ] Gas Service [ ] Suspended Prepared By Name/Number: Bill Penrose, 250-3113 17. I hereby c_~e~ify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~ L~i2..E.(_~ ~ ~'- Commission Use Only Conditions of Approval: Notify Commission so representative may witness Date .,~/~./~, ~ IApproval No.,~)[-~ ,,_, . V' G{'3JOY~¥8-'C'~ Plug integrity "~ BOP Test Location Clearance Mechanical Integrity Test~ Subseque_nt fgrm r, equired 10- tA,~'~.. 'in~ well ~V'e ..~zsr~r~:,.,c,n U,-~'~l c¢?l're I'n or~__ dec~ C~I~2/C~-).,~VZ~J c~ppL,~ Approved by order of the Commission OommissJoner Form 10-403 Rev. 06/15/88 ORIGINAL SIGNED B'¢ Date O(~/O ~/~ / Subrn'l't~ In Tri~)lic~te UNOCAL I Soldotna Creek Unit Well No. 33A-8 Actual Completion 8/18/98 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 18" - . . Surface 55' 10-3/4" 40.5 - - 10.050 Surface 3,332' 7-5/8" 33.7 N-80 BTC 6.765 15' 85' 26.4 N-80 BTC 6.969 85' 3,940' 33.7 N-80 BTC x 8rd 6.765 3940' 3,958' 29.7 N-80 8rd 6.875 3,958' 6,905' 33.7 S-95 8rd 6.765 6,905' 9,631' 5-1/2" 20 N-80 - '4.778 9,631''11,178' Tubing 2-7/8" 6.4 L-80 BTC SC 2.441 17' 10,764' ' A JStage · Collar ~ 7,332' SWS Posi Set Plug ~ 10,889' 12' 13 14 · 15 16 B H-2 H-4 H-5 H-5 · JEWELRY DETAIL NO. Depth ID OD Item 17' - - Shaffcr, 3-1/2", SM, Single Tubing Hanger CIW 1' 2,239' 2.347 4.75C 2 · 4,032' 2.347 4.750 3 5,540' '2.347 4.750 4 6,729' 2.347 4.750 5 7,757' 2.347 4.750 6 8,593' 2.347 4.750 7 9,180' 2.347 4.750 8 9,727' 2.347 4.500 9 10,242' 2.347 4.500 10 10,725' 2.347 4.500 11 10,763' 2.375 4.00 12 10,739' 3.000 4.437 13 10,741' - - 14 10,747' - - 15 10,778' ' 2.250 - 16 10,779' 17 10,783' Type 'H' BPVP McMurry Macco, McMurty Macco, McMurry Macco, McMurry Macco, McMurry Macco, McMurry Macco, McMurry Macco, McMurry Macco, McMurry Macco, 2-7/8" SMO-1 GLM, BK-2 2-7/8'.' SMO-1 GLM, BK-2 2-7/8" SMO-I GLM; BK-2 2-718" SMO-1 GLM, BK-2 2-718" SMO-1 GLM, BK-2 2-718" SMO-I GLM, BK-2 2-7/8" SMO-I'GLM, BK-2 2-718" SMOR-1 GLM S.C. BK-2 2-718" SMOR-1 GLM S.C. BK-2 McMurry Macco, 2-718" SMOR-1 GLM. S.C. BK-2 Anchor Seal Assembly, E-22, 2.77' The following were set on E-Line 10/31)90. Packer, 2-7/8 x 7-518" Baker Mod. 'P-l' Millout Extension, 5.63' Long 1 Jt. 2-7/8" 6.5#, N-80, EUE 8 rd Offs 'XN' Nipple, 2-7/8" EUE 8rd, 2.313 w/2.25" N.G.. 1 Pup Jt., 2-7/8",'6;5#, N-80, EUE 8rd WLREG Notes: A B Stage Collar at 7,332' Sclumberger Posi Set Plug at 10,889' wi 19' of cement. .. ,, i PERFORATION HISTORY 7/1/93 H-2 10,836' 10,856' 20' 4 7/1/93 H-2 10,861' 10,871' 10' 8 10/90 H-4 10,914' 10,930' 16' 4 !Imlated 10/90 H-5 10,938' 10,946' 8' 4 Isolated , ...... ! fig0.H-5 105J62' 10.970' 8' 4 Tmlnted PBTD = 10,889' TD = 1i,086' MAX HOLE ANGLE = 27 deg. SCU 33A-8 Act'Draw DRAWN BY: tcb REVISED: 8/20/95 UNOCAL Soldotna Creek Unit Well No. 33A-8 Well Suspension Version: Summary Objective: Isolate damaged and leaking casing in Well SCU 33A-8 via placing a cement plug. History: The current gas lift completion was installed in SCU 33A-8 in August of 1998. In May of 2000 production began falling off. In October of 2000, fill was found in the tubing at 7,647' and the well pressured up even though there is a tubing plug set below the packer. There is a casing leak that allows the annulus to build up to 1,500 psi when filled with water. It was suspected that this casing leak had produced sand into the annulus and the tubing. CTU diagnostic work and clean-out attempts in July 2001 indicated that the tubing and casing are collapsed at 7,651'. The well can be circulated past this point in the tubing, through the open GLM pockets at 9,727' and 10,242', and out the annulus at the surface. Howbver, a 1-1/2" lead impression block would not pass the collapsed spot in the tubing. The decision was subsequently made to suspend the Well with cement in such a way that the source of the high formation pressure at the casing collapse is isolated with cement. Current Status: The well has been shut in since 10/00. Notes: Original RKB Pore pressure: 26' See 'Reservoir Pressure' below Wellhead Sundry Procedure Page 1 Of 3 8/2/2001/9:49 AM UNOCAL Soldotna Creek Unit Well No. 33A-8 Well Suspension Version: Summary Tubing head is a Shaffer KD 75L1, 11" 5M X 9" 5M 2 Master valves: FMC-OCT, M/20, 3-1/8" 5M, R-Trim, HWO Tree cap: Thornhill Craver, Unibolt, 3-1/8 5M w/3-1/2" EUE lift threads Reservoir Pressure Current Perforations Open: H-2 Sand 10,836' - 10,856' MD, 10,621' - 10,640' TVD 10,861' - 10,871' MD, 10,644' - 10,653' TVD estimated formation pressure = 1,500 psi Casing Leak: Collapsed Csg _+7,651' MD, 7,625' TVD estimated formation pressure = 4,700 psi General Well Information See attached wellbore schematic. The bottom 3 gas lift valves have been pulled, leaving the pockets empty. There is a plug in the tubing tailpipe at 10,778'. Procedure: Ch~:..~.:~k and record tubing and annulus pressures. Set tanks and rig lines'to take returns from the annulus to tanks through a choke. Set a tank filled with lease water for circulating down the tubing. 2. MIRU cementing unit and rig to pump down the. tubing. Pressure test lines to 5,000 psi. . . . . Holding 1,500 psi back pressure on the annulus, establish circulation down the tubing to ensure cement can be circulated around. Pump down tubing 154 bbls of Class G cement with additives. 't'~ Use the choke on the annulus return line to hold 1,500 psi back pressure on the annulus while taking returns to tanks. Follow cement with 36.5 bbls of lease water to place the top of cement in the annulus and tubing at 6,300'. 7. WOC. Sundry Procedure Page 2 of 3 8/2/2001/9:49 AM UNOCALe Soldotna Creek Unit Well No. 33A-8 Well Suspension Version: Summary Bleed down pressure on annulus and tubing to ensure cement has isolated the casing leak. . R/U slickline and make a gauge ring run to the top of cement in the tubing. Record tag depth. POOH w/gauge ring. 10. R/D cementing and slickline equipment and tanks. Clean up location. Sundry Procedure Page 3 of 3 8/2/2001/9:49 AM FW: Swanson Wort(over Program · Subject: FW: Swanson Workover Program Date: Thu, 3 May 2001 08:47:11 -0800 From: "Bill Penrose" <bill@fairweather.com> To: "Tom Maunder $E-mail$" <tom_maunder@admin.state.ak. us> Tom, For your information and records: This is the same e-mail I sent you on 5/1/01 except that I've changed the discussion of BOPE to be used when running rods in the rod pump conversions. Please dispose of that previous message as the BOP discussion was grieviously in error. Thanks! Bill .... Original Message .... From: Bill Penrose [mailto:bill~.fairweather. com] Sent: Tuesday, May 01,2001 8:57 AM To: Tom Maunder (E-mail) Subject: RE: Swanson Workover Program Tom, Following each question that you posed is the answer, preceded with an A: One big question. What rig is proposed? A: H&R Rig #9, being imported from Canada. .SRU 14-15... -What are the BHPs of the old interval and the new? Unless there is a possibility of a high pressure zone (there. are a few out there), 3000 psi sounds appropriate. A: BHP of the old interval is 4,900 psi and will only flow water. The BHP of the new interval is 3,000 psi and is expected to flow gas. The request for testing the BOPs to only 3,000 psi as well as not installing an SSV is an artifact from one of the other programs. Please disregard it. It is our intention to test the BOPs to 5,000 psi. -You request not to have a SSV since the well will not flow unassisted, but this is a gas well. Is the SSV request an artifact from another program? A: Yes, as stated above, the SSV request is an artifact. Please disregard it. -Do you plan to do a casing test in the pre rig work or prior to perfing? A: We will perform a casing test after plugging the presently perforated interval. -How the well will look after workover is not too difficult to imagine, but a drawing will help as I move it up the line. A: I will generate proposal drawings ASAP and get them to you. -What gas rate is expected? Will 2-3/8" tubing limit the production? ^: The gas rate is expected to be ~2MMSCFD which will not be limited by the 2-3/8" tubing. 1 of 4 5/3/01 10:05 AM FW: Swanson Workover Program -What zone/sand is the new completion in? A: The Tyonek 62-5 Sand SRU 234-15... -This plan is pretty straight forward. You have the BHP of the intended zone. Are there any others of concern? A: No, we'll just reperf the existing perforated intervals. -The present packer is a fair distance above the PBTD. Fill is mentioned, has it been tagged? A: No tag run has been made since this interval was perforated. However, the well makes sand so there is probably some amount of fill. -Do you plan to do a casing test in the pre rig work or prior to reperfing and gravel packing? A: No. The perforations are open and the producing pressure will be very Iow. -Although you have larger tubing planned for this well, will it limit production? A: No. There will not be enough rate from this well to see the tubing as a limitation. SRU 14A-33... -As I indicate in my comments...is there any intent or need to clean out the deeper intervals? A: No. We'll just acidize the existing perfs. -You are requesting not to have a SSV on a gas lifted completion. As nOted above, will adding the G perfs make the well capable of flowing? A: No. The BHP in the G-Zone is 1600 psi and will not allow the well to flow. -If the request for no SSV is apprOved, is there some shutdown mechanism on the gas lift? A: There are 2 manual valves at the surface for shutting in the gas lift. While discussing this question, the field supervisor and I decided that we are. uncomfortable with the possibility of a line leak occuring some time before somebody notices and turns off the gas lift gas supply. We therefore withdraw the request to eliminate the SSV. -What are the BHPs. A: Hemlock BHP = 1500 psi, G Zone BHP = 1600 psi I would appreciate some detailed information regarding the downhole equipment and the surface pumping unit. A: Photos and diagrams attached to this message. I can provide more technical data if you'd like, SCU 33A-8... How high Will the tie back be? A: The casing leak is suspected to be at the port collar at 7,332'. The tie-back liner will extend up to cover it, making the tie-back -2500' long. If the leak is found elsewhere, it will effect the length of the liner as the intent is to tie back from the existing TOL to just above the leak. 2 of 4 5/3101 10:05 AM .Swanson Workover Program Subject: Swanson Workover Program Date: Wed, 25 Apr 2001 03:02:30 EDT From: STMaunder@aol.com To: bill@fairweather.com CC: tom_maunder@admin.state.ak.us Bill, Doing a little homework. Funny, the phone doesn't ring near as much here. But the new office doesn't have plumbing problems either. But I digress... I have some questions with regard to the programs. I'll start off with my cryptic diary notes and expand on them. One big question. What rig is proposed? ~,~~.~ ~-~ ~ ~--~,- ~ SRU 14-15...(191-237)...(301-106)...proposal is to clean out the well, abandon the existing perforations and recomplete...request to test BOP to 3000 psi and also not to have a SSV...say that the well won't flow...plan to recomplete as a gas well...might need proposed drawing -What are the BHPs of the old interval and the new? Unless there is a possibility of a high pressure zone (there are a few out there), 3000 psi sounds appropriate. -You request not to have a SSV since the well will not flow unassisted, but this is a gas well. Is the SSV request an artifact from another program? -Do you plan to do a casing test in the pre rig work or prior .to perfing? -How the well will look after workover is not too difficult to imagine, but a drawing will help as I move it up the line. -What gas rate is expected? Will 2-3/8" tubing limit the production? -What zone/sand is the new completion in? ~ ~o~ .~ SRU 234-15...(160-041 )...(301.102)... propOsal is to clean out the well, reperf and gravel Pack the interval and run tubing...BHP stated at 2785 psi...request 3000 psi BOP test...need a new drawing...no mention of deleting -This plan is pretty straight forward. You have the BHP of the intended ,,~ zone. Are there any others of concern? -The present packer is a fair distance above the PBTD. Fill is mentioned, has it been tagged? -Do you plan to do a casing test in ~the pre rig work or prior to reperfing and gravel packing? -AIthoughproduction?yOu have larger tubing planned for this well, will it limit ~'~ SRU 14A-33...(162-017)...(301-103)...proposal is to cut tubing above top packer and clean out the well, not necessary or possible to clean out ~e~ deeper...run tubing shallower, acidize the existing perfs and add G zone perfs..:this is.an oil.well and presently will not flow unassisted...request is to not have a SSV...how do they propose to Sl...will adding the G perfs make the well flow? 1 of 2 -As I indicate in my comments...is there any intent or need to clean out.the deeper intervals? -You are requesting not to have a SSV on a gas lifted completion. As noted ~,l~Wi;ll I~UII ¥¥U| RUYt~I rlU~l above, will adding the G perfs make the well capable of flowing? -If the request for no SSV is approved, is there some shutdown mechanism on the gas lift? -What are the BHPs. The proposed rod pump wells have similar comments. I did talk with Steve Tyler regarding this proposal some time ago. I would appreciate some detailed information regarding the downhole equipment and the surface pumping unit. I have just copied my notes regarding these wells. I don't think they are too cryptic. If you need further clarification, please call SCU 33A-8...(172-017)...(301-103)...proposal is to clean out the well, repairing a 7-5/8" casing leak by runing a 5" tie back and equipping with a rod pump...makes same request to omit SSV...probably more appropriate on this well type...how high will the tie back be?. . .will ' it be fully cemented?...BOP and contingencies when using crane?...is there any liklihood that the Hemlock could flow after reperfing?...need BHPs...will tubing be anchored?...will gas be produced out of a casing valve? SCU 33-33...(176-056)...(301-105)...somewhat similar to 33A-8, plan to clean the well out and complete with rod pump...request relief on SSV as before...plan to use base oil for workover fluid...no reperf...why base oil on this one?...Hemlock and G zones already open in this well...any plan to test the casing? SCU 13-34...(unsure of permit number)...(301-104)...cleanout and equip with pump...plan to add G zone perfs...similar requests as before...plan to use 6% KCl for fluid Bill, thanks in advance for looking at these comments/questions. Please call to discuss. Tom 2 of 2 4/25101 9:49 AM FW: Swanson Workover Program Will it be fully cemented? A: Yes. BOP and contingencies when using crane? A: We plan to use a 2-ram stack consisting of: Top: 2-7~8", 1500 psi WP, 0 - 1-1/2", variable rod rams Btm: 2-1/2", Model LP-15, 0 - 1-1/2", variable rod rams Each well will use both rams while running the rods, with the bottom set being left on the well as a permanent part of the wellhead equipment (i.e., when it's all done, each well will have an LP-15 BOP left on it and the top ram will be left over for future use in running and pulling rods.). Is there any liklihood that the Hemlock could flow after reperfing? A: No, the BHP is only 1500 psi, not enough to lift the oil column. Need BHPs A: BHP = 1500 psi. Will tubing be anchored? A: Yes, see the attached gas anchor schematic. Will gas be produced out of a casing valve? A: Yes. SCU 33-33 Why base oil on this one? A: Base oil is being used because the G-Zone is very water-sensitive. Any plan to test the casing? A: No, the perforations are open and the producing pressure will be very Iow. ~ SCU 13'34 BHP = 1500 psi. Please call or write with any additional questions or comments. Regards, Bill I Name: 1100SlDE&FRTVIEWBELTOUT.jpg r~,~1100SIDE&FRTVIEWBELTOUT.jp.q~t Type: JPEG Image (image/jpeg) i! Encoding: base64 I Name: 1100SIDE&FRTVIEWBELTOUT.jpg F~-.~ 1100SIDE&FRTVIEWBELTOUT.jpgt Type: JPEG Image (image/jpeg) ' ~l Encoding: base64 ~ 1100SI DEVIEW.jP.q :I Encoding: base64 Name: 1100SIDEVIEW.jpg Type: JPEG Image (image/jpeg) 3 of 4 513101 10:05 AM FW: Swanson Workover Program IName: 900FOLDEDSHIPMENT.jpg ] I [-~900FOLDEDSHIPMENT. ip~ Type: Image (image/jpeg) JPEG Encoding: base64 . ~ 900WEIG HT BOX. jp.q Name: 900WEIGHTBOX.jpg Type: JPEG Image (image/jpeg) Encoding: base64 SwansonGas Anchor. doc Type: WINWORD File (application/msword)1 Name: Swanson Gas Anchor.doc Encoding: base64 4 of 4 5/3/01 10:05 AM Swanson River "Poor Boy" Gas Anchor Casing I 2-7/8" Tubing Rods RXBC Rod Pump Gas breaking out of production ISeating Nipple, 2-7/8" Cup Type w/2.280" ID IProduction 2-7/8" Ported Sub 1.660" Dip Tube w/10 rd Box x ~ MS btm 3 jts of 2-7/8" Tail Pipe Production I2-7/8" Otis "R" type Profile Nipple w/plug, 2.188" ID I2-7/8" Ported Sub IProduction LocSet Packer w/o Element JPEG image 768x1024 pixels 1 of 2 5/3/01 10:09 AM 1 4 10 103 2 10 -}' 1 10 0 10 -1 10 -2 10 -3 10 1000 Water Cum Oil Prod ( Mbbl ) Cum Gas Prod ( MMcf ) Cum Water Prod ( Mbbl ) 0.01 1990 01 0.001 Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7677 UNOCAL ) Dan R. Williamson Drilling Manager Tuesday, April 17, 2001 Ms. Julie Heusser, Commissioner AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Application for Sundry Approval; SCU 33A-8 Workover Swanson River Field, Alaska Dear Commissioner Heusser, Unocal Alaska Resources hereby submits an Application for Sundry Approval for its plan to repair Well SCU 33A-8 and convert it to a rod pump completion. SCU 33A-8 is a shut-in, Iow rate'~emlock oil producer that has a leak in the 7-5/8" production casing. The proposed workover will consist of pulling the old completion, locating the casing leak, ~.,,~cementing a 5" tie-back liner across the leak and re-competing with a rod pump c~o..~pletion. The Hemlock will be re-perforated before running rods. Because this well will not flow unassisted after the casing leak is repaired, Unocal requests approval to re-complete this well without a surface safety valve. The anticipated commencement of this workover is approximately June 15. Please find enclosed an Application for Sundry Approval (Form 403), a summary workover procedure and a wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 258- 3446. Sincerely, ~~,~ Dan Williamson Drilling Manager Enclosures cc: Bill Penrose STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL i. Type of Request: [ ] Aband'on [ ] Suspend [ ] Plugging [ ] Time Extension [X] Perforate [ ] Alter Casing [X] Repair Well [X] Pull Tubing [ ] Variance IX] Other* [ ] Change Approved Program [ ] Operation Shutdown [ ] Re- Enter Suspended Well [ ] Stimulate *Convert to rod pump 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF Or KB) UNOCAL ALASKA RESOURCES IX] Development 17' RKB [ ] Exploratory 3. Address [ ] Stratigraphic 7. Unit or Property Name 909 W. 9th Avenue, P.O. Box 196247, Anchorage, AK 99519-6247 [ ] Service Soldotna Creek Unit 4. Location of well at surface '/" ~ ~ 8. Well Number 1959' FNL, 1987' FEL, Sec. 8, T7N, R9W, SM 33A-8 At top of productive interval 9. Permit Number 2533' FSL, 1655' FEL, Sec. 8, T7N, R9W, SM 72-0017-1 At effective depth 10. APl Number 50-133-2024101 At total depth 11. Field and Pool 2430' FSL~ 1563' FEL~ Sec. 8~ T7N~ R9W~ SM Swanson River: Hemlock 12. Present well condition summary Total depth' measured 11,086 feet ~ Plugs (measured) 10,870' (TOC, 19' cmt plug on bridge plug) true vertical 10,855 feet Effective depth: measured 10,870 feet Junk (measured) None true vertical 10,659 feet Casing Length Size Cemented M D TVD Structural N/A Conductor 38' 18" 55' 55' Surface 3,315' 10-3/4" 3,332' to surface 3,332' 3,332' Intermediate 9,614' 7-5/8" 643 sx in 2 stages 9,631' 9,537' Production N/A Liner 1,253' 5-1/2" 1.253' to liner top 11,178' 10,939' Perforation depth: measured 10,836'-10,856' and 10,861'-10,871' ~'~'""~'~ ,~ ~ ~, :~. - ,,, ,, _ true vertical 10,629'-10,647' and 10,651'-10,660' ./.