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Home My WebLink About180-108 i a • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1 b. Well Class ■ 20AAC 25.105 20AAC 25 110 ❑ Exploratory ❑ Stratigraphic ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero - - Development ❑ Service 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 12/8/2012 180 - 108 * 312 - 306 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 10/20/1980 50 029 - 20511 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: / 14 . Well Name and Number: Surface: 12/6/1980 CHEV181112 aka PBU TR18 -11 -12 - 809' FSL, 3893' FEL, Sec. 07, T11N, R12E, UM 8. KB (ft above MSL): 73 15. Field / Pool(s) Top of Productive Horizon: 3013' FNL, 3375' FEL, Sec. 18, T11N, R12E, UM GL (ft above MSL): Prudhoe Bay / Prudhoe Bay • Total Depth: 9. Plug Back Depth (MD +TVD) 3695' FNL, 3582' FEL, Sec. 18, T11N, R12E, UM Surface Surface 4b. Location of Well (State Base Plane Coordinates, NAD : 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x - 598665 • y - 5966158 " Zone ASP4 10906' 9308' , ADL 047450 & 028262 ' TPI: x- 599246 y- 5962343 Zone- ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x- 599051 Y 5961659 Zone- ASP4 None 18. Directional Survey: 0 Yes 1E1 No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIL / BHCS / FDC / CNL / GR / Cal, HDT, NGT, RFT, CBL N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" Conductor Surface 110' _Surface 110' 26" 7 cu yds Concrete 13 -3/8" 72# L -80 Surface 2684' Surface 2684' 17 -1/2" 3720 cu ft Permafrost II 9 -5/8" 47# L -80 Surface 9750' Surface 8428' 12 -1/4" 1390 cu ft Class 'G', 280 cu ft PF 'C' 7" 29# L -80 9243' 10906' 8030' 9308' 8-1/2" 354 cu ft Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD / TVD) None None RECEIVED 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION ?❑ Yes 1E1 No JAN 0 3 2013 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 1493' - 1503' Punch AOGCC Surface - 1503' 188 Bbls Class 'G' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, Gas Lift, etc Not on Production N/A Date of Test Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RgpMS JAN 0 4 2013 • SCANNED MAR 01 2013 Form 10 -407 Revised 10/2012 CONTINUED ON REVERSE �, e � .� ,✓ Submit Original Only 29. GEOLOGIC MARKERS (List all formations an rkers encounter 30. FORMATION TESTS NAME TVD Well Tested'. Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9813' 8478' None Shublik 9851' 8508' Ivishak 10026' 8645' Formation at Total Depth: 31. List of Attachment. Summary of Daily Work, Well Schematic Diagram, Photo of Welded Plate 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Aras Worthington, 564 -4102 Email: Aras.Worthington @bp.com Printed Name: oe stufk Title: Drilling Technologist Signature A ` Phone 564 -4091 Date: I /3/13 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 Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only • • CHEV181112, Well History Date Summary 09/01/12 9 5/8" Casing= 100 psi. 13 3/8" Casing= 55 psi. Temp= SI PPPOT-T PPPOT -IC (FAIL) P&A. PPPOT-T: LDS on TBG head are all backed out indicating there is no TBG hanger in Well. * ** Wellbore Schematic shows no TBG in well * ** Do not Function LDS on TBG Head. PPPOT -IC: Attempted to Bleed void with SBS. void would not bleed down (fluid). Torqued LDS to 600 ft/Ibs. Bled void to 0 psi. with SBS. Removed 1" NPT, installed alimite fitting. Pumped through void, good returns. Attempted to pressure up void for test, void would not build pressure. Removed alamite fitting, installed 1" NPT. Recommend bleeding down WHP's and energizing secondary seals with plastic packing. 