~o,O ,, ,.,,..,....,~!!. :...' Tubing (size, grade and measured depth) 2-7/8", L-80 at 10,783' ' q,,~.~,,:;,.~. ~ ~' ' "~' ~'Oh Packers and SSSV (type and measured depth) 5-1/2" Baker Model F-1 permanent packer at ~ ~,~o~ .... , ..... ,,,,.?/~,,. 13. Attachments iX] Description of Sumary Proposal '" [ ] Detailed Operations Program [ ] BOP Sketch , ,,, ,,, , 14. Estimated date fo~ commencing operation ' 15. Status' Of well classification as: 6/15/01 , , 16. If proposal was verbally approved [X] Oil [ ] Gas [ ] Suspended ..... Name of approver Date Approved Service .... 1'7. I hereb/y~.~rtify th.at thee f~r~going is true and correct to the best of m~ knowledge ' Sign~,)/" ~ ~. Title ~)l~'/t ~,~..~/~ Date .~/'~, ""'/.~.-'~/ - - -,- r " '~ Con'mission I.l~e Only Conditions of Approval: Notify Commission So representative may witness '~.~,~ .~ ~>~ ~.~-~-.- IApproval No. '~ Plug integrity BOP Test ~ Location Clearance ' ~ Subsequent form required 10- ~,t ~.~--~ ~, ~ ~-~ ~,~'~s'~" Mechanical Integrity Test . Gll~, SIGNED BY' , Approved by order of the Commission ,, ~!~ ~ ~,,a~,, Commissioner , Date (~',,Fp ~ [ Form 10-403 Rev. 06/15/88 51icate Unocal Alaska Business Unit Sxvanson River Field Well # SCU 33A-8 AFE # Prepared by: WJP Date: 3/01 ~ Estimate for Non-drilling AFEs (Cap Recomp, SWR, Abandonment) No. Preliminary' Procedure Time CUM cuM Estimate Time Time (Hours) (Hours) (Days) i Prep Well for Workover Test wellhead Attempt Coiled Tubing Cleanout in Tubing and AnnUlus '" Use Slickline and Pumper to Clean Out Annulus Workover 1 MIRU Workover Rig. 72 72 3.0 2 Set BPV, N/D Tree, N/U BOPE and Test 15 87 3.6 3 R/U ACRS, Cut Tbg, R/D APRS 4 9] 3.8 4 M/U Landing Joint, Pull Tbg Hgr to Floor, Circulate ..Well 3 94 3.9 5 POH and L/~.. Tubing and Jewelry 15 109 4.5 6 P/U Drill Pip.e and Overshot and RIH. 20 129 5.4 7 Eng. age Stub: Attempt to Rotate.Tbg Anchor, POH ... 8 137 5.7 8 !Make 7-5/8" Scraper Run to 5" Lnr Top, POH 12 149 6.2 9 RIH w/RTTS, Locate Casing Leak in 7-5/8" Csg, POH 12 161 6.7 10 IRun and Cement Tie-Back Liner to Cover Casing Leak 24 185 7.7 1..1 Make Cleanout Run in 7-5/8" C..s.g, POH ... 6~' 191 8.0 12 tS'et Storm Pkr, N/D BOPE, Add Spool to Wellhead, N/U & T~st BOPE 18 209 8.7 1'3 M,ake Cleanout Run in 5-1/2" Liner, Displace Well tO .Clean Brine, POH 18 227 9.5 14 RIH w/Slickline, Pull Plug from T.bg Tail , 4; 231 9.6 15 P/U and RIH w/2-7/8" Completion to 10,700; .. 24 255 10.6"' 1,6 Set,BPV, N/D BOPE, N/UTree, TestTree 12 ..267 11.1 17 RDMO W0rkover Rig ..... 0 267 11.1 I I I III I Post Rig Work MIRU Slickl'.me Unit, .Tag Fill if Fill Covers Perfs, MIRU CTU and Clean Out to PBTD . .' . . '" MIRU SWS, Reperforate Hemlock, RDMO SWS Run Rod Pump and Rods Us'rog 50-Ton Crane [Subtotal (Days) LosS/Trble'Thne (11%) T°tal Project Days .. i i i i ii i i iiiiii ii i i 11.13 1.22 Note: Loss, Trouble, Unplanned is based on 11%. Also, the risked troubled costs were included in the AFE costs. 12.35 SCU 33A-8 AFE Est Page I of I 4/5/01 UNOCAL 17' SIZE 18" 10-3/4" 7-5/8" 5-1/2" Tubing 2-7/8" Soldotna Creek Unit Well No. 33A-8 Actual Completion 8/18/98 CASING AND TUBING DETAIL GRADE CONN ID . . 40.5 - 33.7 N-80 BTC 26.4 N-80 BTC 33.7 N-80 BTC x 8rd 29.7 N-80 8rd 33.7 S-95 8rd 20 N-80 6.4 L-80 BTC SC TOP BTM. Surface 55' 10.050 Surface 3,332' 6.765 15' 85' 6.969 85' 3,940' 6.765 3940' 3,958' 6.875 3,958' 6,905' 6.765 6,905' 9-~3+' 4.778 9,631' 11,178' 2.441 17' 10,764' A Smsa Co)la' ~ 7,332' SWS Posi Sci Plug ~ 10,889' 11 12 14 15 16 H-2 H-4 H-5 H-5 NO. JEWELRY DETAIL Depth I__D_D .OD 17' - - 1' 2,239' 2.347 4.750 2 . 4,032' 2.347 4.750 3 5,540' '2.347 4.750 4 6,729' 2.347 4.750 5 7,757' 2.347 4.750 6 8,593' 2.347 4.750 7 9,180' 2.347 4.750 8 9,727' 2.347 4.500 9 10,242' 2.347 4.500 10 10,725' 2.347 4.500 11 10,763' 2.375 4.00 !rein Shaffer, 3-1/2", 5M, Single Tubing Hanger CIW Type 'H' BPVP McMurry Maceo, 2-7/8" SMO-1 GLM, BK-2 McMurry Mae¢o, 2-7/8'.' SMO-1 GLM, BK-2 McMurry Ma~¢o, 2-7/8" SMO-1 GLM, BK-2 McMurty Maceo, 2-7/8" SMO-1 GLM, BK-2 McMurry Mae¢o, 2-7/8" SMO-1 GLM, BK-2 McMurty Maeco, 2-7/8" SMO-1 GLM, BK-2 MCMurry Mae¢o, 2-7/8" SMO-1 GLM, BK-2 McMurry Ma¢¢o, 2-7/8" SMOR-1 GLM S.C. BK-2 McMutry Ma¢¢o, 2-7/8" SMOR-1 GLM S.C. BK-2 McMutry Maeeo, 2-7/8" SMOR, 1 GLM S.C. BK-2 Anchor Seal Assembly, E-22, 2.77' 12 13 14 15 16 17 10,739' 3.000 4.437 10,741' - 10,747' - - 10,778' · 2,250 " - 10,779' 10,783' The following were set on E-Line 10131/90. Packer, 2-7/8 x 7-5/8" Baker Mod. 'F-I' Millout Extension, 5.63' Long 1 Jr. 2-7/8" 6.5#, N-80, EUE 8 rd Otis 'XN' Nipple, 2-7/8" EUE 8rd, 2.313 wi 2.25" 1 Pup Jr., 2-718", 6.5#, N-80, EUE 8rd WLREG Notes: A B Stage Collar at 7,332' Sclumberger Posi Set Plug at 10,889' wi 19' of cement. PERFORATION HISTORY ., 711/93 H-2 10,836' 10,856' 20' 4 7/I/93 H-2 10,861' 10,871' 10' 8 , . . , 1(1/90 I-I-4 10,914' 10,930' 16' 4 Isdated .. 10/90 H-5 10,938' 10,946' 8' 4 Isdated I0/90 1-1-5 10.062: . 1.0.qT0' .8' 4 I~lated PBTD = 10,889' TD = 11,086' MAX HOLE ANGLE = 27 deg. SCU 33A-8 Act Draw DRAWN BY: tcb REVISED: 8/20/98 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192) PHONE: (907) 279-1433 FAX: (907) 276-7542 December 6, 1999 Dan Williamson Drilling Manager UNOCAL P O Box 196247 Anchorage, Alaska 99519 Re: Permit Number Ltr Dated October 11, 1999 Dear Mr. Williamson: AOGCC history database had a problem with six duplicate permit numbers that occurred several years ago. The current listed well permits were not issued by AOGCC. We added a seventh digit to the permit number and inturn created a database problem. I corrected this situation by changing the permit number to a new Y2K seven-digit permit number. The new Y2K permit number (first six digits) should be annotated on all reports submitted to AOGCC for these named wells in the future: Current Permit Well name 66-0056-1 Granite Pt St 31-14RDi 100-265-0 66-0056-2 Granite Pt St 31-1.4RD2 100-266-0 74-0026-1 Soldotna Ck Unit 32B-09 100-267-0 72-0017-1 Soldotna Ck Unit 33A-08 100-268-0 80-0107-1 Soldotna Ck Unit 41B-09 100-269-0 68-0044-1 Trading Bay Unit G- 12RD 100-270-0 New Y2K Permit Number The permit number changes were made December 5, 1999 by AOGCC. Sincerely, Steve McMains Statistical Technician O STATE OF ALASKA ALASKA IL AND GAS CONSERVATION MMISSION 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) Union Oil Company of Califomia (UNOCAL) Development: X 154' RKB 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 1959' FNL, 1,987' FEL, Sec. 8, T7N, R9W, SM SCU 33A-8 At top of productive interval 9. Permit number/approval r~mber 2,533' FSL, 1,655' FEL, Sec. 8, T7., R9W,SM ~'~ ~ '" (~ / ¢7 '"'/ ~/~ At effective depth 10. APl~ number 2,457' FSL, 1,587' FEL, Sec. 8, T7N, Rgw, SM 50- 133-20241-01 At total depth 11. Field/Pool 2,430' FSL, 1,563' FEL, Sec. 8, T7N, Rgw, SM Swanson River Field/Hemlock 12. Present well condition summary Total depth: measured 11,178' feet Plugs (measured) 10,889-10,910' MD true vertical 10,935' feet Effective depth: measured 10,889' feet Junk(measured) ORIGINAL true vertical 10,670' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 58' 18" Driven 22' 22' Surface 3,332' 10-3/4" 150 sx 3,332' 3,332' Intermediate Production 9,993' 7-5/8" 743 sx 9,993' 9,864' Liner 1,547' 5-1/2" 360 sx 9,631 '-1 t, 178' 9,631 '-10,935' Scab Liner Perforation depth: measured true vertical 10,620'-10,640'; 10,648'-10,635' Tubing (size, grade, and measured depth) ~1 .,,; .,,,....: 2-7/8",604#, L-80, Buttress Special Clearance · Packers and SSSV (type and measured depth) Baker Model F-1 ~ 10,762' MD 13. Stimulation or cement squeeze summaw N/A Inte~als treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily AvemRe Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7/16/98 291 2 mmcfd 64 550 500 Subsequent to operation 9/28/98 297 1.3 mmcfd 56 700 275 15. Attachments: 16. Status of well classification as: Copies of Logs and Su~eys run: Daily RepoA of Well Operations: ~ ' Oil: X Gas: Suspended: Se~ice: 17. I hereby ceAify that the foregoing is true and correct to the best of my knowledge: ' r ,~, Sign · D n Williamson Title: Drilling Manager Date: Form 10-404 Rev 06/15/88 suBt~ )UPLICATE UNOCALe Orig. RKB = 17' A Stage Collar ® 7,332' 11 12 13-- 14 15 16 SWS Posi Set r~ug @ B 10,889' H-2 H-4 H-5 H-5 SIZE Soldotna Creek Unit Well No. 33A-8 Actual Completion 8/18/98 CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. 1 8" 10-3/4" 7-5/8" 5-1/2" Tubing 2-7/8" 40.5 - - 33.7 N-80 BTC 26.4 N-80 BTC 33.7 N-80 BTC x 8rd 29.7 N-80 8rd 33.7 S-95 8rd 20 N-80 6.4 L-80 BTC SC Surface 55' 10.050 Surface 3,332' 6.765 15' 85' 6.969 85' 3,940' 6.765 3940' 3,958' 6.875 3,958' 6,905' 6.765 6,905' 9,631' 4.778 9,631' 11,178' 2.441 17' 10,764' JEWELRY DETAIL NO. Depth ID OD Item 17' 1 2,239' 2.347 4.750 2 4,032' 2.347 4.750 3 5,540' 2.347 4.750 4 6,729' 2.347 4.750 5 7,757' 2.347 4.750 6 8,593' 2.347 4.750 7 9,180' 2.347 4.750 8 9,727' 2.347 4.500 9 10,242' 2..347 4.500 10 10,725' 2.347 4.500 11 10,763' 2.375 4.00 12 10,739' 3.000 4.437 13 10,741' - 14 10,747' - 15 10,778' 2.250 - 16 10,779' 17 10,783' Shaffer, 3-1/2", 5M, Single Tubing Hanger CIW Type 'H' BPVP McMurry Macco, 2-7/8" SMO-1 GLM, BK-2 McMurry Macco, 2-7/8" SMO-1 GLM, BK-2 McMurry Macco, 2-7/8" SMO-1 GLM, BK-2 McMurry Macco, 2-7/8" SMO-1 GLM, BK-2 McMurry Macco, 2-7/8" SMO-1 GLM, BK-2 McMurry Macco, 2-7/8" SMO-1 GLM, BK-2 McMurry Macco, 2-7/8" SMO-1 GLM, BK-2 McMurry Macco, 2-7/8" SMOR-1 GLM S.C. McMurry Macco, 2-7/8" SMOR-1 GLM S.C. McMurry Macco, 2-7/8" SMOR-1 GLM S.C. Anchor Seal Assembly, E-22, 2.77' BK-2 BK-2 BK-2 The following were set on E-Line 10/31/90. Packer, 2-7/8 x 7-5/8" Baker Mod. 'F-I' Millout Extension, 5.63' Long 1 Jr. 2-7/8" 6.5#, N-80, EUE 8 rd Otis 'XN' Nipple, 2-7/8" EUE 8rd, 2.313 w/2.25" N.G. 1 Pup Jr., 2-7/8", 6.5#, N-80, EUE 8rd WLREG Notes: A B Stage Collar at 7,332' Sclumberger Posi Set Plug at 10,889' w/19' of cement. PERFORATION HISTORY Interval Ae. em~ Date Zone Top Btm Ant spf Con~nents 7/1/93 H-2 10,836' 10,856' 20' 4 - 7/1/93 H-2 10,861' 10,871' 10' 8 10/90 H4 10,914' 10,930' 16' 4 Isolated 10/90 H-5 10,938' 10,946' 8' 4 Isolated 10/90 H-5 10,962' 10,970' 8' 4 Isolated ?BTD = 10,889' TD = 11,086' MAX HOLE ANGLE = 27 deg. SCU 33A-8 Act Draw.doc DRAWN BY: tcb REVISED: 8/20/98 Workover Summary Soldotna Creek Unit, Well 33A-8 8/12/98 - 8/20/98 DAY 1 (8/12198) RU SLICKLINE. TEST LUBRICATOR. RIH W/2.3" GAGE RING. TAG "XN" NIPPLE AT 10,795'. POOH. RIH W/2-1/2 .... XN" PLUG. SET DOWN IN SLIDING SLEEVE AT 10,695' UNABLE TO GET THROUGH. POOH W/O PLUG. RIH W/2-1/2" GS PULLING TOOL. LATCH AND RETRIEVE PLUG. RIH W/2-1/2" PLUG AND SET IN "XN" AT 10,795'. RIH WITH EXTENDED PRONG AND SET IN PLUG. PRESSURE TEST TO 1,500 PSI. GOOD TEST. POOH. RIH AND SHIFT SLIDING SLEEVE AT 10,695'. DAY 2 (8/13/98) MIRU NORDIC RIG NO. 5. BLEED TUBING AND ANNULUS TO ZERO. WELL DEAD. CIRCULATE 445 BBLS OF LEASE WATER TO DISPLACE TUBING AND ANNULUS. INSTALL BPV. DAY 3 (8114/98) CONT. RIG UP. ACCEPT RIG AT 12:00 HRS. NIPPLE DOWN TREE. NIPPLE UP 7-1/16", 5M BOPE. DAY 4 (8/15/98) CONT. NIPPLE UP. PULL BPV INSTALL TWO WAY CHECK. TEST BOP. WITNESS WAIVED BY AOGCC. TEST 250/3,000 PSI. UNABLE TO GET TEST ON 3-1/2" RAMS. CHANGE SAME AND RE-TEST 250/3,000 PSI. GOOD TEST. PULL TWO WAY CHECK. PULL ON TUBING HANGER TO 92K. ROTATE TUBING TO RIGHT TO RELEASE E-22 ANCHOR FROM PACKER. PULL HANGER TO FLOOR AND LAY DOWN SAME. BREAK CIRCULATION W/LEASE WATER. POOH LAYING DOWN 3-1/2" X 2-7/8" COMPLETION. DAY 5 (8/16/98) CONT. POOH W/3-1/2" X 2-7/8" COMPLETION. FULL RECOVERY. CHANGE PIPE RAMS TO 2-7/8". TEST 250/3,000 PSI. GOOD TEST. PREP TO RUN NEW 2-7/8" GAS LIFT COMPLETION. MU E-22 ANCHOR ASSEMBLY, 2-7/8" TUBING AND GAS LIFT MANDRELS AS PER PROCEDURE AND RIH. DAY 6 (8/17/98) CONT. RIH WITH NEW 2-7/8" GAS LIFT COMPLETION. RUN TO TOP OF PACKER. RU E- LINE TO RUN CCL CORRELATION LOG FOR SPACE OUT. UNABLE TO ACERTAIN CORRELATION. PREMATURELY LATCH ANCHOR INTO PACKER. ATTEMPT TO ROTATE OUT. NO-GO. PRESSURE TEST TUBING AND PACKER TO 500 PSI. FOR 15 MIN.. OK. RU SLICKLINE TO RUN GAGE RING TO CONFIRM TUBING NOT OVER TOURQED. RU SLICKLINE. RIH W/2.313" GAGE RING TO 10,790'. POOH. PRESSURE TEST TUBING AND PACKER TO 1,500 PSI FOR 15 MIN. GOOD TEST. DRAIN BOP'S. DISCONNECT AND RAISE. PULL 111K ON TUBING. INSTALL SLIP BOWL AND SLIPS ON TUBING SPOOL. DAY 7 (8/18198) BREAK OUT LANDING JOINT AND INSTALL HANGER. INSTALL LANDING JOINT. PU TUBING AND REMOVE SLIPS AND BOWL. LAND HANGER IN TUBING SPOOL. SET DOWN BOP'S AND NIPPLE DOWN. INSTALL SEAL FLANGE AND TREE. TEST TO 5,000 PSI. GOOD TEST. REMOVE TWO WAY CHECK. COMMENCE RIG DOWN AND DE-MOB. DAY 8 (8120198) RU SLICKLINE. TEST LUBRICATOR, O-RING LEAKING. REPAIR SAME. PRESSURE TEST TO 4,000 PSI. GOOD TEST. RIH W/1-5/8" JDC PULLING TOOL. LATCH AND PULL PRONG AT 10,790'. GAIN 100 PSI ON TUBING. POOH. RIH WITH 2-1/2" GS PULLING TOOL. PULL PLUG IN "XN" NIPPLE AT 10,790'. POOH. RD SLICKLINE. RETURN WELL TO PRODUCTION. Unocal Corporation P.O. Box 196247 Anchorage, Alaska gg51g 907-263-7660 UNOCAL ) Dan Williamson Drilling Superint~nden{ August 14, 1998 Dear Mr. Wondzell, Mr. Blair Wondzell Alaska O&G Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-1392 As per our conversation this morning, Unocal requests a variance for Soldotna Creek Unit Well No, 33A-8, a Hemlock oil producer. The well has 9,375' of 3-1/2" tubing and 1,375' of 2-7/8" which is slated to be pulled for replacement. The well currently has a plug that is set in an 'XN' Nipple at 10,790' (Below a permanent packer at 10,750') which will be left in.the hole to isolate the productive H-2 sand. The well has been circulated to kill weight fluid and the plug tested to 1,500psi. Unocal requests a variance allowing the use of an 11", 5M Double Gate dressed with 3-1/2" and blind rams, utilizing the 11", 5M annular for pressure control when pulling the 2-7/8". If you should have any further questions regarding this request please contact me at 263-7677. Thank you for your attention to this matter. ~_~ Sincerely, Dan Williamson Drilling Superintendent L/l 'd 9090'ON 'd~JOO lVOONn V4dbt'~ 866L 'tb':~nv Unocal North Americar~,,' Oil & Gas Division ~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) /\ Alaska Region August 13, 1993 Mr. Russ Douglas Commissioner AOGCC 3301 Porcupine Dr. Anchorage, Alaska 99504 Dear Russ: This is to notify you that on July 19, 1993 well SCU 33A-8 in Swanson River Field was perforated in the H2 sand from 10,86!' - 10,871' with Schlumberger Pivot Guns at four shots per foot and 180° phasing. Ralph P. Holman Engineer Technician STATE OF ALASKA · ALASKA's': . AND GAS CONSERVATION CO~ SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate X_ ~.'~',~..}~ Pull tubing m Alter casingm Repair well __ Pull tubing __ Other__ G ,,, 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or I~i,'.':i.,. Unocal Devek)pment _~ RKB: 1.54', GL: 128' ~"' ..... 3. Address araagraphi~ __ 7. Unit or Property name \~' P.O. Box 196247 Anchorage, Alaska 99519-6247 Serace Solclotna Creek Unit 4. Location of well at surface 8. Well number 1959' FNL, 1987' FEL, Sec. 8, T7N, R9W, SM SCU 33A-8 At top of productive interval 9. Permit number/approval number 2.5,33' FSL, 1655' FEL, Sec. 8, 'FTN, R9W, SM 72-0017-1 At effective depth 10. APl number 2427' FSL, 1587' FEL, Sec. 8, "I'TN, R9W, SM 50-133-20241-01 At total depth 11. Field/Pool 2430' FSL, 1563' FEL, Sec. 8, T7N, R9W, SM Swanson River/Hemlock 12. Present well condition summary Total depth: measured 11178 feet Plugs (measured) true vertical 10935 feet Effective depth: measured 10889 feet Junk (measured) true vertical 10670 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 58' 18" D riven 58' 58" Surface 3332' 10-3/4" 2218 cu. ft. lead 3332' 3332' Intermediate Production 9993' 7-5/8" 743 sx class G 9993' 9864' Liner 1547' 5-1/2" 74 bbls. class G 9631'-11178' 9631'-10935' Perforation depth: measured 10861'-10871' true vertical 10645'-10654' Tubing (size, grade, and measured depth) 3-1/2" (iD 9375' & 2-7/8" from 9375'-10805' Packers and SSSV (type and measured depth) Baker model F-1 @ 10762' ~ ~ C F ~V ~ ~ 13. Stimulation or comont squoeze summary Intervals treated (measured) N0¥ "3 199; .~Jaska 0ii & ¢~as Cons, C0mmissi0~ Treatment description Including volumes used and final pressure Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 201 10781 6 1400 1300 Subsequent to operation 302 17391 3 1650 1500 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 her~,I.ce/~,~ng is true and correct to the best of my knowledge. Signed~"~~~~J, Title~[tL~l./~ [~~q~"'~ Date ~q,O~"[, Cj~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ~51 AI I-- L)i- ALA~SKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLIC ' ON FOR SUNDRY AP(' 1OVALS 1. Type of request: Abandon __ Suspend __ Operations shutdown __ Re-enter suspended well__ Alter caslng__ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate X_ Other__ 2. Name of Operator Union Oil Company of Califomla (Unocal) 3. Address P.O. Box 196247 Anchorage, Alaska 99619-6247 4. Location of well at surface 1959' FNL, 1987' FEL, Sec. 8, T7N, R9W, SB&M At top of productive inten/al 25,33' FSL, 1655' FEL, Sec. 8, 'lTN, R9W, SB&M At effective depth 2427' FSL, 1587' FEL, Sec. 8, T7N, R9W, SB&M At tolal depth 2430' FSL, 1563' FEL, Sec. 8, T7N, R9W, SB&M J5. Type of Well: 6. Datum elevation (DF or KB) RKB: 154', GL: 128' 7. Unit or Property name $oldotna Creek Unit 8. Well number SCU 33A-8 9. Permit number ~ ?.z-~l~-I ~,¢~. 10. APl number 50-133 -20241-1 11. Field/Pool Swanson River/Hemlock feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11178 10935 10889 1 O670 feet feet feet feet Plugs (measured) Junk (measured) 10889 - 10910 ORI61NAL Casing Structural Conductor Surface Intermediate Production Uner Perforation depth: measured Length Size 58' 18" 3332' 10-3/4" 9993' 7-5/8" 1547' 5-1/2" 10864'- 10870' (H2) true vertical 10848'- 10653' (H2) Tubing (size, grade, and measured depth) 3-1/Z' @ 9375' & 2-7/8' from 9375'-10805' Packers and SSSV (type and measured depth) Baker model F- 1 @ 10762' Cemented Measured depth Driven 58' 2218 cu. ft. lead 3332' & 15o sx class ~ 743 sx class G 74 bbls. class G True vertical depth 8 9993' 9864' 9631'-11178' 9631'-10935' RE.EEIVED JUN 2 8 199 Alaska Oil & Gas Cons. Commissio~t Anchorage 13. Attachments Description summary of proposal __ Delailed operations programX__ BOP sketch 14. Estimated date for commencing operation July 6, 1993 16. If proposal was verbally approved Name of approver I 5. Status of well classification as: Oil X_ Gas __ Date approved Service Suspended 17. I herel~(/'~gertify/ljhat th~fg(ego, ing~s tru_e.,a0d correct to the best of my knowledge. · FOR COMMISSION USE ONLY Conditions of approval: NoUfy Commission so representaUve may witness Plug Integrity _ BOP Test Location clearance Mechanical Integrity Test_ Subsequent form required 10- Approved by the order of the Commission ORIGINAL SIGNED RUSSELL A. DOUGLASS q,o .../ I Approval No. ..'~,pprove. d Copy / / Returned Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE June 24, 1993 Swanson River Well SCU 33A-8 Perforating Procedure 1. Obtain a well test. . Shoot a fluid level in tubing to verify liquid level is several hundred feet above perforated interval. Load tubing with crude if necessary. 3. Hold safety meeting with appropriate personnel. 4. Rig up electric line unit. (A pump-in sub is required on lubricator) 5. Pressure test lubricator to 3500 psi for five minutes. 