09/01/12 T /I /0= 250/55/0 Conducted PJSM. Performed LTT on OA and IA valves. Pass. Removed blinds, added second valves to both existing IA and OA valves. Torqued all flanges to specs., pressure tested thru needle valves against existing OA and IA valves 250 /Iow..3500 /high..pass, for shell tests.(see chart in TRP folder). 09/05/12 T /I /0 = SI /50/0 +. Temp = SI. IA & OA FLs (Pre P&A). IA FL @ surface. OA FL near surface. MV, IA, OA = C. 09/08/12 1/0 =55/0, MIT 9 5/8" PASSED to 2500 psi, MIT 9 5/8 "x13 3/8" PASSED to 1000 psi (P &A wellbore to surface -no tubing in well) Pressured up IA with 1.3 bbls of diesel to reach 2495 psi. MIT -IA lost 58 psi in the 1st 15 minutes and 12 psi in the 2nd 15 minutes for a total of 70 psi in a 30 minute test. Bled IAP. Rig up to OA. Pressured up OA with 2.3 bbls diesel to reach 1000 psi. MIT -OA lost 32 psi in the 1st 15 minutes and 10 psi in the 2nd 15 minutes for a total of 42 psi in a 30 minute test. Bled OAP. Master,IA,OA = Closed. FWHP's =0/0. 09/12/12 T /I /0 =0/0/0 Conducted PJSM. Barrier= Master Valve, verified by pressure testing thru I.A. needle valve against bottom of Master valve,(no tubing in well, communication verified) 500 psi. for 30 min. Monitored top side of Master valve for 0 psi. build up. Pass. Bled I.A. to 0 psi. monitored for 30 min.- 0 build up Pass. Removed blind flange from top of Master valve. Installed dry hole tree on existing 6 3/8" Master valve. Torqued flange to specs. Pressure tested thru tree cap needle valve against top side of existing Master valve, for a shell test, 250 /Iow..3000 /high.. 5 min. each Pass (see chart in TRP folder) No problems. 09/17/12 DRIFT TO TOC W/ 3.70" CENT & 3.00" S.BAILER TO 2357' SLM(sample of cement) * ** AOGCC INSPECTOR CHUCK SCHEVE DECLINED TO WITNESS * * *. 09/22/12 INITIAL T /I /0= 20/0/0. SPOT EQUIPMENT. RIG UP. RIH WITH HEAD /CCL /MPD /FIRING HEAD/TUBING PUNCHER/BOW DECENTRALIZER. OAL = 28.5 FT, OAW = 170 LBS, MAX OD = 1.6875 ". BARRIERS ARE GREASE HEAD AND LUBRICATOR. LOG TIE IN PASS. CONFIRM SHOOTING WINDOW OF 1493 TO 1503 TO BE 2 FT ABOVE COLLAR. PERFORM SHOOTING PASS. CCL STOP DEPTH = 1487.3 FT, CCL TO TOP SHOT = 5.7 FT, TUBING PUNCHED = 1493 TO 1503 FT. BEGIN TO POOH. HOLES IN GUN. RIG DOWN. MOVE OFF WELL. CLOSE PERMIT. FINIAL T /I /0= 20/0/0. 09/27/12 CTU #8 w/ 1 -3/4" CT (CTV= 33.9). Objective -circ out Arctic Pack and PxA w/ cement. Move CTU from V- 207. Park on edge of Pad and wo rig up. Spot unit. NU BOPE. 09/28/12 Heat UR tanks for Coil to 160 *, heat DSL transport to 90 *. Rig to CTU and pump 50 bbls diesel @ 160 *. RDMO. Page 1 of 5 • • • • CHEV181112, Well History Date Summary 09/28/12 CTU #8 w/ 1 -3/4" CT (CTV= 33.9). Objective -circ out Arctic Pack and PxA w/ cement. Finish RU. Open well to zero psi. RIH w/ 3.0" JS nozzle assy displacing 9 -5/8" wellbore of 10.0# NaCI /NaBr with 160F leftover 8.9# brine and FW to tag at 2360'. Circ 9 5/8" to warm Wellbore /arcticPak. Returns up to 128F, PJSM, pump 50 bbls 160F diesel down CT and into IA at 1500' & let soak, chased w/9.8 brine, 9 5/8" loaded w/9.8 brine. IA returns looked like Brine. Chased 9.8 brine OOH w/ 160F FW. POH. Pumped 50 bbls Safe -Surf-O down 9 -5/8" and up 9 -5/8" x 13 -3/8" annulus to clean any possible hydrocarbons from wellbore. Followed SSO w/ 6 bbls red dye for volume calcs and got red dye back at 186 bbls (calc volume is 197 bbls). With wellbore and IA displaced to FW, performed CMIT to 1000 psi. Immediately after pressure reached 1000 psi, OA abruptly rose from 5 psi to 1100 psi. Monitored pressures for 30 min and WHP = —IAP =810 psi, OAP =957 psi and all are falling slowly. Bled off WHP /IAP to zero and OAP was 465 psi and bleeding off at 1 psi /3 seconds. Discuss w/ WIE. Monitor OAP for — 2 hrs and lost 370 psi. WHP and IA showed vac probably due to wellbore cooling. 09/29/12 CTU #8 w/ 1 -3/4" CT (CTV= 33.9). Objective -circ out Arctic Pack and PxA w/ cement. Continue to monitor OAP. Repump red dye down 9 -5/8" and up 9 -5/8" x 13 -3/8" annulus to OTT. Dye immediately showed up at retum tank. Determine plan forward. Will run Caliper log & pump Circ out again. RIH w/ 3" nozzle assy and begin rewarming wellbore. 09/30/12 CTU #8 w/ 1 -3/4" CT (CTV= 33.8). Objective -circ out Arctic Pack and PxA w/ cement. Finish RIH and tag PBD at 2360'. Circ hot FW to warm wellbore while WO vac trucks. Pumped 50 bbls diesel into 9 5/8" x 13 3/8" Ann for soak, w/9.8 Brine, Circ out diesel from OA @ 4 BPM w /fresh water. Returned -- 82 bbl's of Arctic Pack back. RIH, spot 50 bbl's Safe -Surf-O in OA, displ w /water at 5 BPM down backside /up OA. w /water. Pump dye to check volumes. 10/01/12 CTU #8 w/ 1 -3/4" CT (CTV= 33.8). Objective -circ out Arctic Pack and PxA w/ cement. Finish pump dye to verify cement volume. WO cementers -3 rig jobs on schedule before ours. RU Cmt unit, Pump 188 bbl's 15.8 "G" cmt down 9 5/8" taking returns up 9 5/8" x 13 3/8" Ann. Had 4 bbl's 15.8 returned to surface thru _ return MM. 9 5 /8 "csg & 13 3/8" x 9 5/8 "Ann is full of 15.8 cmt. From 1500' & up. Clean up surface equipment and tree vlv's. 10/04/12 DRIFT 3.5" CENT., S- BAILER TO TOC @ 9' SLM. RECOVERED TRACE CEMENT IN S- BAILER ATTEMPTED MIT -T TO 3,000 PSI. UNABLE TO STABILIZE, PRESSURE FALLING 100+ PSI /MIN. 10/07/12 9 5 /8 /OA = 110/109. Pressure Test TOC to 3000 psi - PASSED (P&A Wellbore). FL in 9 5/8 casing near surface. Used 14 gallons diesel to increase pressure from 110 psi to 3000 psi, tested 7 times, see log for details. Bled 9 5/8 casing from 2700 psi to 0 psi returning 4 gallons. Job Complete. Final WHPs = 0/110. SV, MV, 2nd MV = C. IA = inner valve Closed, outer valve Open. OA = inner valve Closed, outer valve Open. 10/21/12 9 5 /8 /OA = 20/85. Temp = SI. Remove fluids from TBG, IA , and OA. Install lifting eye tree cap and lifting strap. 9 5/8 FL @ surface. OA FL near surface. Bled 9 5/8 to 0 psi in 1 min. Bled OAP to 0 psi in 20 min. Monitor for 1 hour. 9 5/8 stayed @ 0 psi, OAP increased 60 psi. Bled OAP 2 more times. monitor for 1 hr. OAP increased 53 psi, bled OAP to 0 psi upon departure. Removed —10 gallons fluid from 9 5/8, Installed lifting eye tree cap and lifting strap. Job incomplete. Final WHPs = 0/0. SV, MV, MV, IA, IA, OA, OA = C. 16:00. 10/23/12 9 5 /8 /OA = 0/62 Temp = SI. Bleed OAP to 0 psi (P&A). OA FL near surface. Bled OAP to slop trailer from 62 psi to 0 psi and held open bleed for 1 hr. Monitor for 1 hr. OAP increased to 32 psi. Held open bleed for 3 hrs. Monitor for 15 min. OAP increased 10 psi. Final WHPs = 0/10. MV, IA, IA, OA, OA = C. Page 2 of 5 • • CHEV181112, Well History Date Summary 10/25/12 T /I /0 = ?