6. Shut down all welding and radio transmissions. , RIH and perforate intervals as instructed by Unocal representative. (When gun is 200' below surface, welding and radio transmissions may resume.) , POOH. (When gun is 200' below surface, shut down all welding and radio transmissions.) 9. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH MEASURED TVD FEET H2 10836-10854 10624-10639 18 H2 10862-10870 10645-10652 8 TOTAL 26 Alaska 0il & ~as Cons. Commission, 'Anchorage Unocal North America: Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITYAL January 22, 1993 TO: Larry Grant FROM: 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION Ralph Holman P O Box 196247 Anchorage AK 99519-6247 ALASKA REGION Transmitting as Follows: Swanson River Unit 1 - Sub-Surface Directional Survey- SCU 33A-8 7 ~"]7"q Kenai Gas Field- KU14-4 2 - Temperature Log Gamma Ray 1 - Spectral Analysis PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUMENT TRANSMITTAL BY SIGNING AND RETURNING ONE CQPY. THANK YOU. DATED: / , ..... , ,._ ,. GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY 8CU 33A-8 WELL NAME. .. .... SWANSON RIVER UNIT, KENAI, ALASKA eeMemmmmmemmmem~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ~OCATION AL1090D35 GYRO/MWD io/2i/9o JOB NUMBER TYPE SURVEY DATE TITLE SIGNATURE DEPTH INTERVAL FROM TO to/oz/9o DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A.SUB-SURFACE SUI~VEY OF YOUR WELL WE HAVE RETAINED A COPY OP YOUR ~UI~VE¥ REPORT IN OUR FILES FOR YOUR CONVENIF/qCE~ HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORW~RDED TO YOU ON b~~ WRITTEN REQUEST, ALL SURVEYS ARE KEPT IN A LOCKBD FILE AND ARE HELD IN STRICTEST CONFIDENCE. ~;~'". ':.~, ~ · -tF GREAT LAND DIRECTIONAL DRILLING, INC. Client .... : ARCO ALASKA, INC. Field ..... : SWANSON RIVER UNIT Well ...... : SCU 33A-8 8ection at: S,27.01,E Engineer..: TOM DUNN Computation...: RADIUS OF CURVATURE Survey Date...: 10/21/90 RKB Elevation.: 154.00 ft Reference ..... : AIA090D35 ~agnetic Dcln.: 24.00 E MEAS INCLN VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DEPTH ANGLE BKB SUB-SEA DI STNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 0 0.00 0.0 -154.0 0.0 N 0.00 E 0.0 N ~' 0.0 E 0.0 N 90.00 E 0.00 100 0.28 100.0 -54.0 -0.2 S 89.50 W 0.2 N 0.2 W 0.2 N 45.25 W 0.28 200 0.25 200.0 46.0 -0.4 ~ 77.50 W 0.1 N 0.6 r~ 0,6 N 80.54 W 0.03 300 0.25 300.0 146.0 -0.5 S 81.60 W 0.0 N 1.0 W 1.0 N 88.72 ~ 0.00 400 0.17 400.0 246.0 -0.7 N 78.00 W 0.0 N 1.4 W 1.4 N 88,59 W 0.08 7 500 0.67 500.0 346.0 -1.3 N 42.20 W 0.4 N 7 600 0.32 600.0 446.0 -2.! N 16.70 W 1.1 N 7 700 0.43 700.0 546.0 -2,6 N 40.90 E 1.8 N 7 800 0.70 800.0 646.0 -3,0 N 36.60 E 2.5 N 7 900 0.62 900.0 746.0 -3.7 N 17.20 E 3.5 N 7 1000 0.77 1000.0 846.0 7 2100 0.88 1100.0 946.0 7 1200 0,73 1199.9 1045.9 7 1300 0.93 1299.9 1145.9 7 1400 0.73 1399.9 1245.9 7 1500 0.77 1499.9 ~345.9 7 1600 0.65 1599.9 1445.9 7 1700 0.45 1699,9 1545.9 7 1800 0.60 1799,9 1645.9 7 1900 0.58 1899.9 1745.9 -4.5 N 26.70 -5.6 N 3.80 -6.8 N 15.60 -7.9 N 3.00 -9.2 N 4.70 -10.4 N 11.50 -11.5 N 25.70 -12.5 N 41.10 -13.2 N 85.60 -13.9 N 67.10 4.7N 6..1N 7.5N 8.9 N 10.3 N 11.6 N 12.8 N 13.6 N 14.0 N 14.3 N 2.0 W 2.5 W 2.3W 1.7W 1.2 W 0.7 W 0.5 'W 0.3# 0.1W 0.1W 0.0 W 0.2W 0.TV 1.5 W 2.5W 2.1 N 79.03 W 0.50 2.7 N 65.08 W 0.35 2.9 N 52.95 W 0.11 3.0 N 34.07 Iir 0.27 3.7 N 18.52 W 0.08 4.7 N 8.94 W 0.15 6.1 N 4.26 W 0.11 7.5 N 2.37 W 0.15 8.9 N 0.48 W 0.20 10.3 N 0.53 W 0.20 11.6 N 0.09 W 0.04 12.8 N 0.76 W 0.1Z 13.7 N 2.92 W 0.20 14.1 N 6.08 W 0.15 14.5 N 9.89 W 0.02 2000 0.33 1999.9 1845.9 -14.4 N 74.30 14.5 N 3'.2 W 14.9 N 12.56 W 0.25 m i i ~D C C 'Survey Codes: ?/GYRO SCU 33A-8 Page 2 10/22/90 RECORD OF SURVEY S MEAS INCLN VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES CLOSUI~E DL C DEPTH ANGLE BKB ~UB-SEA DISTNCE BEARING FROM-WELL-HEAD DI STNCE BEARING /100 7 2100 0.35 2099.9 1945.9 -14.8 N 86.10 W 14.6 N 3.8 W 15.1 N 14.63 W 0.02 7 2200 0.35 2199.9 2045.9 -15.2 N 73.70 91 14.8 N 4.4 W 15.4 N 16.69 W 0.00 -'~'~ 7 2300 0.42 2299.9 2145.9 -15.7 N 56.50 W 15.0 N 5.0 W 15.9 N 18.50 W 0.07 7 2400 0.33 2399.9 2245.9 -16,3 N 47.40 W 15.4 N 5.5 W 16.4 N 19.76 1; 0.09 7 2500 0.37 2499.9 2345.9 -16.8 N 57.60 91 15.8 N 6.0 W 16.9 N 20.88 W 0.04 7 2600 0.25 2599.9 2445.9 -17.3 N 65.40 91 16.1 N 7 2700 0.47 2699.9 2545.9 -17.7 N 88.50 91 16.2 N 7 2800 0.62 2799.9 2645.9 -18.3 N 68.70 W 16.4 N 7 2900 0.30 2899.9 2745.9 -18,9 I 58.70 W 16.7 N 7 3000 0.12 2999.9 2845.9 -19.0 S 53.10 W 16.7 N 6.5W 7.1 91 8.0W 8.8W 9.1 W 17.3 N 22.04 W 0.12 17.7 N 23.70 If O.22 18.3 N 26.13 W 0.15 18.9 N 27.61 19.0 N 28.55 I~ 0.18 IT1 I I ~c~ c z c 7 3100 0.10 3099.9 2945.9 -19.0 S 72.90 W 16.6 N 7 3200 0.05 3199.9 3045.9 -19.1 N 74.10 W 16.6 N 7 3300 0.12 3299.9 3145.9 -19.2 N 30.20 W 16.7 N 7 3400 0.12 3399.9 3245.9 -19.4 N 64.90 W 16.9 N 7 3500 0.05 3499.9 3345.9 -19.4 ~ 54.60 E 16.8 N 7 7 7 7 3600 0.33 3599.9 3445.9 -19.2 N 65.00 E 16.8 N 3700 0.40 3699.9 3545.9 -19.3 N 45.30 E 17.1 N 3800 0.37 3799.9 3645.9 -19.4 N 61.10 E 17.5 N 3900 0.57 3899.9 3745.9 -19.6 N 37.90 ~ 18.0 N 4000 0.32 3999.9 3845.9 -20.1 N 13.50 E 18.7 N 9.3I; 9.4 W 9,5 1; 9.71; 9.7 W 9.4W 8.91; 8.31; 7.7 I; 7.4W 19.1 N 29.13 W 0.02 19.3. N 29.47 If 0.05 19.2 N 29.63 If 0.07 19.4 N 29.82 W 0.00 19.4 N 30.08 W 0.07 19.2 N 29.31 W 0.28 19.3 N 27.43 W 0.07 19.4 N 25.48 W 0.03 19.6 N 23.18 ~/ 0.Z0 Z0.1 ti 21.53 W 0.25 z 4100 0.80 4099.9 3945.9 -20.8 N 12.80 E 19.7 N 4200 1.00 4199.8 4045.8 -22.2 N 12.10 W 21.3 N 4300 0.97 4299.8 4145.8 -23.9 N 21.40 W. 22.9 N 4400 0.97 4399.8 4245.8 -25.5 N 2.10 W 24.5 N 4500 1.32 4499.8 4345.8 -27.3 N 0.30 W 26.5 N 4600 1.18 4599.8 4445.8 -29.3 N 7.90 W 28.7 N 7.2W 7.2~r 7.7W 8.0If 8,2W 21.0 N 20.01 1; 0.48 22.4 N 18.63 Ii' 0.20 24.1 N 18.49 1; 0.03 25.8 N 18.05 W 0.01 27.7 N 16.66 1; 0.35 29.9 N 15.93 I/ 0.14 Survey Codes: 7/GYRO SCU 33A-8 Page 3 10/22/90 R~ORD O~ ~.FR~'~ S HEAS INCLN VERTICAL-DEPTHS SECTION DIRECTION Rk~r.ZkTIVE-COORDINATES CLOSURE DL C DEPTH ANGLE BKB SUB-SEA DISTNCE BEARING FROH-WELL-ttEAD D!STNCE BEARING !100 7 4700 0.92 4699.8 4545.8 -31.0 N 2.g0 E 30.5 N 8.3 ~ 31.6 N 15.16 W 0.26 7 4800 1.07 4799.7 4645.7 -32.5 N 2.60 E 32.3 N 8.2 W 33.3 N 14.24 W 0.15 7 4900 1.10 4899.7 4745.7 -34.1 N 1.90 E 34.2 N 8.1 I~ 35.1 N 13.37 W 0.03 7 5000 1.15 4999.7 4845.7 -35.9 N 3.60 W 36.1 N 8.2 W 37.0 N 12.71 W 0.05 7 5100 1.13 5099.7 4945.7 -37.7 N 1.50 W 38.1 N 8.2 W 39.0 N 12.19 I~ 0.02 7 5200 1,42 5199,7 5045,7 -39,7 N 5,10 E 40,3 N 7 5300 1,67 5299,6 5145,6 -41,9 N 8,50 E 43,0 N 7 5400 1,80 5399,6 5245,6 -44,3 N 9,60 E 46,0 N 7 5500 1.93 5499,5 5345.5 -47,0 N 9,70 E 49.2 N 7 5600 1,97 5599,5 5445,5 -49,6 N 12,90 E 52,6 N 8.2 W 7.8 W 7.4 W 6.8W 6.2 W 41.2 N 11.45 W 0.29 43.7 N 10.34 W 0.25 46.6 N 9.10 W 0.13 49.7 N 7.90 W 0.13 52.9 N 6.69 I~ 0.04 7 5700 2,22 5699,4 5545,4 -52,4 N 12,00 E 56,1 7 5800 2,55 5799,3 5645,3 -55,5 N 18,50 E 60,1 7 5900 2,92 5899,2 5745,2 -58,8 N 19,50 E 64,7 7 6000 3,42 5999,0 5845,O -62,7 N 17,30 E 69,9 7 6100 3.33 6098.9 5944.9 -66.7 N 22.30 E 75.4 5.4 W 4.3 W 2.7 W 1.0 W 1.0 g 56.4 N 5.47 W 0.25 60.3 N 4.07 W 0.33 64.7 N Z.41 W 0.37 69.9 N 0.80 W 0.50 75,4 N 0.77 E 0.09 7 6200 2.93 6198.7 6044.7 7 6300 2.70 6298.6 6144.6 7 6400 2.78 6398.5 6244.5' 7 6500 2.92 6498.4 6344.4 7 6600 3.08 6598,2 6444,2 -70.3 N 21.80 E -73.5 N 24.70 E -76.5 E 23.O0 E -79.6 N 25.40 E -82.8 N 24.80 E 80.5 N 85.0 N 89.4 N r~ 93'9 N 98'7 N 3.1 5.0 6.9 9.0 11'2 80,6 N 2.18 E 0.40 85.2 N 3.37 E 0.23 89.6 N 4.44 E 0.08 94.3 N 5.46 E 0.14 99,3 N 6.47 E 0.16 7 6700 2.95 6698.1 6544.1 -86.2 N 20.30 E 103.5 N 13.Z 7 6600 3.07 6797.9 6643.9 -89.7 'N 22.40 E 108.4 N 15.1 7 6900 3,27 6897,8 6743,8 -93,3 N 22,10 E.. 113,5 N 17,2 7 7000 3.20 6997.6 6843.6 -97.0 N 22.70 E 118.7 N 19,4 7 7100 3.22 7097.5 6943.5 -100.7 N 19.20 E 124.0 N 21.4 104,4 N 7.27 E 0.13 109.5 N 7.94 E 0.12 114.8 N 8.62 E 0.20 120,3 N 9.26 E 0.07 125,8 N 9.78 E 0.02 7 7200 3,17 7197,3 7043,3 -104,5 N 21,80 E 129,2 N ~' 23,3 E 131,3 N 10,23 E 0,05 I I x1 c z c Survey Codes: 7~GYRO SCU 331-8 Page 4 10/22/90 RECORD OF SURVEY S MEAS INCLN VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL C DEPTH ANGLE BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 7 7300 3.27 7297.2 7143.Z -108.2 N 21.70 E 134.4 N 25.4 E 136.8 N 10.70 E 0.10 7 7400 3.28 7397.0 7243.0 -112.O N 19.90 E 139.7 N 27.4 E 142.4 N 11.10 E 0.01 ~7 7500 3.97 7496.8 7342.8 -116.1 N 26.30 E 145.6 N 29.9 E 148.6 N 11.61 E 0.69 7 7600 5.57 7596.4 7442.4 -120.3 N 39.10 E 152.5 N 34.4 E 156.4 N 12.71 E 1.60 7 7700 6.76 7695.9 7541.9 -120,5 N 84.50 E 157.5 N 43.6 E 163,4 N 15.48 E 1.37 7 7750 7.60 '7745.5 7591.5 -117.8 S 86.60 E 157.6 N 49.9 7 7800 7.75 7795.0 7641.0 -113.8 S 75.30 E 156.6 N 56.5 7 7900 8.03 7894.1 7740.1 -102.4 f; 42.80 E 149.6 N 68.1 7 7950 7.02 7943.6 7789.6 -95.9 8 31.70 E 144.4 N 72.0 7 8000 6.40 7993.3 7839.3 -90.1 S 20.20 E 139.1 N 74.6 7 8100 5.72 8092.7 7938.7 -79.6 S 24.60 E 129.4 N 78.6 7 8200 7.22 8192.1 8038.1 -68.5 S 47.70 1; 120.3 N 85.2 7 8300 9.13 8291.1 8117.1 -56.2 S 65.60 E 112.6 N 97.0 7 8400 10.42 8389.6 8235,6 -42.3 S 57.80 E 104.5 I 112.O 7 8450 10.68 8438.8 8284.8 -33.8 S 41.50 E 98.6 N 118.9 165.3 N 17.56 E 1.67 166.4 N 19.83 E 0.51 164.4 N 24.47 E 0.69 161.4 N 26.51 E 2.05 157.9 N 28.19 E 1.27 151.4 N 31.28 E 0.68 147.5 N 35.30 E 1.54 148.6 N 40.76 E 1.96 153,2 N 46.97 E 1.31 154.5 N 50.34 E 1.23 7 7 7 7 8500 10.97 8487.9 8333.9 8550 12.90 8536.8 8382.8 8600 14.58 8585.4 8431.4 8650 15.97 8633.6 8479.6 8700 16.80 8681.6 8527.6 -24.5 S 23.80 -14.3 S 14.40 -2.8 S 10.80 9.8 S 10.80 23.3 S 9.00 90.7 N 124.0 81.0 N 127.4 69.4 N 129.9 56.5 N ,., 132,4 42.6 N 134.8 153.6 N 53.80 E 1.41 150,9 N 57.55 E 3.97 147.3 N 61.90 E 3.39 143.9 N 66.91 E 2.78 141,4 N 72.48 E 1.69 7 8800 18.57 8776.9 8622.9 7 8900 20.07 8871 · 2 8717.2 7 9000 22.20 8964 · 5 8810 · 5 7 9100 24.50 9056 . 3 8902.3 7 9200 24.75 9147 . 2 8993 . 2 51.6 S 2.00 iii 80.8 S 3.60 W 111.2 S 7.30 W. 143.0 til12.10 W 177.4 S 2.50 W 12.3 N 137.7 20.7 S 137~3 56.6 S 133.9 95.7 S 127.2 137.0 S 121.9 138,3 N 84.88 E 1.91 138.8 S 81.41 E 1.64 145.3 S 67.07 E 2.19 159.1 S 53,05 E 2.44 183.3 il 41.67 E 1.70 7 9300 25.57 9237.7 'Survey Codes: 7/GYRO 9083.7 215.6. S 4.70 E 179.4 S 12Z.7 E 217.4 S 34.37 E 1.57 c c~ z c Z SCD' 33A-8 Page 5 20/Z2/90 RB¢ORD OF ilU1WEg S: MEAS INCLN VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATEIl CLOSURR DL C DEPTH ANGLE BKB SUB-IlEA Dr STNCE BEARING FROM-NELL-HEAD DISTNCE BEARING / 100 7 9400 25.57 9327.9 9173.9 255.5 S 4.70 E 222.4 il 126.2 E 255.8 S 29.58 E 0.00 7 9500 25.47 9418.2 9264.2 295.2 S 3.50 E 265.4 8 129.3 E 295.2 il 25.98 E 0.24 ~-~ 7 9600 24.67 9508.7 9354.7 334.1 8 3.70 E 307.7 8 132.0 E 334.8 il 23.22 E 0.80 7 9700 24.82 9599.6 9445.6 372.4 S 3.10 E 349.5 il " 134.5 E 374.5 S 21.05 E 0.18 7 9800 24.32 9690.5 9536.5 410.2 S 1.40 E 391.0 S ! 136.1 E 414.0 fl 19.19 g 0.58 7 9900 25.67 9781,! 9627.1 448.0 S 0.40 W 433.3 il 136.5 E 454.3 8 17.48 E 1.39 ABOVE SURVEYS ARE FRON GYRO SURVEY OF 08/21/90. 7 9977 26.75 3 10056 27.10 3 10087 27.30 3 10125 27.30 9850,2 9696.2 9920.6 9766.6 9948.2 9794.2 9982.0 9828.0 479.1 il 6.94 E 513.9 S 21.20 E 528.0 S 25.80 E 545.5 S 28.30 E 467,2 S 138,4 E 501,8 il 147,1 E 514,8 S 152,7 E 530,3 S r. 160,7 E 487.3 il 16.50 E 2.39 522.9 B 16.34 E 3.77 537.0 S 16.52 Ii: 3.19 554.1 S 16.85 E 1.38 10251 10345 10409 10535 10630 3 10713 i 11007 I 11120 26.20 10094.5 9940.5 26.10 10178.9 10024.9 26.10 10236.4 10082.4 25.50 10349.8 10195.8 25.00 10435,7 10281.7 25.00 10510.9 10356.9 25.00 10777.4 10623.4 22.00 10881.0 10727.0 602.1 S 31,50 E 643,4 S 30.80 E 671.5 8 31.00 E 726.2 S 31.60 E 766,5 il 33.00 E 801.4 S 34.70 E 923.3 S 41.00 E 967.0 il 41.00 E 579.5 S 188.9 E 614.9 S 210.4 E 639.'1S 224.8 E 686.0 S 253.3 g 720.2 S 275.0 E 749.3 S 294.5 E 847.4 S 370.7 E 881.4 S ; 400.3 g 609,5 S 18,06 E 1,00 649,9 E 18,88 E 0.18 677,5 il 19,38 E 0,06 731.2 E 20.27 E 0.48 770.9 8 20.90 E 0.59 805.1 S 21.45 E 0.37 924.9 S 23.63 E 0.38 968.0 S 24.42 E 2.65 PROJECTED T, D, IT 11178 HD, 11178 21,50 10934,9 10780,9 987.9 S 41,50 E 897,6 S 414.4 E 988.6 8 24.78 g 0.87 'Survey Codes: 1/IlINGLE SHOT 3/HWD 7/GYRO SCU 33A-8 Page 6 10/22/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBS~A I~,AS INCLN ~ HD-TVD VERT DIRECTION R~TATIVE COORDINATES DEPTH DEPTH ANGLE BKB DIFF CRRT BEARING --100 54 0.15 54 0 0 S .89.50 T6 O 154 0.26 154 O 0 S 83.02 W 100 254 0.25 254 0 0 S 79,71 W 200 354 0.21 354 0 0 N 87.38 W 300 454 0.44 454 0 0 N 58.67 '6 FROM WELL HEAD 0.05 N 0.05 0.14 N 0.41 0.06 N O. 85 0.01 N 1.26 0.14 N t, 1.67 400 554 0.48 554 0 0 N 28.43 500 654 0.38 654 0 0 N 14.41 600 754 0.58 754 O 0 N 38.58 700 854 0.66 854 0 0 N 26.12 800 954 0.70 954 0 0 N 22.33 0.84 N 2.35 1.47 N 2.46 2.12 N 2.02 3.07 N 1.37 4.13 N 0,98 900 1054 0.83 1054 0 0 N 10.22 E 1000 1154 0.80 1154 0 0 N 6.69 E 1100 1254 0.84 1254 0 0 N 8.79 E 1200 1354 0.82 1354 0 0 N 1.16 W 1300 1454 0.75 1454 0 0 N 4.06 E 5.38 N 6.85 N 8.18 N 9.71N 11.03 N 0.50 0.43 0.15 0.06 0.10 1400 1554 0.71 1554 0 0 N 8.62 1500 1654 0.54 1654 0 0 N 34.03 1600 1754 0.53 1754 0 0 N 65.17 1700 1854 0.59 1854 0 0 N 75.59 1800 1954 0,44 1954 0 0 II 71.00 1900 2054 0.34 2054 0 0 II 80.68 2000 2154 0.35 2154 0 0 II 79.39 2100 2254 0.39 2254 0 O N 64.39 2200 2354 0.37 2354 0 0 II 51.58 2300 2454 0.35 2454 0 0 II 52.92 2400 2554 0.31 2554 0 0 II 61.82 W 12 · 32 13.33 13.91 14.13 14 · 45 14,61 14 · 69' 14,87 15.25 15.64 15.97 0.00 0.45 1.06 2.05 2.94 3.55 4.15 4.75 5.33 5.79 6.31 W '7' CD SCU 33A-8 Page 7 10/22/90 DATA INTERPOLAT~ FOR 100 FT SUBSEA INTR~VAL SUBSEA MEAS INCLN TVD HD-TVD VERT DIRECTION RELATIVE COORDINATES DEPTH DEPTH ANGLE BKB DIFF CRRT BEARING FROM NELL HEAD 2500 2654 O. 37 2654 0 0 lq 77.90 lq' 16.16 N 6.78 2600 2754 0,55 2754 0 0 N 77.78 W 16,26 N 7.59 2700 2854 0.45 2854 0 0 N 63.29 W 16.60 N 8.50 2800 2954 0.20 2954 0 0 S 84.38 W 16.80 N 8.99 2900 3054 0,11 3054 0 0 S 63.82 W 16.67 N 9,20 3000 3154 0.07 3154 0 0 N 89.24 W 16.63 3100 3254 0.09 3254 0 0 N 50.34 W 16.67 3200 3354 O'12 3354 0 0 N 48.98 W 16,82 3300 3454 0,08 3454 0 0 8 23.24 W 16.84 3400 3554 0.20 3554 0 0 S 72.43 E 16.73 9,36 9.46 9.59 9.75 9.61 3500 3654 0.37 3654 0 0 N 54.34 3600 3754 0.38 3754 0 0 N 53.85 3700 3854 0'.48 3854 0 0 N 48.54 3800 3954 0.43 3954 0 0 N 24.69 3900 4054 0.58 4054 0 0 N 13.12 16.92 N 17.36 It* 17.75 N 18.45 N !. 19.16 lq 9.12 8.60 8.02 7,48 7.30 4000 4154 O.91 4154 0 0 N 0.68 4100 4254 0.98 4254 0 0 N 17.14 4200 4354 0.97 4354 0 0 N 10.94 4300 4454 1.16 4454 0 0 lq 1.12 4400 4554 1.24 4554 0 0 N 4.42 4500 4654 1.04 4654 0 0 N 2.04 4600 4754 1.00 4754 0 0 N 2.74 4700 4854 1.09 4854 0 0 N 2.22 4800 4954 1.13 4954 0 0 N 1.09 4900 5054 1.14 5054 0 0 N 2.46 20.50 N 22.16 N 23.78 N 25.55 N 27.76 N 29.76 N 31.46 N 33.30 lq 35.23 37. ZZ lq 7.09 7.40 7.91 8.03 8.09 8.29 8.23 8.15 8.11 8.21 5000 5154 1.29 5154 0 0 N 2.09 39.27 N 8.23 -t IT1 O I I c c. c SCU 33A-8 Page 8 10/22/90 DATA IIfI'~L~TED FOR 100 FT SUBSEA INTERVAL SUBSEA ltEAS INCL}I TVD HD-TVD VERT DIRECTION RELATIVE COORDINATES DEPTH DEPTH AI~GLE BKB DIFF CRRT BEARING FROM WELL HEAD 5100 5254 1.56 5254 0 0 N 6.95 E 41.75 N 8.02 5200 5354 1.74 5354 0 0 N 9.10 E 44.62 N 7.60 5300 5454 1,87 5454 0 0 N 9.65 R 47.73 N 7.08 5400 5555 1.95 5554 1 0 N 11.44 E 51.04 N 6.49 5500 5655 2.11 5654 1 0 N 12.41 E 54.45 N 5.74 5600 5755 2.40 5754 I 0 N 15.55 E 58.27 N 5700 5855 2.75 5854 I 0 N 19.05 E 62.54 N 5800 5955 3.19 5954 I 0 N 18.29 E 67.42 N 5900 6055 3.37 6054 I 0 N 20.05 E 72.99 N 6000 6155 3.11 6154 I 0 N 22.02 E 78.31N 4.85 W 3.46 W 1.78 W 0.06 E 2.18 E 6100 6255 2.80 6254 1 0 N 23.41 E 83.05 N 6200 6355 2.74 6354 1 0 N 23.76 E 87.41 N 6300 6456 2.86 6454 2 0 N 24.33 E 91.88 N 6400 6556 3.01 6554 2 0 N 25.07 E 96.52 N 6500 6656 3.01 6654 2 0 N 22.29 E 101.37 N 4.13 E 6.08 E 8.03 E 10.20 E 12.38 E 6600 6756 3.02 6754 2 0 N 21.48 6700 6856 3.18 6854 2 0 N 22.23 6800 6956 3.23 6954 2 0 N 22.44 6900 7056 3.21 7054 2 0 N 20.72 7000 7157 3.19 7154 3 0 N 20.67 106.23 N <: 111.23 N 116.47 N 121.67 N 126.94 N 14.25 16.28 18 · 42 20.53 22.45 7100 7257 3.23 7254 3 0 N 21.74 E 7200 7357 3.28 7354 3 0 N 20.68 E 7300 . 7457 3.67 7454 3 0 N 23.55 E _ 7400 7557 4.89 7554 3 0 N 33.64 E 7500 7658 6.27 7654 4 0 N 65.37 E 7600 7759 7.63 7754 5 i S 84.66 E 132.13 N 137.44 N 142.96 N · 149.39 N ~ 156.16 N : 157.52 N 24.49 26.58 28.71 32.12 39.07 51.01 E m I c .--t ITl I-- '7 O SCU 33A-8 Page 9 10/22/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN T%'D HD-T~D VERT DIRECTION RELATIVE COORDINATES DEPTH DEPTH ANGLE BKB DzFF CRRT BEARING FROM WELL, HEAD 7700 7860 7.9?. 7854 6 I B 55.95 E i53.22 N 63.81 7800 7960 6.89 7954 6 1 S 29.30 E 143.30 N 72.67 7900 8061 5.98 8054 7 1 S 22.89 E 133.02 N 77.00 8000 8162 6.64 -8154 8 i S 38.83 E 123.75 N 82.08 8100 8262 8.41 8254 8 i B 58.88 E 115.28 N 92.01 8200 8364 9.95 8354 10 1 S 60.62 8300 8465 10.77 8454 11 2 S 36.02 8400 8568 13.49 8554 14 2 S 13.13 8500 8671 16.32 8654 17 4 $ 10.04 8600 8776 18.14 8754 22 5 S 3.69 107.78 N 106.47 96.37 N 120.73 77 . 06 N 128 . 31 50.65 N 133.48 19.91 N . i37.35 8700 8882 19.80 8854 28 8800 8989 21.96 8954 35 8900 9097 24.44 9054 43 9000 9207 24.81 9154 53 9100 9318 25.57 9254 64 6 S 2.57 7 8 6.88 9 B 11.98 10 ~ 1.96 11 S 4.70 14.49 52.39 94.65 140.0,9 187.20 137 · 61 134.38 127.40 121.77 123.35 9200 9429 25.54 9354 75 9300 9540 25.15 9454 86 9400 9650 24 · 74 9554 96 9500 9760 24 · 52 9654 106 9600 9870 25.26 9754 116 9700 9981 9800 10094 9900 10206 10000 10317 10100 104Z9 lOZO0 10540 26.77 9854 127 27.30 9954 ! 40 26.59 10054 152 26.13 10154 163 26.01 10254 175 25.48 10354 186 .11 S 4.35 E 11 ~ 3.58 E 10 Iii 3.40 E 10 Ii; 2.08 R I0 Ii; 0.14 E 11 S 7.71 12 S 26.23 12 8 30.35 12 S 31.01 11 S 31.09 11 S 31.67 E 234.88 282.34 328.49 374.47 420.36 469.11 517.50 562.25 604.48 646.50 687.67 S 127.23 130.38 133.28 135.60 136.50 138.65 154.04 178.59 204 · 09 229.26 254.36 E IT1 0 I I C n z c z c SCU 33A-8 Page .10 10/22/90 DATA IXTERPOLAT~D FOR 100 FT SUBSSA INTSRVA~ SUBSEA NKAS INCLN TVD ND-TVD VERT DIRECTION RELATIVE COORDINATES DEPTH DEPTH ANGLE BKB DIFF CRRT BEARING FROH FEI3h'HEAD 10300 10650 25.00 10454 10400 10761 25.00 10554 ~" 10500 10871 25.00 10654 11091 22.78 10854 196 11 $ ~3.41 E 727.35 S 279.63 207 10 S 35.72 E 765.75 S ' 306,07 217 10 S 38.08 B 803.04 $ 334.07 227 10 S 40.45 E 839.14 S 363.58 237 10 S 41.00 E 873.01 S- 392,96 l-ri I c z c I'i'1 Z CD SCU 33A-8 Page 11 DATA INTERPO~T~ FOR ]000 PT HEAS~JRED DEPTH INTERVAL lO/Z2/9o HEtS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINA~$ CLOSURE Dr./ · DEPTH ANGLE BKB SUB-S DIST BEARING FROH-~I~.~-HEAD DIST BEARING 100 0 0.00 0 -154 0 N 0.00 El 0 N 0 E 0 N 90.00 E 0.0 1000 0.77 1000 846 -4 N 26.70 E 5 N I W 5 N' 8.94 W 0.2 2000 0.33 2000 1846 -14 N 74.30 ~1 15 N 3 W 15 N 12.56 W 0.3 3000 0.12 3000 2846 -19 ii 53.10 W 17 N 9 W 19 N!~28.55 W 0.2 4000 0.32 4000 3846 -20 N 13.50 E 19 N 7 W 20 N 21.53 W 0.3 5000 1.15 5000 4846 6000 3.42 5999 5845 7000 3.20 6998 6844 8000 6.40 7993 7839 9000 22.20 8964 8810 -36 N 3.60 W -63 N 17.30 El -97 N 22.70 El -90 fl 20.20 E 111 ii 7.30 W 36 N 8W 70N 1W 119 N 19 E 139 N 75 E 57 ii 134 E 37 N 12.71 ~ 0.1 70 Il 0.80 W 0.5 120 N 9.26 E 0.1 158 N 28.19 E 1.3 '145 ii 67.07 E 2.2 10000 26.85 9871 9717 11000 25.00 10771 10617 489 S 11.09 E 920 S 40.85 E 477 S 140 R 845 S 369 E 498 B 16,35 E 3.7 922 S 23.57 E 0.4 I I c z c z DEC-10-'90 16:46 ID:KRU/CI/NV DRILLING TEL N0:2656224 ~123 P25 ..... ~eat Lan~ Direct/onal Z~JHin~. Znc. 1300 2600 3250 3900 4550 5650 61~00 7t§O 7600 6450 975O 104O0 11760 SSO 0 660 1300 t9~0 2600 3250 3900 4MO Sect ion Departure VERTICAL SECTION VIEN ARCO ALASKA, INC. Section at: S 27,0! E , ............... TVD Scale,: ! inch- t300 fee~ OeP Scale.: i inch- t300 feet Drawn ..... : iO/~2/go -- . _ Harker Identification FID TVD SEC~ Il kJ ~ O 0 0 .............................. - ........ Bj gI~TRA~ TIE-IN 9900 9761 446 C) PRO~CTED TO tit76 ~935 989 '~ .............. ~-~ '~'~ ............ -~* ~" 1 l ....... ~w,~ ~, .... ~'~ - -.' .......... ......... ..... _ 6~00 ~ .TN~N ,00 ~)5,6'7 DEC-10-'90 16:47 ID.:KRV/CI/NV DNILLIN~ IbL NU:~bOb~ ~l~J ~ 6rear ~an~ Directionul ~/llln~, Inc. PLAN VlEkt ARCO ALABKA. ZNC. SCU 33A-B DECLINATION.' 24.00 E SCALE ....... : t inch - 200 feet DRAHN ' 10/22/90 .... ,~, ..... ~ ........ I00 ZOO 800 BOO gOO tO00 1300 ~- NEST: EAST / ~ ...... 5r ............ l 200 300 40G 500 600 700 6OO 96~ IG~G tt~O ARCO Alaska, Inc. Post Office ~ox J00360 ,Anchorage, Alaska 99510-0350 -Fe!ephone 907 276 't215 April 29, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Subsequent Report for SCU 33A-8 Dear Mr. Smith: ..-t q ,.,I ARCO Alaska Inc. sucessfully completed the reperforation of SCU 33A-8, H2 sands, from 10864'- 10870' on 2/27/92. Please refer to the attached Well Service Report and Subsequent Report for the 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, d.C. Winn Acting Regional Engineer JCW:DRH:dh Attachment cc: Mr. W. Watson Mr.B.C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED M AY - 1 Alaska Oil & Gas Cons. CommiSSiO~ Anchorage AR. CO Alaska, Inc, is a Subsidiary of AtlaaticRich~ie0dCompany STATE OF ALASKA .. ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS; ORIGIN t 1. Type of Request: Operation Shutdown ~ Stimulate Plugging Perforate X Pull tubing ~ Alter casing ~ Repair well ~ Pull tubing ~ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~X Exploratory Stratigraphic ,, Service 4. Location of well at surface 1959' FNL, 1987' FEL, Sec.8, T7N, Rgw, SB&M At top of productive interval 2533' FSL, 1655' FEL, Sec. 8, TTN, Rgw, SB&M At effective depth 2457' FSL, 1 587' FEL, Sec.8, T7N, Rgw, SB&M At total depth 2430' FSLr 1 563' FELt Sec. 8~ T7N~ R9W~ SB&M 12. Present well condition summary Total Depth: measured 11,178' true vertical 10,935' 6. Datum elevation (DF or KB) RKB = 1 54'. GL = 128' 7. Unit or Property name Soldotna Creek Unit feet 8. Well number ~CU 33A-8 9. Permit number/approval number 10. APl number SO-133-20241-01 1 1. Field/Pool Swanson River-Hemlock feet feet Plugs (measured) 10,889-10,91 O' MD Effective depth: measured 10,889' true vertical 10,670' feet Junk (measured) feet 13. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 58' 18" 3332' 10-3/4" 9993' 7-5/8" 1547' 5-1/2" measured 10,864'-10,870' MD (H2) true vertical 10,648'-10,653' TVD (H2) Cemented Measured depth True vertical depth Driven 58' MD 2218 cu.ft, lead 3332' MD & 1 50 sx Class G 743 sx Class G 9993' IvlD 74 bbls Class G 9631'-11178' MD Tubing (size, grade, and measured depth) 3-1/2" @ 9375' MD; 2-7/8" from 9375'-10,805' MD Packers and SSSV (type and measured depth) Baker Model F-1 @ 10~762' MD Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 58' MD 3332' MD 9864' TVD 9631 '-10935' TVD RECEiVE[) ~nchorago 14. ReDresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 116 5837 2 1325 1300 Subsequent to operation 178 7326 4 1525 15. Attachments ~ 16. Status of well classification as: I Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil ..X Gas Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1400 Service ___ Form 10-404 Rev 06/15/88 Title Cook Inlet Regional Engineer Date SUBMIT IN DUPLICATE ,ARCO Alaska, Inc/, '} ~uD~l~l~ o~ AillntlC RiChfield Com~n~ WELL I PBDT FIELD- DISTRICT. ~TATE CONTRACTOR / OPERATION AT RE~ TIM E SWANSON R T VER PRODUCT I ON ~, GD/03 {,- WELL SERVICE REPORT DAYS iDATE ,LSSo a !~ co 0 I ~0~., C~ MAY- t l~ .A~aska Oii & Gas Cons. Commiss~O~'~ , ,[~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK '4W'littllr lTlmp. J ~hlll Riel&:; J Vllll)llltyJ Whld' V-,l~ 'ISI.Illd R,po. ,F . .,,.., k.**. ~ ~c~ ~,~ Anchorage Well- scu 33A-8 Spud Date: 3/73 Original RKB: 17 Top of Hemlock: 10,810' Arco, ,aska Inc. - Swanson River' APl#: 133-20241-01 Completion Date: 5/73 Hanger Type' Max. Hole Angle: 27° ield Well Type: Producer Last Workover: 10/90 Hanger: Angle @Hemlock' 25° All Depths are RKB MD to Top of Equipment. Jewelry I 3997' 2 4012' 3 9375' 4 9621' 5 10,690' 6 10,762' 7 1 0,800' 8 10,804' 9 10,889' Otis 3 1/2" "X" Nipple 1-1/2" Macco GLM dummied 3 1/2" x 2 7/8" X-Over Liner Top Packer 2-7/8" "XA" Sliding Sleeve Baker Model F-1 5-1/2"x2-7/8" Packer Offs 2-718" "XN" Nipple I.D. 2.25" Baker Wireline Entry Guide 0 Schlumberger Posi-Set Plug w/19' of Cement on top Casing and Tubing ~ ~ Grade 18" 94# 0 58' 10-3/4" 40.5# N80 0 3332' 7-5/8" 33.7# Mixed 0 9993' 5-1/2" 20# N80 9631' 11,1 78' 3-1/2" 9.3# L80 0 9375' 2-7/8" 6.5# N80 9375' 10,805' Description Conductor Pipe Sudace Casing Production Casing Liner Tubing Tubing Perforation Data Interval Zone FT SPF Date 10,864'- 10,870' H2 6 ,4' ~ 2/92 10,914'-10,930' 'H4 16 4 10/90 10,938'-10,946' H5 8 4 10/90 10,962'- 10,970' H5 '8 4 11/90 Comments Repeal Plugged Plugged Plugged H2 H5 H5 PBTD -- 11,086' TD = 11,178' RECEIVEB Gas Cons. Commission Anchorage Well SCU 33A-8 JLB 4/28/92 Rev. ARCO Aiaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering January 8, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Application for Sundry Approval SCU 33A-8. Dear Mr. Smith: ARCO Alaska, Inc. proposes to reperforate the H2 Sand (10,864'- 10,870') in Swanson River Field producer SCU 33A-8. Please refer to the attached submittal of the Application for Sundry Approval and the Perforating Procedures for details of this operation. If you require any further information in this regard, please do not hesitate to call Murray Hamilton at 263-4384. Sincerely, j,~,,., "! ~~J' ._ J. C. Winn JCW:MOH:czm:0115 Attachment CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED ,lAN - 9 t992 AJaska Oil & Gas Cons. (;omm~ss~on Anchorage ARCO Alaska, Inc. ia a Subsidiary of Aflentic Richfield Company STATE OF ~ ...... , .. ALASKA OIL AND GAS CONSERVATION ~MISSlON 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 X Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1959' FNL, 1987' FEL, Sec.8, T7N, RDW, SB&M At top of productive interval 2533' FSL, 1655' FEL, Sec.8, T7N, RDW, SB&M At effective depth 2457' FSL, 1587' FEL, Sec.8, T7N, RDW, SB&M At total depth 2430' FSL~ 1563' FEL~ Sec.8~ T7N~ RDW~ SB&M 6. Datum elevation (DF or KB) RKB = 154'. GL = 128' 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 33A-6., 9. Permit number 10. 'APl number . 50-133-20241-01 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 1 1,1 78' feet 1 0,935' feet 11,086' feet 1 0,849' feet Casing Length Size Cemented Structural Conductor 58' 1 8" Driven Surface 333 2' 10 3/4" 2218 cu. ft. lead Intermediate 8, 15'0 sx Class G Production 9 9 9 3' 7 5/8" 743 sx Class G Liner 1 54 7' 5 1/2" 74 bbls Class G Plugs (measured) Junk (measured) 10,889' Measured depth True vertical depth 58' MD 58' MD 3332' MD 3332' MD 9993' MD 9631-1 1 178' 9864' TVD 9631-10935' 13. Perforation depth: measured 10,864'- 10870'; 10,914'- 10,930'; 10,938'- 10,946'; 10,962'- 10,970' MD true vertical 10,647' - 10,652'; 10,692' - 10,707'; 10,714' - 10,721' TVD; 10,736' - 10,743' TVD Tubing (size, grade, and measured depth 3 1/2" to 9375 MD; 2 7/8" from 9375' - 10,805' MD Packers and SSSV (type and measured depth) Baker Model F-1 @ 10r762' MD Attachments Description summary of proposal _ Detailed operation program X BOP sketch * 14. Estimated date for commencing operation January, 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classific~o~=~a~ j~k E~lsVn~D Oil X Gas ~.~ ~ _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ t ~,t.,~~ Title Cook Inlet Regional Engr. FOR COMMISSION USE ONLY servicej.~.N - 9 399 Alaska Oil & Gas Cons. Gommlssi?n~ An~h0r%n~ Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance Mechanical Integrity Test Subsequent form r'"~quire 10-~-~r- ORIGINAl_ SIGNED BY I ' c~ 0_:_?_~. ...... Approved by the order of the Commission I_.ON,NIF C. SMITH Commissioner IApprova_l N~o. . / Date Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE PROCEDURE Prior to Perforatine 1. Obtain a well test. 2. Reperforation Procedure Well SCU 33A-8 Shoot fluid level in tubing to verify liquid level is several hundred feet above perforated interval. Load tubing with crude if necessary. 3. Contact Anchorage office to verify sundry approval before proceeding. E-Line Perforating 1. Conduct safety meeting with appropriate personnel. Obtain diagram of the tool string prior to commencing work. 2. RU E-line unit and lubricator. Make-up tool string of adequate weight bars, 2-1/8" Hollow Carder perf guns @ 4 SPF and 0° phasing, decentralizer, and CCL. 3. Pressure test lubricator. 4. RIH with well shut-in and tie into Atlas Wireline PDK-100 Log dated 10/28/90. 5. Position perf gun at the PDK- 100 depth shown below and fire: Gun No. Interval (PDK-100~ Footage (ffi Sand 1 10864-10870' ~ · ' H2 6. POOH. Confirm that all shots have fired. Repeat the gun run if necessary. 7. RD E-line unit. 8. Perform xylene stimulation treatment immediately following perf work. RECEIVED ^lasl~a Oil & (las Cons. CommissiOn gnchorage Arco ~laska Inc. - Swanson River ~:ield ~- SCU 33A-8 Spud Date: 3/73 ~rlglnal RKB: 17 · op of Hemlock: 10,810' APl#: 133-20241-01 Well Type: Producer Completion Date: 5/73 Last Workover: 10/90' Hanger Type: Hanger: Max. Hole Angle: 27° Angle @Hemlock- 25° All Depths are RKB MD to Top of Equipment. 1 Jewelry I 3997' 2 4012' 3 9375' 4 9621' 5 10,690' 6 10,762' 7 10,800' 8 10,804' 9 10,889' Ot~ 3 1/2' 'X' Nll:~e 1-1/2' Idacco GLM dummled 3 1/2" x 2 7/8' X-Over Tie-back Packer 2-7/8' Sliding Sleeve Baker Model F-1 5-1/2'x2-7/8' Packer Offs 2-7/8' 'XN' Nipple I.D. 2.313' Baker Wire#ne EnW Guide Schlumberger Posi-Set Plug w/19' of Cement on top Casing and Tubing 18' 94# 0 58' 10-3/4' 40.5# NS0 0 3332' 7-5/8' 33.7# Mixed 0 9993' 5-1/2' 20# NS0 9631' 11,178' 3-1/2. 9.3# LB0 0 9375' 2-7/8' 6.5# NS0 9375' 10,805' DeacrlBtlen Conductor Pipe Surface Casing Production Casing Liner Tubing Tubing Perforation Dat~ 10,864'- 10,870' H2 6 4 1/91 10,914'-10,930' H4 16 4 10/90 10,938'- 10,946' H5 8 4 10190 10,962'-10,970' H5 8 4 11/90 Plugged Plugged Plugged PBTD = 11,086' TD- 11,178' RECEIVED JAN - 9 1r99[ Alaska Oil & Gas Cons. Corem[ss%on * ' Anchorage We~ Scu 33A-8 JLB 3/5/91 E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead RECEIVED JAN - 9 ~992 Alaska Oil & Gas Cons. commission Anchorage MOH 6/1/91 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering March 13, 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 33A-8. Perforations in the H4 and H5 sands were isolated behind a plug set at 10,908' with 19' of cement on top. SCU 33A-8 was subsequently perforated in the H2 interval from 10,864' to 10,870' MD on January 13, 1990. The well is currently producing approximately 169 BOPD, 17,016 MCFPD and 6 BWPD. Sincerely, ~ /;, . /~&. Wellman ,,ff*~gRegional Engineer TW:jkw:0091 Attachment cc: Mr. A. R. Kukla Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company i"" STATE OF ALASKA ('] ALASKA OIL AND 6AS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing ~ 2. Name of Operator ARCO Alaska. In(;, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1959' FNL, 1987' FEL, Sec. 8, T7N, Rgw, SB&M At top of productive interval 2533' FSL, 1655' FEL, Sec.8, T7N, Rgw, SB&M At effective depth 2457' FSL, 1587' FEL, Sec.8, T7N, RgW, SB&M At total depth 2430' FSLt 1563' FEL~ Sec.8t T7Nt Rgwt SB&M 12. Present well condition summary Total Depth: measured 11,178' true vertical 10,935' Stimulate Alter casing ~ Repair well 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service I feet feet Plugging ,, Plugs (measured) X Perforate X Pull, tubin9 Other 6. Datum elevation (DF or KB) RKB = 154'. GL = 128' feet 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 33A-8 g. permit number/approval number 10. APl number 50- 133-20241-01 11. Field/Pool Swanson River-Hemlock 10,889-10,91 O' MD Effective depth: measured 10,889' true vertical 10,670' feet feet Junk (measured) 13. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 58' 18" 3332' 10-3/4" 9993' 7-5/8" 1547' 5-1/2" measured 10,864'- 10,870' MD (H2) true vertical 10,648'- 10,653' TVD (H2) Cemented Measured depth True vertical depth Tubing (size, grade, and measured depth) 3-1/2" @ g375' MD; 2-7/8" from 9375'- 10,805' MD Packers and SSSV (type and measured depth) Baker Model F-1 @ 10~762' MD Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Driven 58' MD 58' MD 2218 cu.ft, lead 3332' MD 3332' MD & 150 sx Class G 743 sx Class G ggg3' MD g864' TVD 74bblsClassG 9631'-11178'MD 9631'-10935'TVD RECEIVED ,Oil.& Gas Cons. 14. F~eDresentatiye Daily Averi~ge Production or Injection D~l;a Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 100% 0 0 3600 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations . .. 169 17~016 6 1500 2000 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .//~A.~J~,.~/~ /r~/¥~ ~,{ tle Cook Inlet Re,qional Engineer Form 10-404 Rev 06/15/~88 Date ~// ~/~ [ SUBIdlT IN DUPLICATE WELL i ',JANSON RIUER TEL N0:26~' ~ ~680 P06 ARCO Alaska, Inc.~ ) WELL SERVICE REPORT CON~'R.,~GTO~ -- - ' ~.,~.: g . ~..,-y o,- - IOPEFIATION-AT FI[:I=<T:)FIT'tr]I~I~ - - - " ~' ' - CHECK THiS BLOCK IF SUMMARY CONTINUED ON BACK .VV. mtmr iTem, [Cl~lll Factor I Vlllblllty I w,nd Vet I$1gnld _ ,. ARCO Alaska, Inc. ~) 1 6ul~ ~ Atlantic i~iohflelCl Coral:tony ~PaDT I FIE~- ~ISTRICT- 8TA~ ~T~CTOR - - OP~TION AT RE~ TIME ~408 PO~ ,. - 'WELL SERVICE REPORT IDA*tS DATE '/:-/I.. c~ /, ;../.,,.,/iF',- '- ' · , . ,i i i , , _ i . ii i i i · ,1 ._. i i , · . ,,.,,,,, ii . - , . _ il . i [ #ther j t=p. ..... ~iii Rarer J'.'lbill~' ~nd vet "~ J .......... 'P ~ 'FI mll~ ! knntn ARCO Alaska, Inc. ~ Of Atflrltl= F~flfl~d Coml:m~y WEL~ .... i'P~DT IFIELD. DIETRICT. STATF.. GONTR,a~OTC~ - ..- -- "' -~- ' .~. IOPERATION AT REPORT TIME n~An~ I O9.go- /090 ~408 PO6 ..... WELL SERVICE REPOR'I I _ ,, . _. Il I , , .... . Ill . Il I , , I ___--- , CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK -, ~""" j'"~: --I ~''"''"°' I v,,,.,~' l"w,,, v,,. --' !"""~ JAN-Al-' 91 0,'7:41 It ANSON RIUER TEL N0:26~ :J96 P05 ARCO Alaska, Inc. I~lafy of Atlantlo Riohfleld Coml~n¥ ]FIELD'-'I~ISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE. REPORt ., _ · i ii ii i .... l, ill · I _ . Il I .. [... i iii . i., _ · _. [ , [q,_ , . -_ ,i, CHECK THIS BLOCK IF SUMMARY cONTINUED ON BACK IV~tlfhaw I T,mnn. I ,,~hfl, t'..,... I ~;,.,,-,,,,.. I,., ...... ..... iJ I ,1 ._ Il I Ill mi - :- i , '~tANSON RIUER TEL N0:265( ~ ~366 P03 ARCO Alaska, Inc. 8ubllcll~ Of Atl~ntl= RiChfield Company WELL SERVICE REPORT WELL CONTRACTOR REMARKS |OPERATION AT REPORT TIME I p!o¢ ..~o'P co. ~. c. _O_ . .pO0 ' /4. o. o.~. / / Po'& -- 1 '1 Jill . i .... i ii ii ' E~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON I!iACK wlllhMReport j Te~. 'F ~ 'Chili Fl're, j Viliblll~eF, .11.. [ WMd VM. ARCO ALAS~ INC. Cook Inlet/New Ve90ures Engineering g490 TRANSMISSION T(Z. Commissioner FROM: COMPANY: AOGCC DATE: 1/22/91 Victoria Ferguson COMPANY: ARCO Alaska, Inc WE! Jl~ NAME: SCU 33A-8 Transmitted herewith are the following Blue Sepia Sepia i Fape & Line Folded Rolled IMylar listing PDK-100 1 , ,, ,,,~?,~!:Retum, reciept:to ARCO,~SKA, Inc. ~~: ~JudY Boegler AWn I390A Post Office Box 100360 Anchorage, AK 99510-0360' RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO ALASKA INC. Cook Inlet/New Ventures Engineering g476 TRANSMISSION T~. Commissioner COMPANY: AOGCC DATE: 12/20/90 FROM: Victoria Ferguson COMPANY: ARCO Alaska, Inc WELL NAME: Listed below Transmitted herewith are the following Blue Sepia Sepia rape & Line Folded Rolled Mylar listing SCU 33A-8 Z-Densilog,Comp. Neutron ~/ 1 1 Temp Log ~f 1 1 Venilog ~ 1 1 PDK- 100 Gamma Ray c~ 1 1 Seg. Bond v 1 1 . ACB VDL/Si~n./GR ~-- 1 1 .... DIL FOCUSED GR ,/ 1 1 DIF Temp ,Log .~..~ ~. ~ ~ 1 1 SCU 13z9 Photon Log Gravel Pack Survey 1 1 SRU 31-15 Collar Log 1 1 BRU 214-26 Formation Multi-Tester GR 1 1 BHC ACOUSTILOG GR 1 1 Receipt Acknowledgement: _~_~.n,,. Date: Return reciept to ARCO ALASKA, Inc. ATrN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' RECEIVED DEC 2 6 1990 Alaska Oil & Gas Cons. 8ommission Anchorage A oKA OIL AND GAS CONSERVATION CO;',,IMIsSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS r'~ SUSPENDED ~=~ ABANDONED D SERVICE ~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc ,.. 72-17-// 3 Address . ?' 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~ ...... 50-133-20241 - 4 Location of well at surface,J ~.~',},~-.,.' .'~_ .7'~;~~ -.-,- ,'~ 9 Unit or Lease Name 1959' FNL, 1987' FEL, SEC 8, T7N, R9W, SM .~~~.~ SOLDOTNA CREEK UNIT At Top Producing Interval 10 Well Number 2507' FSL, 1658' FEL, SEC 8, T7N,.R9W, SM SCU 33A-8 At Total Depth 11 Field and Pool 2423' FSLt 1573' FEL~ SEC 8. T7N~ RgwI SM SWANSON RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. HEMLOCK OIL POOL RKB 154' GL 128' A-028996 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susj3. or Aband. 115 Water Depth, if offshore ]16 No. of Completions 10/10/90. 10/21/90. ~ ~,t ,/0 ~/')OI NA feetMSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 11,178'MD/10,935'TVD 11,086'MD/10,850'TVD YES ['~ NO D NA feetUD NA 22 Type Electric or Other Logs Run DIL/CNL/LDT/GR/SP/CALIPER/CBL/PDK 100~ GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 18" LINE PIPE SURF 58' DRIVEN 10-3/4" 40.5# K-55 SURF 3332' 15" 2218 FT3 OR 150 SX LEAD CLASS G 7-3/8" 26.4/29.7/33.7# S-95/N80 SURF 10~672' 9-5/8" PLUGGED ~ 9330' W/120 SX CLASS G 5-1/2" 20# N80 9930' 11178' 6-1/2" 360 SX CLASS G I 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 10~805' 10~762' 10,938'-10,946' MD 10,715'-10,722' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 10,914'-10,922' MD 10,693'-10,700' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED .... 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE I GAS-OILRATIO I TEST PERIOD Flow Tubing 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. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. H SANDS 10851 10635 31. LIST OF ATTAC'HMENTS .... G)/ro, Well History 32. I hereby certify that the foregoing is true and coirect '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 Well Hi,tory - Initial Report - Dail~ IIIIIIl~tlOal: PraDIrl end lubmlt th4 "I#I~M Regort" off the flrl~ WlcIr41duly If~ll I wail Il lDUdCIId o1' workover opirltlonl am i/.Irllci. Dilly wOW prior to I,Ouddlng should be ~ummlrizid on the form giving inclullve duItll only. District ARCO ALASKA INC. Field SWANSON RIVER Auth. or W.O. no. AD6862 lCounly. I)lrmh or i~orough KENAI LalM or Unit ADL: A-028996 Title DRILL & COMPLETE Istlll AK Operator ARCO Spudded or W.O. begun IDate JHour SPUD 10/10/90 06:00 Dale andu depth as of 8:00 a.m. 09/27/90 (1) TD:10130' (10130) SUPV:WH 09/28/90 (2) TD:10130'( 0) SUPV:WH 09/29/90 (3) TD:10130' ( 0) SUPV:WH 09/30/90 (4) TD:10130' ( O) SUPV:WH 10/01/90 (5) TD:10130'( 0) SUPV:WH 10/02/90 (6) TD:10130'( O) SUPV:WH ComDlete record for elch day reported GRACE 154 NU BOPE MW: 0.0 VIS: '0 ND TR~E,NU 13-5/8" BOPE ARCO WI 48.4864 Prior status if · W.O. DAILY:S72,125 CUM:$72,125 ETD:S72,125 EFC:$1,320,000 PU 4-3/4" DC MW: 9.0 VIS: 65 FIN NU 13-5/8" BOPE,RU CHOKE LINE, DEGASSER,pIVERTER LINE & FUNCTION TEST BOP, NU FLOWLINE & 6" LINE TO TRIP TANK, TEST BOP,RAM LINES,VALVES TO 5000 PSI, HYDRIL TO 3500 PSI,INSTALL WEAR BUSHING, Rd ATLAS WIRELINE, RUN GR-CCL-CBL, RD ATLAS,PU 6-1/2" BIT, 7-5/8" SCRAPER, TWO 4-3/4" DC, RIG DOWN-ELECTRICAL PROBLEM ON DRAW WORKS,CONT. TO PU 4-3/4" DC. DAILY:S21,741 CUM:$93,866 ETD:S93,866 EFC:$1,320,000 TIH W/ TRISTATE METAL MUNCHER MW: 9.0 VIS:118 PU 3-1/2" DP,STRAP IN HOLE, DISPLACE HOLE W/HI-VIS MUD,POOH LD 7-5/8" SCRAPERS, PU TRI-STATE M~TAL MUNCHER/OIL JARS/BUMPER SUB, SERVICE RIG, RIH, FILL PIPE EVERY 10 STANDS DAILY:S35,282 CUM:$129,148 ETD:S129,148 EFC:$1,320,000 CUTTING SECTION @ 9973' MW: 9.0 VIS:131 CUT 100' DRLG LINE, RIH TO 9925',CUT CSG SECTION 9925-9963' QUIT CUTTING, CIRC., PULL 10 STDS,WELL SWAbBING, TRIP BACK TO BOTTOM, CIRC.,POOH, CHANGE OUT TRI-STATE METAL MUNCHERS,TiH FILL PIPE EVERY 10 STDS,CUT CSG SECTION 9963-9973',MUD WATER CUT 9.0 TO 8.3 PPG ON BOTTOMS UP. DAILY:S20,269 CUM:$149,417 ETD:S149,417 EFC:$1,320,000 RIH TO SET CMT PLUG MW: 9.1 VIS: 43 FIN CUTTING CSG SECTION 9973-9983',CBU, POOH, LD METAL MUNCHER/JARS/BUMPER SUB, PU 6-1/2" BIT, RIH, BIT WOULD NOT GO PAST 9983' (BTM OF SECTION),CIRC HOLE CLEAN CONDITION MUD POOH, STRAP ANDPU 2-7/8"WORK STRING, RIH TO SET CMT PLUG DAILY:S32,951 CUM:$182,368 ETD:S182,368 EFC:$1,320,000 POOH MW: 9.1 ViS: 54 FIN RIH TO SET CMT PLUG, CIRC @ 9980',RU HOWCO TEST LINES TO 4000#,BATCH MIX CLASS G SLURRY (.5% CFR-3,.45% RALAD-344 .20% HR-7) @ 16.6 PPG, PUMP 18 BBLS CMT,DISPLACE CMT W/MUD AFTER 46 BBLS DISPL. PRESSURE BUILT TO 5000 PSI,SHUT DOWN POOH AND LD 30 JTS 3-1/2" DP AND 15 JTS 2-7/8" TBG FULL OF CMT, CLEAN CMT OFF FLOOR/BOP SUB BASE/CELLAR, PU BIT AND RIH CIRC AND COND MUD, POOH DAILY:S30,323 CUM:$212,691 ETD:S212,691 EFC:$1,320,000 The above I$ ~9~rect sio,,,tu,V" I I .