/0/52. Temp =SI. Hold open bleed on OAP (P&A). No FL or WH. TBG, IA & OA cemented to surface. OAP increased 42 psi since bleed on 10- 23 -12. Bled OAP from 52 psi to 0 psi in < 1 min, gas. Held open bleed for 3 hrs 30 min. Monitor for 30 min. OAP increased 20 psi. SV,MV,MV,IA,IA,OA,OA = Closed. No WV or SSV. 10/26/12 /I /0 = ?/0/30. Temp = SI. WHPs (P&A) post bleed. No FL or well house. OAP increased 10 psi ovemight. SV,MV, MV, IA, IA, OA, OA =C. No WV or SSV. NOVP. 15:25. 10/28/12 9 5 /8 /OA = 0/45 Temp = SI. Bleed OAP to 0 psi (P&A). OA FL near surface. Bled OAP to slop trailer from 45 psi to 0 psi in >1 min and held open bleed for 6 hr. Monitor for 1 hr. OAP increased psi. Monitor for 1 hr. OAP increased 26 psi. Job incomplete. Final WHPs = 0/26. MV, IA, IA, OA, OA = C. 16:10. 10/28/12 9 5/8/0A = 0/26 Temp = SI. Hold open bleed on OAP (P&A). Heater on SC and working. OA FL near surface. Bled OAP to bleed trailer from 26 psi to 0 psi in 1 min and held open bleed for 5 hrs. Monitor for 30 min. OAP increased 20 psi. Job incomplete. Final WHPs = 0/20. MV, IA, IA, OA, OA = C. 0330. 10/29/12 9 5 /8 /OA = 0/25. Temp = SI. Bleed OAP to 0 psi (P &A). OA FL near surface. Bled OAP to slop trailer from 25 psi to 0 psi in >1 min and held open bleed for 6 hrs. Monitor for 1 hr. OAP increased 12 psi. Job complete. Final WHPs = 0/12. MV, IA, IA, OA, OA = C. No WV, SSV. 1600. 10/30/12 9 5/8/0 =0/20. Temp = SI. Bleed OAP to 0 psi & hold open bleed for shift. (P & A). OA FL = near surface. Bled OAP from 20 psi to 0 psi in <30 seconds & maintained open bleed for 4 hours. Rig down & monitor for 30 minutes for end of shift. No change in 9 5/8 during bleed or monitor, OAP increased to 8 psi during 30 minute monitor. Final WHP's = 0/8. All WH Valves = Closed & flagged. 10/31/12 9 5/8/ 0 = 0/12. Temp = SI. Bleed OAP to 0 psi & hold open bleed untill end of shift. (P & A). OA FL = Near surface. Bled OAP from 12 psi to 0 psi in <15 seconds & held open bleed for 7 hours, rig down for end of shift & monitor for 30 minutes. No change in 9 5/8" , OAP increased 3 psi during 30 minute monitor. Final WHP's = 0/3. Wellhead valves all closed and flagged. 0400. 10/31/12 9 5/8/0 = 0/16. Temp = SI. Hold open bleed on OAP (P&A). OA FL = near surface. OAP increased 8 psi since last shift bleed. Bled OAP from 16 psi to 0 psi in <30 seconds & maintained open bleed for 7 hours. Rig down, monitor for 30 minutes. No change in 9 5/8 during bleed, OAP increased to 4 psi. Final WHP's = 0/4.. All WH Valves = Closed & Flagged.. NOVP. 16:30 hrs. 11/01/12 I/O = 0/8. Temp = SI. Hold open bleed on OA (P&A). OA FL near surface. OAP increased 5 psi in 6 hrs. Bled OAP to 0 in <1 min. Held open bleed for 4 1/2 hrs. Monitored for 30 min. OA increased 3 psi. OA FL unchanged. Final WHPs = 0/3. All wellhead valves closed and flagged. 11/02/12 I/O = 0/9. Temp = SI. Hold Open Bleed on OA (P&A). OA FL near surface. OAP increased 6 psi in 5.5 hrs. Bled OAP to 0 psi in <1 min. Held open bleed for 6.5 hrs. Monitored for 30 min. OAP increased 3 psi. Final WHPs = 0/3. All wellhead valves closed and flagged. NOVP. 1600. 11/03/12 9 5/8/0 = 0/10. Temp = SI. Bleed OAP to 0 psi & hold open bleed untill end of shift. (P & A). Bled OAP from 10 psi to 0 psi in <15 seconds, maintained open bleed for 7 hours, monitor for 30 minutes during rig down for end of shift. No change in 9 5/8 during bleed or monitor, OAP increased 4 psi during 30 minute monitor. Final WHP's = 0/4. WH valves closed and flagged. Page 3 of 5 • • CHEV181112, Well History Date Summary 11/03/12 9 5/8 / 0 = 0/7 . Temp = SI. Monitor WHPs (P & A). 9 5/8 unchanged and OAP increased 3 psi since 11/03/2012 night shift bleed. WH Valves closed and flagged. NOVP. 1630 hrs. 11/04/12 9 5/8/0 = 0/7. Temp = SI. Hold open bleed on OA (P & A). Bled OAP from 7 psi to 0 psi in <5 seconds, maintained open bleed for 6.5 hrs. Monitored for 30 min. OAP increased 2 psi. Final WHPs = 0/2. WH valves closed and flagged. 11/05/12 9 5/8 / OA = 0/7. Temp = SI. Bleed OAP to 0 psi & hold open bleed until) end of shift. (P & A). OA FL = Cement to surface. Bled OAP from 7 psi to 0 psi in <15 seconds, held open bleed for 4 1/2 hours. Rig down & monitor for 30 minutes. No change in 9 5/8 ", OAP increased 3 psi during 30 minute monitor. Final WHP's = 0/3. WH valves closed and flagged. 03:00. 11/05/12 9 5/8 / OA = 0/3. Temp = SI. Hold open bleed on OA (P&A). OA FL = Cemented to surface. Bled OAP from 3 psi to 0 psi in < 1 minute, held open bleed for 4.5 hours. Monitored for 30 minutes. No change in 9 5/8 ". OAP increased 1 psi. Final WHPs = 0/1. WH valves closed & flagged. 16:00. 11/06/12 9 5/8 / 0 = 0/5. Temp = SI. Bleed OAP to 0 psi & hold open bleed until) end of shift. (P & A). Bled OAP from 5 psi to 0 psi in <15 seconds, held open bleed for 8 hours, rig down & monitor for 30 minutes @ end of shift. OAP increased 2 psi during 30 minute monitor. Final WHP's = 0/2. Wellhead valves closed and flagged. 0400. 11/07/12 9 5/8 / 0= 0/3. Temp = SI. Bleed OAP to 0 psi & monitor open bleed until) end of shift. (P & A). Bled OAP from 3 psi to 0 psi in <15 seconds & held open bleed for 7 1/2 hours, rig down & monitor for 30 minutes for end of shift. No change in 9 5/8, OAP increased 2 psi during 30 minute monitor. Final WHP's = 0/2. 0400. Wellhead valves closed and flagged. 11/08/12 9 5/8 / 0 = 0/2. Temp = SI. Bleed OAP to 0 psi. (P & A)_Bled OAP from 2 psi to 0 psi in < 10 spcnnds,.. held open bleed for 6 hours, rig down & monitor for 30 minutes for end of shift. No change in 9 5/8, OAP increased 1 psi during 30 minute monitor. Final WHP's = 0/1. Wellhead valves closed and flagged. 11/09/12 I/O = 0/3. Temp = SI. WHPs (pre P&A). OAP increased 1 psi overnight. Wellhead valves closed and flagged. 11/10/12 I/O = 0/3. Temp = SI. WHPs & LELs (pre P&A). LEL over range. Wellhead valves closed and flagged. 1000. 11/11/12 9 5/8 / OA = 0/5. Temp = SI. WHPs. Wellhead valves closed. NOVP. 1230. 11/12/12 9 5/8 / 0 = 0/3. Temp = SI. Bleed OAP to 0 psi & hold open bleed for shift. ( P & A ). Bled OAP from 3 psi to 0 psi in <15 seconds & held open bleed for 6.5 hours, SI for end of shift & monitor for 30 minutes. No change in 9 5/8, OAP increased 1 psi during 30 minute monitor. Final WHP's = 0/1 Wellhead valves closed and flagged. 03:30. 11/14/12 T /I /0= 0/0/0; Conduct PJSM; Start Barriers list; Barriers= I/A count turns, O/A Cement to surface open to atmosphere. LTT passed; Remove piggy- backed valves off I/A and 0 /A; Install blind flange and jewelry on I /'A and test to 2500 psi for 5 min. LTT passed; O/A valve left open to atmosphere. 