% -- Fol' fo~ ~re~tl~n ~d~'b~l~, ~e Pmcedu~nuat~l~ 10. O~lllng, P.ge~ AR3B-459-1-D INumberall dually ~11 hletory for.~ consecutively Page no. as they are preplmdu for IlCh well. I I ARCOOIla~ asCompany O Dally Well History--lnterir IflltllictlcHle: This form il utld Ourirlg ~nlling or work. over O~rltlOnl. If tilting, cortng, ot ~dOrlhng. ShOW fo~lti~ ~lml ~ ~llCrl~i~ *Ork ~lrf0rmeO Number III ~tlll Itlm IIItl Hqulntillly. A~Kh ~ti~tlOn of Ill corll. Work ~tfO~l~ by Producing Section will bi rlpO~l~ On "l~l~ll' comgllt~Ofl. RI~O~ offiCill o~ ~rlHnllti~ tl~ ~ "F~I' IO~. 1) Sub~t 'IIIIM" ~.tt when tille~ oul but not IIII f~Qulnily thin ivlry O~ Wl~ll~ly ol {~1 wiik i~ w~ich oil ~ il ~. S~bmlt wltkiy for worko~ I~0 followmg ~ttmg of OH Itrln~ unhl completion. OiltriCt lCOunty o. P,r,sh jst.,. AR~0 ALASKA INC. I KENAI AK I LIIII or Umt SWAN~QN RIVER ] ADL: A-028996 Olta mhd Olpth Complete record for Ilch dly whde c]r~limg or workovlr m progrmIs al of 8:00 i.m. GI~%CE 154 10/03/90 (7) TD:10108' ( 0) SUPV:WH 10/04/90 (8) TD:10108' ( 0) SUPV:WH 10/05/90 (9) TD: 9930'( 0) SUPV:EB 10/06/90 (10) TD: 9930'( SUPV:EB WOC MW: 9.1 VIS: 52 STRAP & PU 16 JTS 2-7/8" TBG, RIH, SLIP 50' DRLG LINE, PU 17 JTS 3-1/2" DP, RIH TO 9975, CIRC, RU HOWCO, BATCH MIX CLASS G CMT, 15 BBLS SLURRY DISPLACE W/66 BBLS MUD, PULL 6 STDS SQUEEZE 1 BBL AWAY, POOH, CUT DRLG LINE, PU BIT & 4-3/4" DC, RIH TO 9500' SLM, CIRC &woc. DAILY:S33,010 CUM:$245,701 ETD:S245,701 EFC:$1,320,000 TEST BOPE MW: 9.1 VIS: 46 WOC @ 9500',WASH TO 9550',DRLG CMT STRINGERS TO 9725',CLEAN OUT SOFT CMT TO BTM OF WINDOW @ 9983',CIRC AND COND MUD,POOH PICK UP 16 JTS 2-7/8" TBG AND TIH TO 9980',CIRC AND RU HOWCO PUMP 5 BBLS H20 W/2% CAUSTIC,TEST LINES TO 5000#, BATCH MIX 80 SX CLASS G CMT BLENDED W/.3% CFR-3 AND .2% HR-7 @ 16.6 PPG, PUMP 12 BBLS H20 W/2% CAUSTIC-3 BBLS FRESH WATER-14.8 BBLS CMT, DISPLACE WITH 3 BBLS WATER AND 64 BBLS MUD WHILE HOLDING 500 PSI BACK PRESSURE,PULL 7 STANDS, SQUEEZE .5 BBL AWAY @ 2200 PSI,REV OUT DP,PUMP DRY JOB, POOH, LD 16 JTS 2-7/8" TBG AND 32 JTS 3-1/2" DP,PULL WEAR BUSHING, TEST BOPE. DAILY:S32,809 CUM:$278,510 ETD:S278,510 EFC:$1,320,000 ORIENT MUD MOTOR MW: 9.1 VIS: 35 FIN TESTING BOPE, RE-SET WEAR BUSHING, BLOW DN CHOKE AND MUD LINES,PU 6-1/2" BIT AND DRLG ASSY.,TIH TO 9487',WASH 9487' TO CMT @ 9670',DRLG MED. FIRM CMT FROM 9670' TO 9885' AND SOFT CMT FROM 9885' TO 9925',CIRC AND COND MUD, WOC,DRLG MED FIRM CMT FROM 9925' TO 9930',CIRC/MIX/PUMP DRY JOB, POOH, LD 9 4-3/4" SPIRAL DC, PU NEW BHA, TEST MTR AND MWD, TIH TO 5060' SLIP DRLG LINE AND FILL DP,CONT TIH TO 9900',BREAK CIRC AND ORIENT MOTOR @ 9930' DAILY:S23,374 CUM:$301,884 ETD:$301,884 EFC:$1,320,000 REVERSE OUT DP MW: 9.2 VIS: 37 ATTEMPT TO SIDETRACK, GOOD CMT 9930-9932',PLUG DETERIORATED WOULD NOT HOLD TOOL FACE, CLEAN OUT BAD CMT TO 9980' CIRC/MIX/PUMP DRY JOB, POOH, STD BACK KICKOFF ASSY, BRK BIT REMOVE MWD BATTERY PACK, TIH W/6-1/2" BIT TO 9920',REAM 9920'- 9980',DRLG CMT 9980'-9983',WORK BIT THROUGH TOP OF STUMP AND DRLG TO 9985', HARD,CIRC/MIX/PUMP DRY JOB, POOH,PU 16 JTS 2-7/8" TBG AND TIH, SERVICE RIG, CONT TIH TO 9985',CIRC AND RIG UP BJ TITAN, TEST LINES TO 5000#,PUMP 17 BBLS 2% CAUSTIC WATER PREFLUSH ~ 3 BBLS FRESH WATER, PUMP 84 SX CLASS G CMT(14;8 BBL) BLENDED W/.6% CD-31/.15% R-1 @ 16.4 PPG,DISP. AND SPOT CMT W/4 BBL WATER AND 60 BBL MUD WHILE HOLDING 500 PSI BACK PRESSURE, PULL 7 STDS,CIP @ 0600 HRS DAILY:S26,502 CUM:$328,386 ETD:S328,386 EFC:$1,320,000 32A-$ Tho Ibova II correct s,on.t..,.-"'" l For form i:)riba~tio~ He Procedure~nUll ~lction 10, / \ AR38-459-2-B "Number all daily will hiltory tOrreS consecutively as they are prel:,arecl for each well. Page no ARCO Oila~ ,asCompany Daily Well History--lnterir II~ll~ellOIIl: Thai form il "#d c:lunng drilling or workovlr Ol:)4rltIOnl. If testing, coring, or glrforllmg, show fOrmlliO~ IIime m dllCril:)i~lg work OtrlormiO. NumOlr Iii drill Item relll #Quentlelly. Attlch ~lCrtl)tion of oil corel. Work I)lrformod by Producing Section will 1:)4 rel~orted on "ln#rlel" IJllfll until flail coml)letton. PII~Or~ officill Or rel:)rl#ntltlVe tilt on "(11#11" foe1. 1) Submtt "1#11,111" i1%li{I whtn filled out I)ut not IiiI freq,lntly thin ivlry 30 dlyl. Oil' (2) orl WldnllCSly ol thl Wtlk in which oil Ilrlno il Ne. SlJI)fl%It welkly for workovlre and Iollowmg ~4ttlng of oil Ilrm§ unlH coml:)lltlOfl. Diltrict ARCO ALASKA INC. Field SWANSON RIVER County or PlrlIh IStiiA I KENAI LIIN or Unit ADL: A-028996 AK s£lJ 33A-8 Dill arid ~IIoII~ II of 8:00 a.m. 10/07/90 (11) TD: 9930'( SUPV:EB 10/08/90 (12) TD: 9930'( SUPV:EB 0) 10/09/90 (13) TD: 9930' ( 0) SUPV:EB 10/10/90 (14) TD: 9988'( 58) SUPV:EB $) 10/11/90 (15) TD: 9993'( SUPV:EB Complele record for each OAy while <~rilhng or workovAr m I:)rOgrAll GRACE 154 POOH MW: 9.2 VIS: 35 REVERSE OUT 2 BBLS CMT, PUMP DRY JOB, POOH, LD 23 JTS DP AND 16 JTS 2-7/8" TBG, PU 6-1/2" BIT, TIH TO 9500',WASH 9500'-9631' DRLG MED TO SOFT CMT TO 9800',CIRC & WOC, DRLG MED CMT F/9800-9815',APPROX 150 FT/HR, CIRC AND WOC,DRLG MED FIRM CMT AT 9815',NO APPARENT CHANGE IN COMPRESSIVE STRENGTH IN PAST 10 HRS,DRLG AT 150 FT/HR F/9815'-9848',ROP INCREASED VERY POOR CMT THROUGH SECTION AREA, PULL UP TO 9985',CIRC BTMS UP,MONITOR WELL, FIRST 30 MIN APPEAR STATIC,VERY LIGHT FLOW OVER NEXT 30 MIN-ESTIMATE I BBL/HR INFLUX,PUMP DRY JOB POOH DAILY:S31,831 CUM:$360,217 ETD:S360,217 EFC:$1,320,000 POOH MW: 9.2 VIS: 34 CONT POOH,MONITOR THE WELL FOR FLOW,APPROX. i BBL/HR INFLUX MODIFY 2-7/8" MULE SHOE AND CUT DRLG LINE,PU 16 JTS TBG SERVICE RIG, TIH, SPACE OUT TBG TAIL W/PUPS @ 9984',CIRC BTMS UP,GAS CUT TO 8.7+,CONT TO CIRC AND RIG UP BJ TITAN, MIX 7BBL 2% CAUSTIC PREFLUSH AND BATCH MIX CMT-87 SX CLASS G/l% CD-31/.9% A-2/.35% R-11 AND 1 GAL/100 SX FP-6L @ 16.5 PPG PUMP 3 BBLS CAUSTIC FLUSH AND 3 BBLS FRESH WATER, PUMP 14.8 BBL CMT, FOLLOW W/3 BBLS FRESH WATER, DROP DP DART,DISPLACE WITH 69 BBL MUD, PLUG DID NOT BUMP,POOH 9 STDS,CIP AT 20:00 MRS,REVERSE OUT AT 9150' 1/2 BBL TO SURFACE, SHUT WELL IN WITH 2000 PSI,WOC, RELEASE PRESSURE AFTER 8 HR, PUMP DRY JOB POOH DAILY: $30,553 CUM: $390,770 ETD: $390,770 RFC: $1,320,000 ORIENT MOTOR MW: 9.2 ViS: 36 CONT POOH, STD BACK 2-7/8" TBG, FOU~TD HOLE IN DP @ 7052',PU 6-1/2" BIT AND TIH, TAG CMT @ 9680',DRLG M~D FIRM CMT F/9680' TO 9880',ROP CONSISTENT @ 90 FT/HR, CIRC AND WOC DRLG FIRM CMT 9880' TO 9930',ROP CONSISTENT @ 69 FT/HR, CBU AND MONITOR HOLE, STABLE, PUMP DRY JOB, POOH, LD 2-7/8".TBG FROM DERRICK, MAKE UP BIT AND TEST MWD AND MOTOR, TIH TO 9900',BRK CIRC AND WASH TO 9930' DAILY:S23,030 CUM:$413,800 ETD:S413,800 EFC:$1,320,000 SIDETRACK PLUG MW: 9.2 VIS: 35 ORIENT MTR AND SIDETRACK WITH KICKOFF ASSY @ 9930',DRILL TO 9988' DAILY:S32,096 CUM:$445,896 ETD:S445,896 EFC:$1,320,000 POOH MW:10.0 VIS: 36 SIDETRACK OUT 7-5/8" CSG SECTION 9988'-9993',SURVEY AND PULL INTO CSG, MONITOR WELL, FLOWING APPROX. 2 BPH,CIRC AND INCREASE MUD WT F/9.2 TO 9.5 PPG, MONITOR WELL, 15 MIN. STABLE The AbOVe il correct P[~ DRY JOB, POOH, NORMAL HOLE FILL, RE/~OVE MWD BATTERY PACK SignAture CLEAN MUD PITS~ERVICE RIG, TIHIW$6-1/2" BIT AND STABS TO 9725',WASH AND~ REAM WINDOW SECTION F/9925' TO 9993' ,CBU, RUN For form I~rel~lrltion end diltribulion ,I Proceduro, Monuol Section 10.~,"~',~ Drilling, Pig# Se Ind 87 AR3B-459-2-B I Number Ill daily well history lorms consecutively as they ere prepArect for eActt well. IPage *= ARCO OII a{: ,as Company Dally Well History--lnteri~ Iltlllll~bi#l: Thll form il Ulld during d~tlling Of wOH~OVer o~Irllionl. If lilting, coring, or ~trforlhl~g. Ihow formlho~ name in dllCribing work performe~3. Numl:~r I11 <~r~ll Item tlltl le<luehllllly. At, Ich ~l~,iDt~on of &Il co,Il. Wo,k ~.lrform.l¢l by Producing Section will bt ~ll}orted O~ "lallrlll" Ihlltl until finll completion. Rlporl officill o, ~prelentltlvl tim git "FIII~" form 1) Submit "lalerbi" %hlltl thin filled out but ilO, Iiii frequently fhifl Ivlry 30 dlye. or OIl ~Vldhlldly OF the wtlk if1 whiCl~ oil Itdl~ il lei. S~bmit weekly for workov~l Ind following letting of oil If,lng Ut, iii completion. OII,,.C, ltD..fy or P.,,., F~a~dARCO ALAS~.% ~N~ I KENAI I I ADL: A-028996 CompJefe rico,el for each dly while Orllhng or workover ~n progrell SWANSON R~VSR Date in,'l clepth es of 8:00 a.m. 10/12/90 (16) TD:10050' ( 57) SUPV:EB 10/13/90 (17) TD:10138' ( 88) SUPV:EB 10/14/90 (18) TD:10218' ( 80) SUPV:EB 1.0/15/90 (19) TD:10330'( 112) SUPV:EB 10/16/90 (20) TD:10476'( 146) SUPV:EB GRACE 154 SPERRY SUN GYRO SURVEY WHILE CLEANING BALANCE OF MUD PITS LIGHT FLOW, SHUT IN AND MONITOR PRESSURE WHILE BUILDING NEW MUD, 500 PSI AT 01:00 HRS, INCREASE NEW MUD WT IN PITS TO 10 PPG, DISPLACE 9.5 PPG LIME WINDOW MUD TO 10.0 PPG W/15 BBL DESCO WATER SPACER AHEAD OF NEW MUD, BUILD MUD VOLUME CIRCULATE TO CONSTANT 10.0 PPG, TEST FORMATION TO 14.5 PPG EMW MIX DRY JOB DAILY:S35,868 CUM:$481,764 ETD:S481,764 EFC:$1,320,000 DRLG WITH MOTOR MW:10.0 VIS: 44 POOH,NORMAL FILL, LAY DN STABS,TEST BOPE, RESET WEAR BUSHING PU MWD BATTERY PAC, TEST MOTOR AND MWD,TIH TO 9985',SURVEY AND ORIENT TOOL FACE,DRLG WITH MOTOR 9993'-10050',BTMS UP GAS CUT TO 9.6 PPG DAILY:S51,014 CUM:$532,778 ETD:S532,778 EFC:$1,320,000 POOH MW:10.0 VIS: 42 DRLG W/MTR 10050'-10138',SURVEY,CIRC AND PULL UP INSIDE CSG SLIP DRLG LINE, MONITOR HOLE,VERY LIGHT FLOW, PUMP PILL AND POOH, NORMAL HOLE FILL, LD MTR AND BENT SUB, PU NEW BHA, TIH TO 9925',WASH AND REAM MTR RUN F/9930'-10138',BTMS UP GAS CUT 9.8 PPG, CBU AND RIG UP SPERRY SUN, RUN GYRO SURVEY,PUMP DRY JOB DAILY:S28,182 CUM:$560,960 ETD:S560,960 EFC:$1,320,000 DRILLING AHEAD MW:10.1 VIS: 44 POOH,NORMAL HOLE FILL, LD STEEL STABS,PU NEW BHA, TEST MWD,TIH TO 10138' (NORMAL) DRLG TO 10218',BTMS UP GAS CUT TO 9.8 DAILY:S29,845 CUM:$590,805 ETD:S590,805 EFC:$1,320,000 DRILLING AHEAD MW:10.0 VIS: 44 DRILLING 10218'-10233',SHORT TRIP TO 7-5/8" CASING (NORMAL) DRLG 10233'-10330' DAILY:S27,285 CUM:$618,090 ETD:S618,090 EFC:$1,320,000 DRILLING AHEAD MW:10.0 VIS: 43 DRILLING 10330'-10340',SHORT TRIP TO 7-5/8" CSG, NORMAL DRILLING 10340'-10352', REPLACE SWIVEL WASHPIPE,DRILLING 10352'-10460',SHORT TRIP TO 7-5/8" CSG, DRILLING 10460'-10476' DAILY:S28,029 CUM:$646,119 ETD:S646,119 EFC:$1,320,000 AK IWell ~.~ scp 3~-8 Tho above il co,Itc, $ignatu O · For form prepar-atio~ &n~ 011trlbution lei ProcldurlI,Mlnull ~ctioh t0. AR3B-459-2-B INumbor all daily well hiltory forms conleculively as they are prepared for each well. ARCO Oil at( ,al Company Dally Well History--lnterir Iltlflliolklltl: Thai form il ulOd dunng drHIIn~ or lorkover oDer&tlonl. If tilting, coring. Or ~dOrlliflg. thow formlh~ filet i~ dllCribing wo~ ~rformeO. NumDIr III drill Itlm tl~l ~flltllly. A~lCh ~Kriplion of III CO~I. Work ~rfo~O by PmOucing Seclion will ~ moo~ed on "IflMHM" ~llll uflt~l hnll compllllo~. ~lpO~ o~icsl or ~p~lltt~ IW ~ "F~" Io~. 1) Submit "lall~" ihflll l~lh hlllO out ~ut n~ It~ l~qulntly t~l~ IVl~y ~ ~lyl. Of (2) On Wldnlldiy of the will in which OII ~H~ Il ~. ~bmll wkly for worko~ and following ~tling of oil ltrt~ until completion. Date In''I (:ltl)Ih al of 8:00 I.m. 10/17/90 (21) TD:10653' ( 177) SUPV:EB 10/18/90 (22) TD:10758' ( 105) SUPV:WH 10/~9/90 (23) TD:10890' ( 132) SUPV:WH 10/20/90 (24) TD:11026' ( 136) SUPV:WH 10/21/90 (25) TD:11122' ( 96] SUPV:WH 10/22/90 (26) TD:11178' ( SUPV:WH 10/23/90 (27) TD:11178' ( 0' SUPV:WH 10/24/90 (28) TD:11178' ( 0 SUPV:WH S~U 33A-8 Complete record for each dly whill drilling or worKover in GRAC]~ 154 DRILLING AHEAD MW:10.0 VIS: 44 DRILLING 10476'-10586',SHORT TRIP TO 7-5/8" CSG, NORMAL DRILLING 10586'-10653' DAILY:S22,253 CUM:$668,372 ETD:S668,372 EFC:$1,320,000 TEST BOP MW:10.0 VIS: 48 DRLG 10653 TO 10725, SHORT TRIP TO CASING, DRLG F/10725 TO 10758, CIRC SURVEY POOH & LD 15 JTS S135 & MWD, PULL WEAR RING, TEST BOP DAILY:S25,523 CUM:$693,895 ETD:S693,895 EFC:$1,320,000 DRLG MW:10.0 VIS: 44 RIG SERVICE, PU BHA, RIH, CUT DRLG LINE, FRIH, DRLG F/10758'-10890' DAILY:S31,428 CUM:$725,323 ETD:S725,323 EFC:$1,320,000 DRLG DRLG, SHORT TRIP TO CASING, DRLG MW:10.0 VIS: 43 DAILY:S22,070 CUM:$747,393 ETD:S747,393 EFC:$1,320,000 DRLG MW:10.0 VIS: 43 DRLG TO 11065', DROP SURVEY & DROP PILL, POOH, RETRIEVE SURVEY, CHANGE BIT, SERVICE RIG, RIH, DRLG TO 11,122 DAILY:S30,721 CUM:$778,114 ETD:S778,114 EFC:$1,320,000 RIH MW:10.0 VIS: 43 DRLG TO 11178', SHORT TRIP TO WINDOW, CIRC, DROP SURVEY PUMP PILL, POOH, RU DA, RUN SP,GR, DIL, TEM~,CNL, LOT,CAL, RD DA, DAILY:S27,431 CUM:$805,545 ETD:S805,545 EFC:$1,320,000 CIRC MW:10.0 VIS: 44 FRIH, WASH TO BOTTOM 5' FILL, CBU, SHORT TRIP TO WINDOW, CIRC & COND MUD, DROP RABBIT, POOH, RU & RUN 5-1/2" LINER, PU LINER & HANGER, RIH, CIRC CAP LINER, RIH TO WINDOW W/LINER, FILL 5 JTS, CBU @ 9919, FRIH, WASH 11151 TO 11177, NO FILL, CIRC & BATCH MIX CMT DAILY:S20,527 CUM:$826,072 ETD:S826,072 EFC:$1,320,000 CIRC MW:10.0 VIS: 45 CIRC & MIX BATCH CMT, CMT LINER W/74 BBLS CLASS G, BUMP PLUG W/2500 PSI-FLOAT HELD, LD CMT HEAD, PULL 10 STDS, MIX & PUMP PILL, POOH WELL FLOWING, MONITOR FLOW, SHUT WELL IN PRESS UP TO 1000, BLEED OFF PRESS OPEN RAMS WELL FLOWING, FPOH LD SETTING TOOL, RUN HWDP & MONELS IN HOLE, LD SHE, PU BIT RIH TAG TOP OF CMT 9090, DRLG CMT 9090 TO 9631 TOP OF LINER, 088]Ti"a ETD: $900,088 EFC:$1,320,000 AR3B-459-2-8 INumber all daily well history' forms as they are preparecl for each well, consecuhvely Page no ARCOOIIal( ,asCompany O Dally Wall Hlstory--lnterin Ini~tklne: Thil form il UNO during drilling or workovlr OpOr&tlons. If testing, coring, or i:)~rforeting, show formation nome in describing work OortormeCl. NumOOr iii clrdl item tiltl 14quent/&lly. A~Ch ~OICril:)tloh Of ell COteS. WOrX IMrforn~d by Producing Socliofl will be reported On "lfltlrhl" InCite until fines compllhon Re0on offlCill or reprelontlllVO tel~ on "Fle~" form. 1) Submit "Interim" IAfltl when filled out bul not Iiii frequently Ihln every 30 days. or (2) on Wednel(~ey bi the week in which oil I~1tl~o Il Ill. Submit wflkly for workovlte Ifld following I~ttlng of Oii Itrlflg unlil coml311tloh. District i¢ounty or PlrJtn iSfete F~,ld ARCO ALASKA ~, I KENAI JLeel~ or Unit ~ ADL: A-028996 Complete recorcl for each dly while drilling or workovlr in progrell .~WANSON RIV£~ O/II end &i of 800 e.m. 10/25/90 (29) TD:ll178' ( SUPV:WH 10/26/90 (30) TD:ll178' ( SUPV:WH 10/27/90 (31) TD:11178' ( SUPV:WM 10/28/90 (32) TD:11178' ( SUPV:WH 10/29/90 (33) TD:11178 PB:11084 SUPV:WH 0) 0) gRA~E 154 CLEAN OUT CELLAR MW:10.1 VIS: 42 FIN CIRC HOLE CLEAN, MONITOR WELL FOR FLOW, PRESSURE UP CSG TO 1000 PSI,HOLD, PUMP PILL, POOH, PU 2-7/8" DP AND 3-1/8" DC, RIH DRLG CMT FROM 9631-9636,WASH F/ 9636-9706,FIN RIH TO LANDING COLLAR AT l1086,CIRC BTMS UP,PRESSURE TEST CASING TO 1000 PSI,HOLD,CSG TESTED OK, PUMP PILL, POOM, PU RET. 'BRIDGE PLUG RIH AND SET AT 9599,PULL 20 STANDS,SET STORM PACKER, CLEAN OUT CELLAR. DAILY:S23,388 CUM:$923,476 ETD:S923,476 EFC:$1,320,000 RIH W/BIT AND SCRAPER MW:10.1 VIS: 44 ND BOPE, SET OUT OLD TUBING SPOOL, PULL OLD PACKOFF, INSTALL NEW PACKOFF AND TEST TO 2500 PSI,SET IN NEW TUBING SPOOL, NU BOPE, TEST BOPE 250-3000 PSI RAMS,LINES AND VALVES 250-4500 PSI,RETRIEVE STORM PACKER, RIM 20 STANDS,RELEASE BRIDGE PLUG CIRC, POOM AND LD BRIDGE PLUG, PU POLISHING MILL, CUT DRLG LINE POLISH TOP OF LINER 9631-9639,POOH, LD POLISHING MILL, PU BIT AND SCRAPER, RIH W/BIT AND SCRAPER DAILY:S37,382 CUM:$960,858 ETD:S960,858 EFC:$1,320,000 RIM MW: 9.5 VIS: 0 FIN IN HOLE W/BIT AND SCRAPER TO 9630',CIRC.,PUMP PILL, POOH PU TIW TIE BACK SLEEVE,TIGHT SPOT @ 8445',SET TIE BACK PACKER(LINER TOP 9621'),TEST TO 1000#, PUMP PILL, POOH, PU MILL AND 5-1/2" SCRAPER, RIH,CBU, PUMP 200 BBLS FRESH WATER, FLUSH PUMPS AND MUD LINES,DISPLACE HOLE WITH 9.5 PPG NACL TRIP TO TOP OF LINER WAIT FOR ANY SETTLING, RUN BACK TO BOTTOM TO REVERSE CIRC. DAILY:S32,101 CUM:$992,959 ETD:S992,959 EFC:$1,320,000 LOGGING MW: 9.5 VIS: 0 REVERSE OUT FILTERED BRINE WATER, CLEAN FILTERS,CONT REVERSE OUT FILTERED BRINE POOH, RU ATLAS WIRELINE,RUNNING CASED HOLE LOGS, RAN GR-CCL-CBLAND PDK-100, RUNNING GYRO NOW. DAILY:S30,329 CUM:$1,023,288 ETD:S1,023,288 EFC:$1,320,000 RIH MW: 9.5 NaCl RUN GYRO, CHANGE OUT HEADS TO RUN CASING INSPECTION LOG, RUN LOG IN HOLE,TOOL FAILED, POOM,ATTEMPTTO REPAIR CASING INSPECTION TOOL, COULD NOT, SENT iT INTO SHOP, RU LUBRICATOR AND TEST TO 500 PSI,RIH W/PERF GUN, PERF 10938-10946',CH~NGE OUT PERF GUNS, RIH,MISS FIRE, REPAIR GUN, RIH AND PERF 10914-10922',POOH,RD ATLAS PU MILL, RIH TO LD DP. DAILY:S24,015 cUM:$1,047,303 ETD:S1,047,303 EFC:$1,320,000 AK IWell sgu 32~-8 The shove il ~,~;~¢t_ For form pr~'perl}tlot~encl cllltrtbu~o ~ Proce~ Min~l Section D, fig, P~87 AR3B-459-2-B I NumPer all claily well history forms consecutively they are prepared rot eec~ well. P3ge ne il ~ ARCO O,1 ~': Gal Company Dally Well History--Inter, lelllll~lM~l: Thll form il ul~(I du/il'l~ ddlli~ Or tO~r o~rltionl. I~. tilting, coring, or~rforlling, Ih~w IOrmltlOn nlml in dtlCr~bin~ wo~ ~rformid Numar Iii drill Itl~ lllll ~ntJ~ly. A~ ~ri~lon of III COrll work ~rfor~d by Producing Section will bi ~ld ~ "In/HI' thllll uti i fi~l completion. RIPO~ offiClll or ~prl~tltl~ ~ ~ "F~" to~. 1) Submit '*lallrl~" Ihlltl Whl~ filll~ o~t but not IIII frlqul~lly then I~ ~ ~lyl. or (2 O~ WId~l~ly ol thl Wtlk i~ t~ic~ oil ~ il .I. ~mil tNkly for wO~O~ In~ foIIowmg ~ttmg of Od lit ~ until compllh~l DIItrlct ICounty or Perlll~ I$11te ~eldARCO ALAS~(,% ~N~. I KENAI I LIlll Or Unit SWANSON RIVER I ADL: A-028996 O"ti Ind dlpth II Of 8:00 I,m. 10/30/90 (34) TD:11178 PB:11084 SUPV:WH 10/31/90 (35) TD:11178 PB:l1084 SUPV:WH 11/01/90 (36) TD:ll178 PB:11084 SUPV:EB AK SCI~ 33A-8 Complete record for each day while drilling or workover in ~rogrell Gm%C~ RIH W/PACKER MW: 9.5 NaCl FIN IN HOLE TO LD DP AND DC, CIRC.,PUMP PILL, BREAK KELLY AND $UBS,LD 3-1/2" AND 2-7/8" DP,LD 3-1/8" AND 4-3/4" DC,ATTEMPT TO RUN CASING INSPECTION LOG, TOOL FAILED,RUN JUNK BASKET AND GAUGE RING TO 10,800',PU WLEG/PUP JT/XN NIPPLE/1 JT 2-7/8" TBG/MILL OUT EXTENSION/BAKER F-1 PACKER, RIH ON WIRELINE W/PACKER ASSY DAILY:S19,236 CUM:$1,066,539 ETD:S1,066,539 EFC:$1,320,000 WAIT ON SLIDING SLEEVE MW: 9.5 NaCl RUN BAKER MODEL F-1 PROD. PACKER, SET AT 10,739' WLM, RUN 2-7/8"X 3-1/2" PROD STRING, STOPPED AT 9629',POOH W/PROD STRING, LD 1 JT 3-1/2" TBG AND GLM IN 2-7/8 STRING,WAIT ON 2-7/8" SLIDING SLEEVE DAILY:S84,025 CUM:$1,150,564 ETD:S1,150,564 EFC:$1,320,000 NU TBG HD ADAPTER MW: 9.5 NaC1 WAIT ON OTIS SLIDING SLEEVE AND X NIPPLE,RIH(SLM) W/PRODUCTION STRING, LOCATE PKR W/PUMP,SPACE OUT AND LAND TBG WITH ANCHOR SEAL ASSY, LATCHED IN TO PACKER, RUN IN LOCK DOWN SCREWS ON TBG HEAD AND PRESSURE TEST ANNULUS TO 1500 PSI FOR 15 MIN.,RU SLICKLINE UNIT, RIH AND SET PLUG IN OTIS XN NIPPLE AT 10,820'WLM, POOH, RiH AND SET PRONG IN PLUG, POOH AND RD SLICKLINE UNIT,PRESSURE TEST TUBING TO 2500 PSI,LD LANDING JOINT, RD TBG TONGS,CLEAR FLOOR, SET BPV IN TBG HANGER REMOVE FLOOR PLATES/ROTARY AND ND BOPE AND 8" X 13-5/8" DBL STUDDED ADAPTER DAILY:S52,031 CUM:$1,202,595 ETD:S1,202,595 EFC:$1,320,000 The iI:)ov~ I1 correct - ' For IO~ preplrltion~nd diltri~ut}on ~ Procid.