11/14/12 T /I /0= SI /SI /0 Conducted PJSM; Start Barrier list; Barriers= Cement to surface; Monitored open bleed on OA for 30 min. w /no flow; Pulled blind flanges on both OA valves & left OA valves in open position so they could "breath" (Tagged valves to be left in the open position). Page 4 of 5 • • CHEV181112, Well History Date Summary 11/30/12 Deliver Wachs saw and power pack. R/U & cut off Rat hole pipe. Removed "insulation" from SC to attach Wachs saw. Wachs saw hung & level. Rat hole pipe cut & removed. 12/02/12 Well cut Complete. CHEV181112 20 ", 13 3/8" & 9 5/8 cut 4' below tundra level. 12/06/12 Assist LRS w/ thaw casing for Cement fill (13 3/8/' x 20 "). Thawed to 44 ". 12/07/12 Filled 20" x 13 -3/8" annulus with cement to surface. Request state inspection and approval to install weld- on cap. 12/08/12 Received State of Alaska approval to install weld -on cap. Fitted and welded cap on well with appropriate abandonment information. Received final approval upon inspection of welded cap from State of Alaska inspector Chuck Sheve to re -bury well casing. Notified Bell and Associates to perform final "as built" survey. Page 5 of 5 • , ,,,,, .., . it* 4 ,. A A ' , A % . i • . „. . . .A. * *. ` , . • • ., ■ 0.. A N . A 41111. 1411,1111%., "1141,,., . ,., • . : A • .,, • I .. • . • t ' ' 'I ', ' * ■ • N6 1 ,r4 , , , 6010”' ' * t ,, 0 . ;77 . 1 . , t 11, I A :, ,: : 1, l'''',.i'i... yi . 4 .. 4 ... , ,* • ..4 1, • • t. . - .. . ,,..,,,,,,.,..,* ,..,. "*. , 4, . 4 . . 4 0 il . 0, ;,,,',; ..**0,1v$V ., .* .. 4. •-i,,,,- .• * „. ,f ! .. .** * * * • . ' ''' * % . ' ,. * ' *. • . * . a . - * ' ' . ,„. *"%*,.., d ' ''' ' Illok . . v* * , * Y ' A 44 .. :iit, , to, . 4 : . ,, ......,. i'.. ,,,,...... ii 1 ts, it* .P.--,,,„, , ' . ,,,,,t, 'to,: * ''''' ; '' '' ' `^ 4744' '',:;; 4,:.,,** ' , o ,, , ,- •,,-,,, *. , 4•41titt .. ' .,,, .,,,,A,4 • ,• ,,,,,,,.., -• ,t,t.-: i ' A i . , *". '''' P * ' ''' 1,- *, .,.. A ,:, 11 , ' - i '''.114'14'? „,,,,,, i' ,,,, 4 ' ', '''''''. ' '''''. '' , ,,, , , TREE-1- • „WELLHEAD - ACTUATOR = C H EV 181112 411111 SAFETY NOTES: KB. ELEV = BF. BB/ = s c e c • Y I F; ( ) KOP= J �►### e e SURFACE - 1503 CEAE TT RUG (10/01/12) Angle ' C J ed .e#I datum N©_ # #► + � #i►/, � #t Datum 7VD= 88W SS 04,%111, -%%% ITBG PUNCH (09/22)12) H 1493' - 1503' I i i J 2360' - 2500' -jCevIBYT PLUG eee 113 -318" CSG, 72#, L -B0, D = 12.347" I—I 2684' H iieereiv ??? I-I TOP OF CEMENT I 40 # site J `# * 'J, . "- I 9191' H BRIDGE PLUG J I9 -5/8" CSG, 47#, 1-80, ID= 8.681' H 9750 . PERFORATION SUMuW RY REF LOG: ??? ANGLE AT TOP FERE: 1 . ' . ` . + . ' , + .,. ' . ' 1 Q426' IH TOP OF CEfAE T I Note: Refer to Rod uction DB for historical pert data # SIZE SFF NTBRVAL Opn/Sgz DATE 1•0••••• ? 4 10600 - 10620 S 2 ; _ , I 10610 I- -IRE FETID I 10735' remav►v+r 17' LNR, 29#, L -80, 0371 bpf, D = 6.184' H 1 0906' DATE REV BY CONANT'S DATE RPV BY COMaENTS (EVRON TRACT WELL 12/24180 ORIGINAL COMPLETION WELL: CHEV181112 04/08/11 JM) NAME CORRECTION FERMTNo: 980108 09/24 /12 JCMJM) TBG PUNCH (09/22/12) AR No: 50 -029- 20511 -00 01/03/13 KSB/ PJC CMT TO SURFACE (10/01/12) SEC 07, T11N, R12E, 808' FSL & 1033' PM_ BP Exploration (Alaska) 1 • • scirEE 0[F ALAs[K(A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Doug Cismoski 51,,Mt4ED AUG 1 t Z Well Interventions Manager BP Exploration (Alaska), Inc. P.O. Box 196612 g6-1 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, CHEV 181112 Sundry Number: 312 -306 Dear Mr. Cismoski: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ‘ Cathy 9 Foerster Chair DATED this /Sa of August, 2012. Encl. cfIAL STATE OF ALASKA U � ' , � R E C E I E D ri ALA CDsk OIL AND GAS CONSERVATION COM �, APPLICATION FOR SUNDRY APPROVAL AUG 0 7 2012 20 AAC 25.280 AOGCC 1. Type of Request: ® Abandon • ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. .. 