~ MIn.~l Section Drilling, PIgII~ 67 AR3B-459-2-B I Number ell deily wall hiltOry forms consecutively they ere prepared for each walt. ARCO O~;'~.nd Gas Company Dally Well History-Final Report IIIlt~tlOal: Prepare end i~bmlt the "Flllll RIIHirt" on the flrlt Wldnaldly after allowable hll {)lan illignt~'l or well il Plugged. Ablndonld. or Sold. "Final Reperl' Ihould be lubmitted &Ilo wllln operltlonl enl lUlplndld for In indefinite or epprlcllble length of time. On workovl~'l when In o~ciel tilt il not rlquirld upon completion. ~,port co~ptetlo, nind mprlll~tlliVt tilt dltl In blOCkl providld. The "Fill I%~IT' form rely bi uled for reporting thl lntlrl operltlOn if IplCl ii Ivlillbla. District ARCO ALASKA INC. Field SWANSON RIVER Auth. or W.O. no. AD6862 County or Plrilh KENAI Laele or Unit ADL: A-028996 Title DRILL & COMPLETE IAccounting coat cantle' cOde State AK I well '~o S(~U 33A-8 Operator ARCO Spudded or W.O. t)egun IA.R.Co. W.I. 48.4864 Date 10/10/90 SPUD Date end depth Complete record for each day reported es of 8:00 a.m. GRACE 154 Iotalnumber of wells (active or inactive) on this dst center prior to plugging and I bandonment of th~s well I our I Prior status if a w.o. I 06:00 11/02/90 (37) TD:11178 PB:11084 SUPV:EB MOVING RIG TO $CU 24-5 MW: 9.5 NaC1 NU 9" 5M X 3-1/8" 5M DBL STUDDED ADAPTER FLANGE AND 3-1/8" TREE, TEST PACKOFF/ FLANGE/TREE TO 5000 PSI,PULL TWO WAY CHECK VALVE AND INSTALL BPV,CLEAN PITS, RELEASE RIG AT 1200 HOURS DAILY:S100,755 CUM:$1,303,350 ETD:S1,303,350 EFC:$1,320,000 Old TD Released rig New TD I PB Depth Date IKind of rig IType completion (single, dual, etc.) Official reservoir name(s) Classifications (oil, gal, etc.) Producing method Potential lest data The al)ova il~.~or,fc} .,0.,..-, _.. ' .o, ,o~ ~.;.,,~.....,,,;.,,o., ~1 P~ce~el Man~l, Section 10,~ ",,~,.'.s~a as they a~ p~parod for each well. AR3B~5~3-C ,, Well no. Date IReaervolr Producing Interval OII or gasTest time Production Oil on test Gas per day ,. Pump laze, SPM X length Choke laze T,P. C.P. Water % IGOR Gravity Allowable Effective date corrected AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PERMIT ~ ?~ - / ? -- / WELL NAME ~-~ C (-~. COMPLETION DATE ?/ ! ~- !,~ CO. CONTACT 33,~- R check off or list data as it is received.*list received for 407, if not renuired list as NR drillino history surve~ well tests core dcscri COred int~rVa|s core analysis dry ditch intervals digital data LOG TY,-- '~O'N INTERVALS scALE ................... NO. [to .the nearest foot} ,,, [inchll . . ~i //~ ~ ~z~ ~ ...... / ~ ~ - ~o ~ ~ . , , , , ,, ,,, ,, , , , ,, ,,, ,, i,,,, ,,,, , , , ,,, I I I Ill I Ill IIII IUll I Il I I IUll IU' 11 11 IIII I ~Ii iiii i i i i i ii ii ii ii] _ ........................... 1~I , ...... ~1 ..... ......... ~ ......... ~ ,,, ~H ~ ~1 .......... i' ' .................. ...... ~ ....... j ........ ., , ................ ,, ii ii ii i[11 iiiiii iii z_ ii ii i . iii ii iiiiiiJ ~1 L II I ARCO Alaska, Ir(" Post Office c~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering December 18, 1990 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 33-8 (ARCO SCU 33A-8). SCU 33-8 was perforated in the H5 interval from 10,962' to 10,970' MD on November 27, 1990. The well tested approximately 100% gas and and is currently shut- in. Sincerely, T. Wellman Regional Engineer TW:jkw:0011 Attachment DEC 1 9 Alas_Ea,Oil &.Gas,Co~ .. ..... ,,~:~u~ ~ , /~[llCNOrage cc: Mr. A. R. 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~ .,~0360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering December 12, 1990 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 H4 and H5 intervals and perforate the H2 interval in SCU 33-8 (ARCO SCU 33A-8). We propose to perforate 6' of the H2 sand (10,864' - 10,870' MD) using 2 1/8" strip 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 Stacy L. Strickland at 263-4914. Sincerely, T. Wellman Regional Engineer TW:j kw: O010 Attachment cc: Mr. A. R. Kukla Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation Alaslia 0il & 6as Cons. ~Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ..... ALASKA OIL AND GAS ~RVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend_ Alter casing __ Repair well Change approved program m Operation Shutdown m Re-enter suspended well __ _ Plugging X Time extension _ Stimulate_ Pull tubing ~ Variance _ Perforate ~ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 99510 5. Type of Well: Development Exploratory Stratigraphic Service 1959' FNL, 1987' FEL, Sec.8, T7N, RSW, SB&M At top of productive interval 2533' FSL, 1655' FEL, $ec.8, T7N, RSW, SB&M At effective depth 2457' FSL, 1587' FEL, Sec.8, T7N, RSW, SB&M At total depth 2430' FSL~ 1563' FEL~ Sec.8~ T7N~ RSWr SB&M 6. Datum elevation (DF or KB) RKB -- 154'. GL = 128' 7. Unit or Property name $oldotna Creek Unit _ f~et 8. Well number SCU 33-8 (ARCO SCU ;~.:3A-8) 9. Permit number 10. APl number 5o-133-20241-00 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 58' 3332' 11,178' 10,935' 11,086' 10,849' Size 1 8" 10 3/4" 9993' 7 5/8" 1547' 5 1/2" measured feet Plugs (measured) 10,894' - 10,906' (Proposed) feet feet Junk (measured) feet Cemented Measured depth True vertical depth Driven 58' MD 2218 cu. ft. lead 3332' MD & 150 sx Class G 743 sx Class G 9993' MD 74 bbls Class G 9631'-11178' MD 58' MD 3332' MD 9864' TVD 9631 '-10935' TVD 10,914' - 10,930', 10,938'- 10,946', 10,962'- 10,970' MD; true vertical 10,694' - 10,709', 10,716'- 10,723', 10,737'- 10,744' TVD; Tubing (size, grade, and measured depth 3 1/2" @ 9375 MD; 2 7/8" from 9375'- 10,805' MD Packers and SSSV (type and measured depth) Baker Model F-1 @ 10~762' MD 13, Attachments Description summary of proposal · 14. Estimated date for commencing operation ' December. 1990 16. If proposal was verbally approved 17. Proposed' Proposed: Detailed operation program X 10,864' - 10,870' MD 10,648' - 10,653' TVD 15. Name of approver Date approved I I hereby certify that the foregoing is true and correct to the best of my knowledge. StatUs of well classification as: Oil ~ Gas . Suspended DEC 1 9 1990 BOP sketch ,, Signed '/'~~~ Title Cook Inlet Regional ErjQE FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so rePresentative may witness J~lilr;]lOra§l~Approval_No. Plug integrity BOP Test _ Location clearance ~ Mechanical Integrity Test ~ Subsequent form require 10- '~' /' Approved Copy Returned~ Commissioner ,u SUBMIT IN T~PLICATE ORIGINAL SIGNED BY LONNIE C. SMITH Approved b)~ the oroer otthe Commission Form 10-403 Rev 5/03/89 SCU 33A-8 Set Plug/ H2 Add Perfs Procedure SR 209 Obiective: - To set a plug over the H4/H5 interval and add perforations in the H2 interval to return the well to production. Well Date.: Completion: Tie-in Log: Minimum Restriction: Capacities: Pressure Data: 3-1/2" tbg to 9375' MD, 2-7/8" tbg to 10,805' MD PDK 100 (10/28/90) Otis 'XN' Nipple @ 10,800' MD (2.313" ID) 5-1/2" csg = 0.9314 gal/ft -- 0.0221 Bbl/ft; 3-1/2" tbg = .0087 Bbl/ft; 2-7/8" tbg = .00579 Bbl/ft Tbg=3600psi; PC= 1000 psi; SC=Opsi Recommended Procedure: Prior to Job , RU pump truck. Bullhead 40 Bbls of lease water down tubing. Displace water with 50 Bbls of lease crude to provide a water environment for setting the through tubing bridge plug and cement. 2. MIRU slickline unit. RIH with 2.2" gauge ring to ensure adequate clearance for through tubing plug and perforating guns. 3. Assure that Sundry approval has been obtained prior to setting the plug and perforating. Set plug~Dump bail cement 1. Hold safety meeting with all appropriate personnel. 2. MIRU conductor line. Pressure test lubricator to 4000 psi.' 3. RIH with CCL/plug. Tie-in using the PDK 100 log dated 10/28/90. (There is a centralizer located at 10,625' MD.) 4. Set plug top at 10,904' MD. Note: Plug will take approximately one hour to set. POOH. 5. Batch mix sufficient quantity of expanding cement to provide a lO-foot cement plug on top of the through tubing plug. 6. RIH with cement dump bailer and dumP cement on top of plug. POOH. Allow cement to cure for at least 24 hours prior to pressure testing and perforating. . Pressure test plug to 2500 psi for one hour. If plug does not hold, contact Anchorage Engineering before proceeding with perforating. 8. Bleed-off pressure. RECEIVED DEC 1 9 199~ A. laska.Oll & Gas Cons. C0mmissi0[~ ~,nchorage ARCO Alaska Inc. Is a subsidiary of Atlantic Richfield Company AR3B-6OO1-A Page Two SCU 33A-8 Set Plug/ H2 Add Perfs Procedure SR 209 Perforate H2 Interval 1. RIH with perf gun/CCL. Tie-in to perf interval' PDK 100 (10/28/90) Footage Sand SPF 10,864-10,870' MD 6' MD H2 4 Hole Company Gun Type Gun Size Depth Schlumberger Enerjet Strip 2- 1/8" 1 0.25" Atlas Silver Jet 2 - 1/8" 1 0.55" Halliburton DynaStrip 2- 1/8" 1 0.39" NOTE: Gun orientation should be 60° from hole bottom. 2. Open well to gauge tank. Perforate interval. Flow well for 5 minutes. POOH. 3. Check gun to confirm that all shots have fired. RDMO. 4. Return well to production ASAP in the 900 psi system on current choke. 3, and 5. Hole Diameter .36" .39" .51" Shut-in well. Test on days 1, DEC ~ 9 ~99~ A~as~a.oij & Gas Cons. Commission Anchorage ARCO Alaska Inc. Is a subsidiary of Atlantic Richfield Company AR3B-6001-A ~.[- SCU 33A-8 Spud Date' 3/73 Original RKB: 17 Top of Hemlock:10,810' Arc~'~ ,laska Inc.- Swanson Riv[' APl#: 133-20241-01 Completion Date: 5/73 Hanger Type: Max. Hole Angle: 27° Field Well Type: Producer Last Workover: 10/90 Hanger: Angle @Hemlock: 25° All Depths are RKB MD to Top of Equipment. Jewelry I 3997' 2 4012' 3 9375' 4 9621' 5 10,690' 6 10,762' 7 1 0,800' 8 10,804' Otis 3 1/2" 'X' Nipple 1-1/2' Macco GLM dummied 3 1/2' x 2 7/8' X-Over Tie-back Packer 2-7~8' Sliding Sleeve Baker Model F-1 5-1/2"x2-7/8" Packer Otis 2-7~8" "XN" Nipple I.D. 2.313" Baker Wireline Entry Guide Casing and Tubing Size Welqht ~ ~ Bottom 18' 94# 0 58' 10-3/4" 40.5# N80 0 3332' 7-5/8' 33.7# Mixed 0 9993' 5-1/2' 20# N80 9631' 11,178' 3-1/2' 9.3# L80 0 9375' 2-7~8" 6.5# N80 9375' 10,805' Descrlotlon Conductor Pipe Sudace Casing Production Casing Liner Tubing Tubing Perforation Data 10,914'-10,930' H4 10,938'-10,946' H5 FT SPF Date 1 6 4 10/90 8 4 10/90 Comments PBTD -- 11,086' TD= 11,178' D~C ~ 9 & Gas Cons. C0mmissio~ Anchorage Well scu 33A-8 JLB 11-19-90 E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead R.?E~EIVED D~"O~_ I 9 ']996 Alaska Oil & 6as Co,is. gommissio~] Anchorage ARCO Alaska, Inc. ~*r Post Office B(~x ,00360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering December 12, 1990 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached are Application's for Sundry ApProval requesting name changes and new APl numbers for the following sidetracked wells as discussed in phone conversations between C. M. Baker and L. C. -Smith on 12/3/90: Old New SCU 4 lA-9 SCU 33-8 SCU 32A-9 SCU 4 lB-9 SCU 33A-8 SCU 32B-9 If you have any questions or need additional information, please contact C. M. Baker at 263-4643. Sincerely, T. Wellman Regional Engineer TW:jkw: 0012 Attachment RECEIVED DEC 1 9 199~ AJaska Oil & Gas Cons, Commisslort Anchorage cc: Mr. A. R. 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 CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend_ Alter casing __ Repair well _ Plugging Change approved program __ Pull tubing ~ 2. Name of Operator ~ 5. Type of Well: Development Exploratory Stratigraphic Service Operation Shutdown __ Re-enter suspended well __ Time extension _ Stimulate_ (Name Variance _ Perforate _ Other .~X Ch.ange) 6. Datum elevation (DF or KB) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1959' FNL, 1987' FEL, Sec.8, T7N, R9W, SB&M At top of productive interval 2533' FSL, 1655' FEL, Sec.8, T7N, R9W, SB&M At effective depth 2457' FSL, 1587' FEL, Sec.8, T7N, R9W, SB&M At total depth 2430' FSL~ 1563' FEL, Sec.8r T7N~ R9Wr SB&M 12. Present well condition summary Total Depth: measured Effective depth: true vertical measured true vertical Length 58' 3332' 11,178' feet Plugs (measured) 1 0,935' feet 11,086' feet Junk (measured) 1 0,849' feet Size Cemented I 8" 10 3/4" 9993' 7 5/8" 1 547' 5 1/2" measured Casing Structural Conductor Surface Intermediate Production Uner Perforation depth: RKB = 154', GL = 12{)' feet 7, Unit or Property name Soldotna Creek Unit 8. Well number Proposed SCU 33-8 Name: SCU 33A-8 9, Permit number 13. 14. Estimated date for commencing operation 10. APl number 5o-1 33-20241 11. Field/Pool Swanson River/Hemlock Measured depth True vertical depth Driven 58' MD 2218 cu. ft. lead 3332' MD & 150 sx Class G 743 sx Class G 9993' MD 74 bbls Class G 9631'-11178' MD 10,914' - 10,930', 10,938' - 10,946', 10,962 - 10,970' MD true vertical 10,694' - 10,709', 10,716' - 10,723', 10,737' - 10,744' TVD Tubing (size, grade, and measured depth 3 1/2" @ 9375 MD; 2 7/8" from 9375' - 10,805' MD Packers and SSSV (type and measured depth) Baker Model F-1 ~ 10r762' MD Attachments Description summary of proposal _ Detailed operation program -.. 58' MD 3332' M D 9864' TVD 9631'-10935' TVD RECEIV£D DEC 1 9 1990 Alaska 011 & Gas Cons. C0mm'tss~on Anchora,qe, BOP sketch 15. Status of well classification as: Oil X Gas. 16. If proposal was verbally approved Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Suspended _ Sicjned --?-/,v~.,.__ 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_ Approved by the order of the Commission Form 10-403 Rev 5/03/89 Approved C.op¥ Returnecll Subsequent form require 10- ORIGINAL SIGNED BY LONNIE C. SNIITt'l Date IApprov_al No~..,_ Commissioner SUBMIT IN TRII~LICATE 'ol -. ,,.ORIGINAL . REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: OpeFation Shutdown Stimulate Plugging Pepfo~ate Pull tubing Alte~ casing __ Repaie well __ Pull tubing Othep 2. Name ot Operato~ 5. Type of Well: 6. Datum elevation (DF o~ KB) Development ARCO Alaska. Inc. :3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1959' FNL, 1987' FEL, Sec.8, TTN, Rgw, At top of productive interval 2533' FSL, 1655' FEL, $ec.8, T7N, R9W, $B&M At effective depth 2457' FSL, 1587' FEL, Sec.8, T7N, Rgw, SB&lvl At total depth 2430' FSL~ 1563' FEL~ Sec.8~ T7N~ R9WI SB&M 12. Present well condition summary Total Depth: measured 11,1 78' true vertical 10,935' Exploratory Stratigraphic __ Service / RKB = 154'. GL = 128' feet 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 33-8 (ARCO SCU 33A-8) 9. Permit number/approval number I O. APl number so- 133-20241-0~ 1 I. Field/Pool Swanson River-Hemlock feet Plugs (measured) feet Effective depth: measured 1 1,086' feet Junk (measured) true vertical 10,849' feet Casing Length Size Cemented Structural Conductor 58' 18" Driven Surface 3332' 10-3/4" 2218 cu. ft. lead Intermediate & 150 sx Class G Production 9993' 7-5/8" 743 sx Class G Liner 1547' 5- 1/2" 74 bblS Class G Perforation depth: measured 13. 10,914 '-10,930', 10,938'-10,946', 10,962'-10,970' MD true vertical 10,694'-10,709', 10,716'-10,723', 10,737'-10,744' TVD Tubing (size, grade, and measured depth) 3-i/2"@ 9375' MD; 2-7/8" from 9375'-10,805' MD Packers and SSSV (type and measured depth) Baker Model F-1 @ 10~762' MD Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Measured depth True vertical depth 58' MD 58' MD 3332' MD 3332' MD 9993' MD 9864' TVD 9631'-11178'MD 9631'-10935' TVD N/A ECEIVE,D ] 9 1990 Alaska Oil & Gas Cons, .CQ~sst, Anchorag~l~ , 14. Representative Daily Average Production or I niection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 28 8500 0 1000 3600 Subsequent to operation 0 100% 0 0 3600 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service , Signed Form 10-404 Rev 06/15/88 Title Cook Inlet Reqional Enqineer SUBMIT IN DUPLICATE "ARCO Alaska, Inc' ~1 , WELl. CONTRACTOR TEL fi~BDT - - [~LL~ DISTRICT- STA¥~,,~ ..... .,~_~j..~o,,_.,'~ ]"~.l V OPERATION AT REPORT TIME tWELL SERVICE REPOR' - ,,' t DAYS IDAY~i ' ' .., 'Arm~ot~.go ., i i , iii iii _ ii ii . · ilnlUl, il , Ill. l" . I ii ii i IIll ('~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~;;9.~ It'"'"' I c,,,,,..;= 'I'~"""""Y'" I w,.c~v.,." I~_'~. ' ..... j IL _ , . _ ARCO Alaska, In{ ', Post office uox 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering November 19, 1990 R£¢EIVED NOV 7 ]990 Mr. L. Smith/'~ A~a~.Ol~ & Gas Cons. Alaska Off and Gas Conservation Commissioj~iC/I.'p..t~ ,~mlllisSillll 3001 Porcupine Drive '" Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval to perforate the H5 interval in Well SCU 33A-8. We propose to perforate 8' of the H5 sand (10,962' - 10,970' MD) using 2 1/8" strip 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 Stacy L. Strickland at 263-4914. Sincerely, T. Wellman Regional Engineer TW:jkw:0006 Attachment cc: Mr. A. R. 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 CONSERVATION ~MISSION 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 X 5. Type of Well: ! 6. Datum elevation (DF or KB) Development X / Exploratory _ Stratigraphic _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4, Location of well at surface 1959' FNL, 1987' FEL, Sec.8, T7N, R9W, SB&M At top of productive Interval 2533' FSL, 1655' FEL, Sec.8, T7N, R9W, SB&M At effective depth 2457' FSL, 1587' FEL, Sec.8, T7N, R9W, SB&M At total depth 2430' FSL~ 1563' FEL~ Sec.8~ T7Nr R9Wr SB&M 12. Present well condition summary Other Total Depth: measured 11,1 78' true vertical 1 0,93 5' Effective depth: measured 11,086' true vertical 1 0,84 9' feet Plugs (measured) feet feet Junk (measured) feet Casing Length Size Structural Conductor 5 8' 1 8" Surface 3 3 3 2' 1 0 3/4" Intermediate Production 9 9 9 3' 7 5/8" Uner 1 5 4 7' 5 1/2" Perforation depth: measured 10,914' - 10,930'; 10,938' - 10,946' MD; true vertical 10,694' - 10,709'; 10,716' - 10,723' TVD; Tubing (size, grade, and measured depth 3 1/2" @ 9375 MD; 2 7/8" from 9375' - 10,805' MD Proposed' Proposed' 13. RKB = 154'. GL = 128' feet 7. Unit or Property name Soldotna Creek Unit I8' wel' number //' c~.. ,%/ .... *~c~_.~ scu '""' I 9. Permit ~mber '-¢''~)~' I10.APl number -p,~ so-133-20241- ~-*'"~_, 11. Field/Pool Swanson River/Hemlock Packers and SSSV (type and measured depth) Baker Model F-,1 ~ 10r762' MD Attachments Description summary of proposal _ Cemented Measured depth True vertical depth Driven 58' MD 2218 cu. ft. lead 3332' MD & 150 sx Class G 743 sx Class G 9993' MD 9864' TVD 74 bbls Class G 9631'-11178' MD 9631'-10935' TVD MD TvoRECEiVED 10,737' 10,744' 58' MD 3332' M D NOV 2 7 1990 ' ~laska 0.il & Gas Cons, Detailed operation program ~ B~I;~ 14. Estimated date for commencing operation November. 1990 oi~ ~ 16. If proposal was verbally approved Name of approver Date approved Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '7'/,~g~,,~.~...- Title Cook Inlet Regional Engr. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ MeChanical Integrity Test 15. Status of well classification as: Gas ~ Suspended _ BOP T~pl,ev~C(~[gp~clearance ~ __ -'-Ret~quent form require 10-/-~' ~f" Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL ~u~ ~", LONNIE C. SMITH Commissioner Date IApproval No. SUBMIT IN 'I:RIPLIC~ATE / '' " ($CU 33A-8 ~..,*~-, ..... H5 Add Pe~ Proced~e SR ~ Objective: To add perforations in the H5 interval and increase well production. Well Data: Completion' Tie-in Log: Minimum Restriction' Tubular Capacities' Pressure Data: 3-1/2" tbg to 9375' MD, 2-7/8" tbg to 10,805' MD PDK 100 (10/28/90) Otis 'XN' Nipple @ 10,800' MD (2.313" ID) 3-1/2" tbg = .0087 Bbl/ft; 2-7/8" tbg = .00579 Bbl/ft Tbg= 3600 psi; PC = 1000psi; SC = 0psi Procedure: Note' · Make a 2.2" gauge ring run to 11,000' MD to assure that there is adequate clearance for perf guns prior to RU conductor line. · Assure that Sundry approval has been obtained prior to perforating. 1. Hold safety meeting with all appropriate personnel. 2. MIRU pump truck. Bullhead 20 Bbls lease crude down tubing so that liquid will cover the perf guns. (Run packer calculations, as necessary.) 3. MIRU conductor line. Pressure test lubricator to 4000 psi. 4. RIH with perf gun/CCL. Tie-in to perf interval: PDK 100 (10/28/90) 10,962-10,970' MD Footage .Sand .SPF 8' MD H5 4 Hole Hole Company Gun _Type Gun Size Depth Diameter Schlumberger Enerjet Strip 2-1/8" 10.25" .36" Atlas Silver Jet 2-1/8" 10.55" .39" Halliburton DynaStrip 2-1 /8" 10.39" .51" NOTE: Gun orientation should be down (at hole bottom). 5. Perforate interval. POOH. 6. Check gun to confirm that all shots have fired. RDMO. 7. Return well to production ASAP in the 900 psi system on current choke. Test on days 1, 3, and 5. ARCO Alaska Inc. Is a subsidiary of Atlantic Richfield Company AR3B-6001-A Well- sou 33A-8 Spud Date' 3/73 Original RKB: 17 Top of Hemlock:10,810' '~ Alaska Inc.-Swanson R}' ~r Field APl#: 133-20241-01 ~ Well Type' Producer Completion Date' 5/73 Last Workover: 10/90 Hanger Type' Hanger' Max. Hole Angle: 27° Angle @Hemlock' 25° All Depths are RKB MD to Top of Equipment. Jewelry I 3997' 2 4012' 3 9375' 4 9621' 5 10,690' 6 10,762' 7 1 0,800' 8 10,804' Otis 3 1/2" "X" Nipple 1-1/2" Macco GLM dummied 3 1/2" x 2 7/8" X-Over Tie-back Packer 2-7/8" Sliding Sleeve Baker Model F-1 5-1/2"x2-7/8" Packer Offs 2-7/8" "XN" Nipple I.D. 2.313" Baker Wireline Entry Guide Casing and Tubing Size ~f.P,J.g.bt Grade 18" 94# 0 58' 10-3/4" 40.5# N80 0 3332' 7-5/8" 33.7# Mixed 0 9993" 5-1/2" 20# N80 9631' 11,1 78' 3-1/2" 9.3# L80 0 9375' 2-7/8" 6.5# N80 9375' 10,805' Descrl_Dtion Conductor Pipe Sudace Casing Production Casing Liner Tubing Tubing Perforation Data Interval Zone FT SPF Date 10,914'-10,930' H4 16 4 10/90 10,938'-10,946' H5 8 4 10/90 Comments PBTD = 11,086' TD= 11,178' Well SCU 33A-8 JLB 11-19-90 E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves ,,. Wellhead ARCO ALASKA INC. Cook Inlet/New Ventures Engineering g465 TRANSMISSION TO:. Commissioner COMPANY: AOCK2C DATE: 10/29/90 FROM: Scott Jepsen 'COMPANY: ARCO Alaska, Inc WELL NAME: Listed below Transmitted herewith are the following ,5~ee. 73a po.0z c¢ 61£ :: ~ 23Pw~ Blue Sepia Sepia rape& Line Folded Rolled Mylar listing SCU 33-8 1 SCU 13-9 Dual Burst 'IDT Log(TDTP) 1 1 Receipt Acknowledgement: Date: Return reciept to ARCO ALASKA, Inc. ATrN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' RECEIVED OCT 3 I 1990 Alaska Oil & ~as Cons. Commission Anchorage TELECOPY ~ (907) 276-7542 A W McBride ARCO ATO 1448 P~e ~ SCU 33-8 API No. 50-133-20241'" Permit No. 72-17 Dear Mr. McBride The enclosed sundry.application i's being returned to you because the API number is invalid. Apparently, Arco took it upon itself to assign the API number, which reflects an operation to redrill the well. Our records indicate that no application for a permit to redrtll this well has been filed with our agency. Please be advised that AOGCC is t'he appropriate entity for assigning API numbers, not ARCOI ~ In the future, we expect ARCO to use only validAPI numbers, we'll names, and permit numbers in its correspondence with AOGCC. Your attention to this matter will help ensure timely processing of permit applications and sundry notices. If you have any questions, please contact Larry Grant or Robert Crandall at 279-1433.. David W. JohnStd~:~ Commissioner~,,~ ,,~ ~. , cc~ Carol Baker Steve Edwards B2.924 STATE OF ALASKA '!. ALASKA OIL AND GAS CONSERVATION COMMISsiON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator ARCO Alaska. Inc. _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program_ Pull tubing _ Variance _ Perforate ~ Other .X Si.detrack 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface At top of productive interval 2831' FNL, 1701' FEL, Sec, 8, T7N, Rgw, SM At effe~ive depth S ~p ~ 2436' EEL, 1850' FEE, Sec, 8, m7N, R9W,,~U 4 7990 At total depth ~aska Oil&G~.. Cons. 2946' FNL, 1664' FEL, Sec. 8, T7N, R9W, SM ' 12. Present well condition summary .... w~u[a~ Total Depth: measured 11,100' feet Plugs (measured) true vertical 10,387' feet Effective depth: measured 1 0,130' feet Junk (measured) true vertical 9,980' feet 6. Datum elevation (DF or KB) RKB 154.' GL 125' 7. Unit or Property name Soldotna Creek Unit 8. Well number $CU :~3-8 (ARCO sCU 33A-8] 9. Permit number 72-17 feet 10. APl number 50-133-20241 '"~0~ 11. Field/Pool Swanson River Field Hemlock Oil Pool SCU 33-8 P&A with 120 sx Class G @ 10,130'. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 58' 18" 3332' 1 0-3/4" 1 0,672' 7-5/8" 640' 5- 1/2" measured None open to production true vertical None open to production Tubing (size, grade, and measured depth) None Cemented Measured depth True vertical depth Driven 58' md 58' tvd 2218 ft3 .lead 3332' md 3332' tvd & 150 sx Class G 743 sx Class G 10,672' md 10,470' tvd 93 sx Class G 10,460'-11,100' md 10,837' tvd 33-8 has been P&A @10,130'. 33A-8 will be sidetracked from 33-8 with minimum departure from the original BHL. Packers and SSSV (type and measured depth) None Attachments Description summary of proposal ..~ Detailed operation program_ BOP sketch X 14. Estimated date for commencing operation Seotember 27. 1990 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~,/.~ ,'j~'~,l.~ .~..~~ ~itle Area Drilling Engineer Date 13 - - ' ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-~...~~' I! A P P r ° v~N~° ?..~-~. ~,pproved by the order of the Commission Form 10-403 Rev 06/15/88 i3P, tl~tNAL S~GI~.!3 ~ LONI~IE C. ,~ Commissioner Approved Copy Retqrned Date SUBMIT IN TRIPLICATE ,~CU 33-8 General Procedure 1. Move in rig and rig up. . Ensure well is dead, ND tree, NU BOPE, and test same. Build hi- vis mud system suitable for section milling. 3, PU 3-1/2" drill pipe and GIH w/ 6-1/2" bit and 7-5/8" 33.7// casing scraper to PBD = +/- 10,331'. Test casing to 3,000 psi. Displace casing w/ hi-vis mud system suitable for section milling and POH. , GIH w/ Tri-State Metal Muncher section mill for 7-5/8" 33.7# casing. 5. Cut 60' section f/ +/- 9,900'- 9,960'. POH. 1 GIH open ended and spot cement plug f/ PBD = 10,331'- 9,850'. PU above TOC and squeeze +/- 3 bbls cmt into formation if possible. Open preventers and POH. . GIH w/ 6-1/2" bit and dress off kick-off plug to 10' below top of casing section. POH. ge Side track well out of section with minimum displacement to the Northeast from the current bottom hole location keeping angle as low as practical. Redrill well to +/- 11,100' TVD. . Log open hole and make any additional necessary rat hole on the conditioning trip prior to running casing. 10. Run 5-1/2" production liner and cement same. 11. Clean out to TOL and test same to 3,000 psi. 12. Clean out inside of liner and retest to 3,000 psi. 11. 12. Run cased hole logs Perforate w/TCP. POH and LD drill pipe. 13. 14. 15. 16. Run completion assembly. ND BOP's, NU tree, and test same. RD and MO rig. Displace to lease crude and turn well over to Production Supervisor. Coos. ~lt~Chorago Corntni~ion SCU 33A-8 5.1/2" Liner Desien Factors _ Casing 5-1/2", 20#/ft, N80, FL4S, R3 Collapse (psi) 8,83 0 Burst (psi) 9,190 Pipe Body Yield (M lb) 4 66 Joint Strength (M lb) Make up Torque Tube I.D. Joint I.D. Drift I.D. 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) 9,608' to 11,088' MD (9,515' to 10,850' TD) 1,480 TENSION (Air Wt.) .loint Strength String Weight Pioe Bodv Yield -- v String Weight = 303,200/(1,480)(20.0) = 1 0.2 = 466,000/(1,480)(20.0) = ~[ 5.7 COLLAPSE (Void Csg.) 1. Assume 12 ppg mud weight maximum 2. Annulus full of mud Collaose -- Annular Pressure = 8,830/(10,850)(12.0)(.052) = 1.3 O Collapse (TOL) = 8,830/(9,515)(12.0)(.052) = 1.4 9 Annular Pressure BURST (Top and Bottom) Ton Burst 1. Worst case during production 2. Backup gradient of 8.9 ppg 3. BHP - 5,000 psi @ TVD w/gas column to surface 4. Tubing leak at surface. 5. Oil packer fluid = 7 ppg 6. Gas gravity = 0.65 SITP = BHP * 1/e (¥ * TVD · 0.0000347) where: B HP = Bottom hole pressure ¥ - Gas gravity TVD = Total vertical depth SITP = (5,000)(1/e(0'65x10,850x0'0000347)) = 3,915 psi Top Burst = Burst Rating + Backup SITP + Packer Fluid 9.190 + (8.9)(.052)(9.515) 3915 + (7.0)(.052)(9,515) = 1.84 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 Rating + Backu0 Surface Pressure + Fluid Gradient 9.190 + (8.9~(.052)(10.850) = 1.42 5,000 + (8.9)(.052)(10,850) SCU 33A-8 i~, Liner Schematic 18"@ 58' 10-3/4" @ 3,332' Top of SCU 33A-8 5-1/2" Liner @ +/-9,600' 7-5/8" Window milled @ +/- 9,900'-9,960' Kick off Cement Plug @ +/-9,890' 7-5/8" Cement Retainer @ 10,331' Top of SCU 33-8 5-1/2" Liner @ 10,460' SCU 33-8 7-5/8" Window @ +/-10,672' SCU 33-8 Abandoned Wellbore PBTD @ 11,010' TD @ 11,100' Note: All depths are corrected to RKB=154', G.L.=128',RKB-G.L.=26' (Original RKB-G.L.=15') SCU 33A-8 Proposed Completion Schematic 10-1 11 12 14 15 18" @ 58' 10-3/4" @ 3332' Top of 5-1/2" Liner @ 9,600' 7-5/8" Window cut @ 9,900' H Sands @ +/-10,400' - 10,700' PBTD @ 11,010' TD @ 11,100' COMPLETION DETAIL . 3. 4. 5. 6. . , 10. 11. 12. 13. 14. 15. 16. 17. 130 JTS 3-1/2",9.3#,N80, EUE 8RD MOD,R2 TUBING OTIS X NIPPLE PUP,3-1/2" X 6' GLM,3-1/2" X 1" PUP,3-1/2" X 6' 182 JTS 3-1/2",6.5#,N80,EUE 8RD MOD,R2 TUBING X-OVER,3-1/2" X 2-7/8" 28 JTS 2-7/8",6.5#,N80,EUE 8RD MOD,R2 TUBING PUP,2-7/8" X 6' GLM,2-7/8" X 1" PUP,2-7/8" X 6' 2 JTS 2-7/8",6.5#,N80,EUE 8RD MOD,R2 TUBING BAKER MOD. F-1 PACKER 1 JT 2-7/8",6.5#,N80,EUE 8RD MOD,R2 TUBING OTIS XN NIPPLE 1 JT 2-7/8",6.5#,N80,EUE 8RD MOD,R2 TUBING Note: All depths are corrected to RKB=154', G.L.=128', RKB-G.L.=26' (Original RKB-G.L.=15') 1:3-5/8 !"" 000 BOP ST i""K DIAGRAM ACCUMULATOR CAPACITy TI~ST I '1 REYENTER~ PIPE RAH BLI ND RAHS DRILLING SPOOL PIPE RAMS TBO SPOOL 1. CHECK AND Flu-ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3500 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. ~RVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER AU. UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER MMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. CHECK THAT AU- I-tCXJ~DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN LOCK-DOWN SCREWS IN HEAD. :3. OPEN CASINO VALVE(S) ON TUBING HEAD. (MONITOR CASING VALVE FOR FLOW THRCXJGH 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 BOTrOM PIPE RAMS. TEST TO 250 AND 5,000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 7. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PUl/. 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 UNES ARE FULL OF A NON-FREEZING UOUID AND ALL VALVES ARE SET iN THE DRlU. ING POSITION. 9. TEST STANDPIPE VALVES TO 250 AND 5,000 PSI. 10. TEST KELLY COCKS AND INSIOE BOP TO 250 AND 5,000 PSI. 11. RECORD TEST INFORMAT~ ON ~ 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 OFTHE ~ ALL BOP EQUIPMENT 5000 PSI RATED C:MOK~ KI~%FOLD XH 8XZDDgD Z~OU~g TO I)%TS/(3AB BUSTBIt (%)' (2) (3) (4) (S) 20,000t LXHB. FBCI(BOPl 10,O00! ~ROSI 4" 10,000! VP, Z,VB8 3' 10,O00! VALVBI 10~000! H~DRAULZ¢ CHOEB8 3' S00O! VALVR8 3' x SO00! ~iK)8I 3' x S000! LX#II 4" x $000J LXHBI Grace 154 Drilling Fluids System Ii I.. I ! --'- I Ill 31 6 5 18 19 PRO, OS ED REDRILL SCU-55A-8 17 2O --i-- 34 I0 ,~w on$on CERTIFICATE OF SURVEYOR hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska and that this plot represents a proposed drilling location. Dimensions and other details furnished by Arco Alaska Inc. Date Surveyor 15 T8N T7N PROPOSED REDRILL SCU - 35 A- 8 Located in Sec. 8~T.?N.IR.gw.t S.M.1AIosko for ARCO ALASKA INC. P.O. BOX 100360 ANCHORAGE, AK. 99510-0360 R.C. DAVIS 8~ ASSOC. LAND 8~ MINERAL SURVEYORS 14870 SNOWSHOE LANE ANCH.,AK. 99516 I SCALE: I"= I ARCO Alaska, ~'", Post office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 4, 1990 , Mr. Daniel Doshier U.S. Fish and Wildlife Services Kenai National Wildlife Refuge P. O. Box 2139 Soldotna, Alaska 99669' Dear Mr. Doshi'er: Subject: Swanson River Redrill/Workover Activities As'mentioned in my previous letter, ARCO Alaska,Inc. (AAI) plans to perform a redrill of three wells (SCU 32B-9, SCU 33-8, and SRU 21- 34, and a workover on one well - SCU 13-9. This wOrk is planned to commence about May 28, 1990. 'All activities will be done from existing well pads. The final Plan of Operations and a copy of the "Coastal Project Questionnaire" are provided for your review and authorization of the proposed work. If you have any questions Or need additional information about these operations, please contact me at 265-1501. Sincerely, Permit Coordinator LLB:es LLB/04/031 I E6EIVEi., enclosure' Plan of Operations CZM Questionnaire~ cc w/o enclosures: J. Dygas, BLM, Anchorage Kenai Borough, Soldotna L. Leatherberry, ADEC, Soldotna P. Miller, DGC, Anchorage '~ L. Smith,"AOGCC, Anchorage ARCO Alaska. Inc. Is a Subsidiary of AllanllcRIchfleldCompany ,~rv~n cfyv~ r, ARCO Alaska.' .~, ..... Post Ot,,,.! ,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 1, 1990 Mr. Lester Leatherberry Alaska Department of Environmental Conservation Kenai District Office P.O. Box 1207 Soldotna, Alaska 99669 Dear Mr. Leatherberry: EHG ASST I ,s?, ~, Ec,~i%~p FILE I .I Subject: Swanson River Redrill/Workover Activities ARCO Alaska, Inc. (AAI) plans to perform a redrill of three wells and workover on one at Swanson River Field beginning abOut May 28, 1990. All work will be done from existing pads. A copy of the "Coastal Project Questionnaire" and Plan of Operations are~ provided for your information. If you have any questions, I can be reached at 265-1501. Sincerely, Permit Coordinator LLB:es LLB/04/032 Enclosure- Plan of Operations CZM Questionnaire cc w/o enclosures' J. Dygasl B LM, Anchorage Kenai Borough, Soldoma P. Miller, DGC, Anchorage L. Smith, AOGCC, Anchorage - B. Wright, DNR, Anchorage RECEIVE£, Alaska 0il & Gas Cons. Commission Anchorago ARCO Alaska. Inc. is a Subsidiary o! AtlanlicRIchfieldCompany AR3B-6003-C ARCO Alaska,'.'.-' ~ Post O'th,~e Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 May 1, 1990 Mr. Bill Wright Department of Natural Resources Land and Water Management P.O. Box 107-005 Anchorage, Alaska 99510-7005 Dear Mr. Wright: ARCO Alaska, Inc. (AAI) is planning redrill operations on three wells in the Swanson River Field and a workover on SCU 13-9 starting about May 28, 1990. The wells involved are SCU 32B-9, SCU 33-8, and SRU 21-34. As part of this activity, we plan to utilize groundwater from nearby water wells, which have been drilled previously. The drilling and testing activities .on each well' will last less than one month and we anticipate the daily water use to be approximately 10,000 gallons per day for each well. In anticipation of these and future redrill activities at Swanson River this summer,we request that by this application a temporary water use permit be issued for each of these wells. To minimize the administrative workload on AAI and the Division of Land and Water Management, it would be preferred that AAI be issued a permit that would allow temporary use of any installed water well within the field for ade,.tuat,,,z .......the a period of one year. We feel the single permit would ,, ,,I,, ~,4,4 .... anticipated activities in the field. Periodic reports would be provided to ensure that the State, and Fish and Wildlife Service records are complete.. AAI would, however, continue to obtain USF&WS and BLM authorizations for field operations as needed. I have attached the Plan of Operations that applies to the planned activities and the required check for $100.00. If you have any questions or need additional information about these drilling operations, please contact me at 265-1501. I hope to hear from you at your earliest convenience dUe to the short-time frame before the work is planned to begin. Sincerely, Permit Coordinator LLB:es LLB/04/28 enclosures: Plan of Operations CZM Questionnaire cc w/o enclosures: D. Doshier, USF&WS, Soldotna J. Dygas, BLM, Anchorage H. Friedman, ADEC, Anchorage Kenai Borough, Soldotna L. Leatherberry, ADEC, Soldoma P. Miller, DGC Anchorage L.' Smith, AOGCC, Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanlicRlchlieldCompany Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 1, 1990 Mr. Henry Friedman Alaska Department of Environmental Conservation 3601 C Street, Suite 1350 Anchorage, Alaska 99503 Dear Mr. Friedman: ARCO Alaska, Inc. (AAI) plans to perform a redrill of three wells (SCU 32B-9, SCU 33-8, SRU 21-34), and a workover on SCU 13-9 in order to improve oil production. The drilling activities will begin about May 28, 1990. All work will be done from the existing well pads. The Plan of Operations for these activities is attached for your information. The drilling waste to be generated will consist of used mud and formation cuttings, which will be confined to a metal "cuttings box", for transport to the Swanson River Field Central Disposal Facility that is a lined permitted facility for the disposal of this type of drilling waste. All pumpable liquids generated during the drilling and testing of the ::,el! ,:.,il! be injected into disposal well SCU 43-4. It is estimated that approximately 3000 barrels of drilling waste fluid will be injected.in this manner. If you have any questions concerning this waste disposal notice, please do not hesitate to call me at 265-1501. Sincerely, Permit Coordinator LLB:es LLB/04/029 enclosure: Plan of Operations CZM Questionnaire cc w/o enclosures: D. Doshier, USF&WS, Soldotna J. Dygas, BLM, Anchorage Kenai Borough, Soldotna L. Leatherberry, ADEC, Soldotna P. Miller, DGC, Anchorage L. Smith, AOGCC, Anchorage B. Wright, DNR, Anchorage RECEIVED o 7 lggo /tlaska.oii.& Gas Cons. Commission ~nch0ra~ ARCO Alaska, Inc. is a Subsidiary of AllanlicRIchfleldCompany AR3B-6003-C; ARCO Alaska,.. ~..? July 18, 1989 Mr. Bill Wdght Department of Natural Resources Land and Water Management P.O. Box 107001 Anchorage, AK 99510-7001 Dear Mr. Wright: ARCO Alaska Inc. (AAI) is planning redrill operations on two oil wells in the Swanson River Field commencing about the 10th of August, 1989. The wells involved are SCU 41B-9 and SCU 43B-8. As part of this activity, we plan to utilize groundwater from nearby water wells which were drilled prior to 1970. The drilling and testing activities on each well will last less than one month and we anticipate the daily water use to be apprcximately 10,000 gallons per day for each well.. In anticipation of these and future workover operations, AAI is by this application requesting a temporary water use permit for each of these wells from Land and Water Management. To minimize the administrative burden on AAI and the Division of Land and Water Management, it is preferred that AAI be issued a permit that would allow temporary use of any installed water well within the field for a period of at least one year. We feel that one permit would address the multiple anticipated activities in the field. Periodic reports would be provided to ensure that the State and US Fish and Wildlife Service records are complete. We would, however, continue to obtain USF&WS and BLM authorizations for field operations as needed. I have attached for your information the Plan of Operations that applies to the two subject wells and the required checks for $50.00. If you have any questions or need additional information about these drilling operations, please call me at 263-4675. I hope to hear from you at your earliest convenience due to the short time frame before the work is planned to begin. Sincerely, Marcia P. I~latthieu Cook Inlet Permits Coordinator. MPM:es MPM/07/011 MPM:es MPM/07/011 Enclosures: Plan of Operations CZM Questionnaire cc w/o enclosures: P. Bielawski, DGC, Anchorage J. Dygas, BLM, Anchorage H. Friedman, ADEC, Anchorage J. Gabler, KPB, Soldotna L. Leatherberry, ADEC, Soldotna B. Richey, USFWS, Soldotna L. Smith, AOGCC, Anchorage ARCO Alaska, I, ~'? ~.':" ~;':,.''. · ''~ ' ~; Office . · ' -or..'~c:,~. ...,,.~(~.~ .,7 . '.~ ' ' " July 18, 1989 Mr. Henry Friedman AK Dept. of Environmental Conservation 3601 "C" Street, Suite 1350 Anchorage, Alaska 99503 Dear Mr. Freidman: ARCO Alaska, Inc. plans to perform a redrill of two wells, SCU 4 lB-9 and SCU 43B-8, at Swanson River Field in order to improve oil production. The drilling will begin on or about August 1, 1989. All the work will be done from the existing well pads. The Plan of Operations for these redrills is attached for your information. The drilling waste to be generated will consist of used mud and formation cuttings which will be confined to a metal "cuttings box" for transport to the Swanson River Field Central Disposal Facility,.which is a lined, permitted facility for the disposal of this type of drilling waste. All pumpable liquids generated during the drilling and testing of the well will be injected into disposal well SCU 43-4. It is estimated that approximately 3000 barrels of drilling waste fluid will be injected in this manner. Our evaluation of the planned activities indicates that this is not storage and therefore, permits are not required. We request, however, that ADEC review and provide written concurrence with the plan outlined above. If you have any questions, pleaSe do not hesitate to call me at 263-4675. Sincerely, Marcia P. Matthieu Cook Inlet'Permits Coordinator MPM:es MPM/07/010 Enclosures: Plan of Operations CZM Questionnaire cc w/o enclosures: P. Bielawski, DGC, Anchorage J. Dygas, BLM, Anchorage J. Gabler, KPB, Soldotna L. Leatherberry, ADEC, Soldotna B. Richey, USFWS, Soldotna L. Smith, AOGCC, Anchorage B. Wright, DNR, Anchorage '.RCO ,Maska, !nc. is a Subsiaiary RI AtlanlicRicl~lielrlC'ampany :.F ~t.~ '.'-L.,; ~ ,' luly 18, 1989 Ms. Patty Bielawski AK Dept. of Governmental Coordination Office of Management and Budget 2600 Denali, Suite 700 Anchorage, AK 99503 Dear Ms. Bielawski: A ARCO Alaska, Inc. plans to perform a redrill of two wells - SCU 41,1~-9 and SCU 4,3fl~ at Swanson River Field in order to improve oil production. The drillingq's planned to begin on or about August 1, 1989. All the work will be done from the existing well pads. The Plan of Operations for the red_rills is attached as well as the "Coastal Project Questionnaire." We have applied for permits as follows: BLM: Permit to Drill, and Land & Water Management: Temporary Water Use. Copies of these applications are attached for your information. Our contact for the BLM permit is Joe Dygas, and for the Water Use permit is Bill Wright. If you have any questions, please do not hesitate to call me at 263-4675. Sincerely, Marcia P. Matthieu Cook Inlet Permits Coordinator MPM:es MPM/07/009 Enclosur'es: Plan of Operations CZM Questionnaire CC: J. Dygas, BLM, Anchorage* L. Leatherberry, ADEC, SoldOtna ~.'..~,mith~A~CC~An~horag~.~t B. Richey, USFWS, Soldotna* J. Gabler, KPB, Soldotna* H. Friedman, ADEC, Anchorage B. Wright, DNR, Anchorage *with attachments ARCO Alaska, Inc. ~s a Subsidiary of AtlantlcRichtieidCompany .:R38-6063.C Well Histo,ry 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 APPENDIX' No 'special'effort has been made to chronologically organize this category of information. COMPANY:ARCO ALASKA INC. WELL:SCU 33,-8 FIELD:SOLDOTNA CREEK UNIT COUNTY:KENAI STATE:ALASKA uo!ss!u~u~oo 'suoo S~O ,g I!0 e>tsel¥ TAPE INFORMATION FILE:LIS .001 FILE INTERVAL: START= 11110.000 END= 9790.000 DEPT 11110.000 9790.000 AC ACQ CAL RILD RILM SP T2R2 TEMP TTEN -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 CHT CILD GR RFOC SPD TlR1 TlR2 T2R1 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 COMPANY:ARCO ALASKA INC. WELL:SCU 33,~ -8 FIELD:SOLDOTNA CREEK UNIT COUNTY:KENAI STATE: RECEIVED OCT 1 1990 Alaska Oil & Gas Cons. Commission Aachorag~ FILE:LIS .002 FILE INTERVAL: START= 11190.000 END= 10880.000 DEPT 11190.000 10880.000 AC ACQ CAL RILD RILM SP T2R2 TEMP TTEN -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 CHT SPD -999.250 -999.250 -999.250 -999.250 CILD TlR1 -999.250 -999.250 -999.250 -999.250 GR TlR2 -999.250 -999.250 -999.250 -999.250 RFOC T2R1 -999.250 -999.250 -999.250 -999.250 COMPANY:ARCO ALASKA INC. WELL:SCU 33A-8 FIELD:SOLDOTNA CREEK UNIT COUNTY:KENAI STATE: FILE:LIS .003 FILE INTERVAL: START= 11180.000 END= 9840.000 DEPT 11180.000 9840.000 AC ACQ CAL RILD RILM SP T2R2 TEMP TTEN -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 CHT SPD -999.250 -999.250 -999.250 -999.250 CILD TlR1 -999.250 -999.250 -999.250 -999.250 GR TlR2 -999.250 -999.250 -999.250 -999.250 RFOC T2R1 -999.250 -999.250 -999.250 -999.250 COMPANY:ARCO ALASKA INC. WELL: SC~~A~~/~'---'" "~ FIELD:SOI~lTN2%--CREEK UNIT COUNTY:KENAI STATE:ALASKA FILE:LIS .004 FILE INTERVAL: START= 10560.000 END= 10310.000 DEPT CAL CHT GR SPD TTEN CN DEV HRD1 HRD2 LSN PE PORZ SFT2 SHR SSD SSN ZCOR ZDEN CR2 RB 10560.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 10310.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 COMPANY:ARCO ALASKA INC. WELL:SCU 33A-.8 FIELD:SOLDOTNA CREEK UNIT COUNTY:KENAI STATE: FILE:LIS .005 FILE INTERVAL: START= 11160.000 END= 9910.000 DEPT 11160.000 CAL CHT GR SPD TTEN CN DEV HRD1 HRD2 LSN PE PORZ SFT2 SHR SSD SSN ZCOR ZDEN -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 CR2 RB -999.250 -999.250 9910.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 COMPANY:ARCO ALASKA INC. WELL:SCU 33A-8 FIELD:SOLDOTNA CREEK UNIT COUNTY:KENAI STATE:ALASKA FILE:LIS .006 FILE INTERVAL: START= 11110.000 END= 9790.000 DEPT CAL CHT GR SPD C025 CILD RFOC RILD TlR2 T2R1 T2R2 TEMP TTEN RILM AC SP ACQ TlR1 11110.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9790.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 COMPANY:ARCO ALASKA INC. WELL:SCU 33A-8 FIELD:SOLDOTNA CREEK UNIT COUNTY:KENAI STATE:ALASKA FILE:LIS .007 FILE INTERVAL: START= 11190.000 END= 10880.000 DEPT CAL CHT GR SPD C025 CILD RFOC RILD TlR2 T2R1 T2R2 TEMP TTEN RILM AC SP ACQ TlR1 11190.000 10880.000 -999.250 -999.250 -999.2 -999.250 -999.250 -999.2 -999.250 -999.250 -999.2 -999.250 -999.250 -999.2 -999.250 -999.250 -999.2 -999.250 -999.250 -999.2 50 50 50 50 50 50 -999.250 -999.250 -999.250, -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 COMPANY: ARCO ALASKA INC. WELL:SCU 33A-8 FIELD:SOLDOTNA CREEK UNIT COUNTY:KENAI STATE:ALASKA FILE:LIS .008 FILE INTERVAL: START= 11180.000 END= 9840.000 DEPT CAL CHT GR SPD TTEN AC ACQ C025 CILD RFOC RILD RILM SP TlR1 TlR2 T2R1 T2R2 TEMP 11180.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9840.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 COMPANY:ARCO ALASKA INC. WELL:SCU 33A-8 FIELD:SOLDOTNA CREEK UNIT COUNTY:KENAI STATE:ALASKA FILE:LIS .009 FILE INTERVAL: START= 10560.000 END= 10310.000 DEPT CAL CHT GR SPD TTEN CN CR2 DEV HRD1 HRD2 LSN PE PORZ RB SFT2 SHR SSD SSN ZCOR ZDEN 10560.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 10310.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 COMPANY: ARCO ALASKA INC. WELL:SCU 33A-8 FIELD:SOLDOTNA CREEK UNIT COUNTY:KENAI STATE:ALASKA FILE:LIS .010 FILE INTERVAL: START= 11160.000 END= 9910.000 DEPT CAL CHT GR SPD TTEN CN CR2 DEV HRD1 HRD2 LSN PE PORZ RB SFT2 SHR SSD SSN ZCOR ZDEN 11160.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9910.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 PROGRAM: LISCAN REVISION: 5.2 Start of execution: Thu 17 JAN 91 3:40p **** REEL HEADER **** LIS 91/ 1/17 AWS 01 **** TAPE HEADER **** LIS 91/ 1/17 PART NUMBER: W5790-MICRO RFCEIVED JAN ,? ~ !9nl Alaska Oil & (~as uorls. ~ommJssior] /mchora[l~ O1 FILE # 1 LIS .001 **** FILE HEADER **** 1024 CN : ARCO ALASKA WN : SCU 33A-8 FN : SOLDOTNA CREEK UNIT COUN : KENAI STAT : ALASKA * COMMENT RECORD * API NO. 50-133-20241. PDK-100 LOGGED ON 10-28-90. 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96499.75 0.5927165 24.17004 259.2671 101934.0 0.6781373 25.24342 247.9460 99268.81 0.4557858 24.67245 241.5240 106861.5 21.36673 21.88860 0.0000000E+00 29.19633 21.85301 20.65291 0.0000000E+00 31.82014 18.69220 20.99791 0.0000000E+00 29.48671 18.02586 19.99800 0.0000000E+00 23.67404 16.15039 19.99800 0.0000000E+00 26.'14098 17.12289 19.99800 0.0000000E+00 9.249418 19.86537 19.99800 0.0000000E+00 26.41754 20.08379 19.76221 0.0000000E+00 29.96030 20.88402 20.23380 0.0000000E+00 30.76031 20.25314 19.99800 0.0000000E+00 31.61989 21.36890 20.76210 0.0000000E+00 22.37480 1.973007 19543.04 15116.34 302660.4 1.837927 20440.66 16384.58 307978.9 1.921361 22307.00 16182.34 303941.7 1.921287 21543.39 16446.14 305029.6 1.885904 21711.18 16041.52 303828.4 1.912896 21496.27 14046.22 263652.4 1.820388 19609.43 15269.03 287075.7 1.820552 21120.50 15001.65 287037.5 1.850325 20915.32 15877.61 293420.5 1.823397 22402.72 15353.02 291974.9 1.809469 21435.42 16684.07 301765.1 1215. 198 18.41011 5580.000 5077.332 1032.403 18.72441 5530.000 7073.543 1318.883 18.19405 5480.000 5266.855 1049.084 19.53908 5430.000 4958.957 985.5171 19.68301 5380.000 5232.578 978.4631 19.39410 5330.000 5978.227 1129.716 18.47678 5280.000 4195.457 895.2700 21.00317 5230.000 5327.469 1000.901 19.22896 5180.000 5242.219 1066.699 19.19322 5130.000 -999.2500 -999.2500 -999.2500 2355.738 9.735294 50.94501 1119.516 2325.120 9.385191 54.87300 2231.349 2358.475 10.04478 83.35600 1099.105 2350.890 10.15382 60.33401 1054.610 2349.604 10.01359 88.83701 1205.636 2340.341 10.05435 60.20200 1547.604 2324.814 9.731806 89.47400 770.8669 2303.687 10.04445 79.75302 1215.314 2366.590 9.982750 66.36699 1187.029 2293.137 9.844952 -999.2500 -999.2500 -999.2500 -999.2500 0.4218925 21.44296 203.7570 91282.44 0.4910129 23.17209 218.8850 100538.3 0.3511820 17.69005 268.4900 100198.2 0.5638193 23.52850 247.0080 99340.50 0.2880580 23.35545 255.3170 99873.75 0.5693165 22.52483 209.6200 100138.1 0.5113096 20.57410 244.1130 99414.81 0.6701261 26.57689 189.5640 100047.8 0.2731424 22.61096 212.0880 105905.2 0.3934516 22.72710 -999.2500 -999.2500 -999.2500 -999.2500 18.63228 20.34300 0.0000000E+00 15.53677 19.91762 19.99800 0.0000000E+00 24.20862 16.66609 19.99800 0.0000000E+00 36.32799 20.31772 19.99800 0.0000000E+00 34.27061 20.81268 20.23380 0.0000000E+00 31.02789 21.26532 19.99800 0.0000000E+00 28.34161 19.06033 23.23351 0.0000000E+00 37.48914 22.36644 22.99770 0.0000000E+00 29.37993 21.20673 22.23360 0.0000000E+00 22.41734 20.55598 22.99770 -999.2500 -999.2500 -999.2500 -999.2500 1.859649 22701.86 14457.63 270702.3 1.839612 20545.75 16516.98 302083.3 1.905868 22030.12 15448.86 298812.7 1.870439 21322.32 14962.90 294751.8 1.875312 20529.96 15292.47 296925.5 1.807742 20853.86 15777.44 294794.5 1.841079 21469.59 14566.14 294720.9 1.899639 20044.47 15413.93 296437.2 1.860657 21231.29 16021.10 307868.9 1.906284 21931.23 -999.2500 -999.2500 -999.2500 -999.2500 TOTAL DATA RECORDS : 226 STARTING TAPE DEPTH = 6480.00 ENDING TAPE DEPTH = **** FILE TRAILER **** 5130.00 **** REEL HEADER **** LIS 91/ 1/17 AWS 01 **** TAPE HEADER **** LIS 91/ 1/17 01 FILE # 2 LIS .001 **** FILE HEADER **** 1024 CN : ARCO ALASKA INC. WN : SCU 33A-8 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 BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 14 RBOR 15 RICS 16 RIN 17 SGMA 18 SPD 19 SS 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 11070.000 0.0000000E+00 650.0000 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 5.000000 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 150.0000 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 -1.000000 0.0000000E+00 11020.000 12511.76 1932.648 15.09858 158.8210 4309.961 3300.376 11.98092 373.9050 96381.94 0.1874521 15.98144 0.0000000E+00 123.7662 15.79305 22.99770 20980.56 314242.1 1.664043 30530.30 10970.000 10150.63 1533.460 15.79429 120.7390 3109.132 3117.938 12.10131 309.5649 96826.12 0.2627153 18.24855 0.0000000E+00 51.89078 18.72612 22.99770 19310.33 313219.0 1.683981 28486.89 10920.000 12483.41 1957.232 15.04401 91.54799 4325.258 3192.947 11.62753 248.1910 99303.19 0.3351129 15.89746 0.0000000E+00 39.46725 15.93975 22.99770 21335.35 323410,2 1.714613 31230.87 10870.000 8260.926 1404.426 15.34377 108.7660 2402.488 2908.076 11.80223 233.2770 94963.50 0.5085425 19.25786 0.0000000E+00 54.80379 18.43800 23.55571 17584.70 298212.9 1.645560 25657.14 10820.000 7689.637 1283.845 18.22527 165.8320 1719.004 2810.799 12.31403 284.9351 107314.4 0.2872421 22.76097 0.0000000E+00 60.43878 21.39679 16.99831 18640.70 324349.8 1.779038 27537.29 10770.000 11671.28 2033.326 15.07886 67.42801 3921.956 2941.420 12.17607 260.1431 110349.1 0.4156445 16.53484 0.0000000E+00 28.43834 15.59617 26.40361 21878.68 342495.6 1.749484 31601.68 10720.000 10244.27 1685.348 15.88055 93.02802 2924.376 2755.317 11.90718 263.5400 109104.4 0.4769421 19.02374 0.0000000E+00 32.96024 17.93819 26.99730 20682.27 325651.0 1.722606 30263.75 10670.000 11020.61 1858.247 15.71591 10620.000 9415.832 1449.247 15.47735 10570.000 11240.85 1785.744 15.22653 10520.000 12199.12 2061.836 14.87071 10470.000 7706.234 1335.357 16.95839 10420.000 10784.55 1764.974 15.48162 10370.000 7681.566 1254.297 16.99777 10320.000 11662.96 1888.833 15.05308 10270.000 7274.992 1211.909 17.36603 10220.000 10461.30 1722.025 15.35571 10170.000 7003.602 1169.508 16.98070 90.94200 3497.204 2702.283 11.34024 53.64101 2769.959 2664.328 11.58728 77.70801 3428.572 2781.749 12.06738 46.20500 4132.363 2641.063 11.75607 107.5980 1778.699 2574.566 12.41431 70.55002 3090.787 2609.170 11.87439 91.25500 1766.595 2586.187 12.21028 72.24101 3613.819 2597.042 11.78506 102.0500 1597.135 2562.306 12.42337 84.03500 3069.073 2564.230 11.91978 97.25200 1428.821 2502.792 12.60106 262.1689 111753.1 0.3059405 17.59192 182.3160 97799.00 0.3663825 18.58362 255.5240 108158.7 0.3726245 18.14381 259.6060 112157.5 0.2567885 16.69865 272.7000 107984.8 0.6356775 22.30573 288.2471 108007.0 0.3290945 18.71124 218.5350 103582.9 0.5951030 22.40862 275.7539 110558.9 0.3317572 17.71164 297.1030 104168.9 0.5431854 22.89134 245.9670 105880.1 0.3098397 18.54466 286.2080 104961.1 0.4935901 23.86122 0.0000000E+00 29.58258 16.56270 26.99730 0.0000000E+00 27.40530 19.46457 23.99760 0.0000000E+00 26.02113 17.89316 24.99750 0.0000000E+00 21.70944 16.24640 22.99770 0.0000000E+00 40.87236 20.86746 22.99770 0.0000000E+00 26.81079 17.98860 22.99770 0.0000000E+00 39.09686 22.08978 23.00360 0.0000000E+00 31.40625 17.51057 23.03340 0.0000000E+00 38.67236 22.52054 18.99811 0.0000000E+00 29.62971 17.70181 17.99820 0.0000000E+00 41.62711 23.02782 24.99750 21396.85 333181.1 1.761847 30724.07 19005.63 300800.2 1. 694388 28132.28 21573.82 328498.7 1.691390 31928.85 22857.68 338946.9 1.703333 33608.71 18870.27 319960.5 1.708740 27878.38 21279.37 325071.1 1.662028 31755.84 18470.94 309422.3 1.697981 27732.52 22223.10 332503.9 1.686560 33066.94 18228.77 314143.9 1.721252 27340.45 20636.70 318035.9 1.695352 30487.58 18051.85 313465.9 1. 672306 27008.94 10120.000 6711.602 1055.697 16.67538 10070.000 9308.980 1513.538 15.83194 10020.000 7947.477 1346.713 16.29218 9970.000 8605.207 1459.932 16.00853 9920.000 8509.277 1425.244 15.64404 9870.000 4570.113 794.0310 21.91646 9820.000 5035.754 876.1731 20.63826 9770.000 4303.754 729.0801 23.12914 9720.000 4777.398 863.1292 20.96188 9670.000 6821.363 1087.983 19.79730 9620.000 4883.484 751.8262 23.21989 123.3120 1569.523 2482.594 11.80531 61.27200 2546.954 2503.455 11.72742 83.88402 1928.250 2492.682 .11.60783 98.61201 2267.656 2483.387 11.78699 76.88800 2215.513 2490.144 11.27053 39.22499 1036.412 2460.431 13.72997 70.57202 1159.130 2438.411 13.09758 50.73201 845.2202 2435.723 12.78685 59.38202 1015.243 2453.116 13.42131 30.67700 2025.569 2444.624 13.04096 53.51001 1215.194 2427.823 14.55978 254.7560 94412.31 0.4089018 22.28992 221.7320 105226.1 0.3578153 19.77437 271.3691 104780.6 0.4123809 21.75748 235.2680 101837.1 0.4148905 20.56995 234.1890 102543.1 0.3751385 20.44710 185.4750 94166.25 0.5365548 22.86313 190.0230 93131.44 0.4460585 22.29608 218.5820 91717.31 0.5121405 24.71198 195.0610 95500.87 0.8616526 23.41704 199.4330 96800.37 0.5592101 18.68506 180.0840 88677.87 0.6440352 21.24590 0.0000000E+00 35.10986 24.15135 25.40370 0.0000000E+00 31.85503 19.80191 23.99760 0.0000000E+00 30.62875 20.92038 24.59131 0.0000000E+00 32.06706 19.83658 24.96181 0.0000000E+00 28.12401 20.34027 23.99760 0.0000000E+00 18.98952 23.99846 24.99750 0.0000000E+00 23.48921 22.52827 23.99760 0.0000000E+00 20.11668 24.95540 24.03329 0.0000000E+00 26.14006 22.61375 24.99750 0.0000000E+00 18.49055 19.85329 25.00340 0.0000000E+00 22.44148 23.24756 25.93221 16861.49 284557.0 1.680942 25523.68 19944.85 317717.6 1.677056 29943.34 18799.85 306990.5 1.687329 28217.00 19153.53 308106.4 1.666698 28911.24 19235.05 294304.7 1.640283 29045.32 14058.54 297434.2 1.946190 19031.70 14474.19 300410.9 1.835965 19842.32 13484.27 293611.6 1.981878 18200.61 14392.86 302402.4 1.908745 19499.80 15994.75 317448.4 1.949350 21521.80 13302.42 304263.6 1.993253 17382.97 9570.000 -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 : 251 STARTING TAPE DEPTH = 11070.00 ENDING TAPE DEPTH = **** FILE TRAILER **** 9570.00 **** REEL HEADER **** LIS 91/ 1/17 AWS 01 **** TAPE HEADER **** LIS 91/ 1/17 01 FILE # 3 LIS .001 **** FILE HEADER **** 1024 CN : ARCO ALASKA INC. WN : SCU 33A-8 FN : COUN : STAT : * 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 CODE SAMPLE# UNIT 68 1 CPS 68 1 CPS 68 1 DIM 68 1 API 68 1 CPS BYTES 4 4 4 4 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 G1 LS RICS (TYPE# BKL G2 MON RIN o) 966 BYTES BKS GElS MSD SGMA CCL GR RATO SPD CSS ISS RBOR SS 11080.000 -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 11030.000 5528.891 993.0522 19.30270 148.1190 1105.810 2169.027 12.18691 225.3120 93311.75 0.5389498 24.94214 0.0000000E+00 69.42003 22.31114 15.99840 15227.85 296183.6 1.764856 22194.48 10980.000 8412.031 1465.698 17.51926 100.4350 2596.654 2387.983 11.93713 244.4720 91078.37 0.3022741 17.89978 0.0000000E+00 45.64157 16.71947 14.99850 16947.82 295910.5 1.852182 24445.11 10930.000 10379.99 2151.286 15.35420 77.10501 3422.887 2859.588 11.73124 215.6990 105916.7 0.3242901 16.69493 0.0000000E+00 36.42180 12.83556 14.10780 19814.32 329764.5 1.742902 27564.31 10880.000 5295.762 961.3101 18.70392 127.2230 1099.819 2892.092 12.20962 278.6670 86347.44 1.056581 24.00710 0.0000000E+00 63.41640 21.73962 22.76190 14265.80 271605.6 1.778209 20989.91 10830.000 3973.344 759.5222 20.03207 149.1740 680.1160 2877.055 12.42394 281.2041 81128.62 0.8540339 27.34581 0.0000000E+00 67.69835 24.09541 24.99750 12682.78 258110.9 1.716653 18320.46 10780.000 -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 **** 51 11080.00 ENDING TAPE DEPTH = 10780.00 **** TAPE TRAILER **** LIS 91/ 1/17 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 548 **** REEL TRAILER **** LIS 91/ 1/17 AWS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 549 TOTAL RECORDS IN THIS PHYSICAL REEL: 549 End of execution: Thu 17 JAN 91 3:41p Elapsed execution time = 40.32 seconds. SYSTEM RETURN CODE = 0