180 - 108 1 Development ❑Exploratory 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 ," 50 029 - 20511 00 - 00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: /Al ---r ` . IL property line where ownership or landownership changes: CHEV 1 811 12 Spacing Exception Required? ❑ Yes ® No / rZ- 9. Property Designation: 10. Field / Pool(s): ADL 047450 & 028262 ' Prudhoe Bay / Prudhoe Bay • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10906' ' 9308' 2360' 2360' 2360', 9048', 10426' None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2684' 13 -3/8" 2684' 2684' 4930 2670 Intermediate 9750' 9 -5/8" 9750' 8428' 6870 4760 Production Liner 1663' 7" 9243' - 10906' 8030' - 9308' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None Packers and SSSV Type: None Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development ❑ Service ❑ Str 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: September 1, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ® Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564 -4102 Printed Name Doug Cismoski, P.E. Title Well Interventions Manager Prepared By Name /Number: Signature DO r Phone 564 - 4303 Date Joe Lastufka, 564 -4091 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness �/ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance s um Sundry Number: 2 1 �.. 5t .�r ) Other: A/ 0 > f N I ✓76 p e- h r 4 5 I v-i' CJ I ea. fr"e • photo CivCvi- v7?b1 - i- 6vt oFt 0 'Is i`-77 a"c) 1'1/ l d d p Iii . Subsequent Form Required: % 0 .— 40 7- 3f 4,,,,,,/„....... APPROVED BY � Approved By: , ,f 6 COMMISSIONER THE COMMISSION Date .. fi e •• r� p o or 0 ,dg 6 t' 0 N A # 2 , r.i s L �� ---rrr Submit In Duplicate �� ec eim-liz_ "if9/9A • • Summary of Proposed Work BP Exploration Alaska Inc (BPXA) P & A Program Chev181112 PTD 180 -108 API No. 50- 029 -20511 Present Well Condition The well was drilled to a depth of 10,906' MD, and is cased as follows: Casing Size Weight Grade Depth (MD) Cementing Record Conductor 20" 155# 110' 189 cu. ft. Surface 13 -3/8" 72# L -80 2684' 3720 cu. ft. Permafrost II Intermediate 9 -5/8" 47# L -80 9750' 1390 cu. ft. Class G, 280 cu. ft. Permafrost C Liner 7" 29# L -80 9243' - 10,906' 354 cu. ft. Class G Maximum Anticipated Surface Pressure (MASP) is 0 psi (all openhole and casing shoe is cemented and plugged providing hydraulic isolation) per 20 AAC 25.036 (c.) The final operation to plug and abandon the well is scheduled to be performed in the Fall of 2012. With approval to complete the P &A from the AOGCC, it is desired that the sundry be approved until December 31, 2013. ©' In December 1980, the well was suspended with the following cement and plugs in the welibore: 10,426' Set 7" retainer @ 10,610' MD, squeezed 10 bbls Class G, tagged @ 10,426' MD and PT'd to 3000 psi. 9048' Set 9 -5/8" retainer @ 9191' MD w/ 10 bbls Class G on top. 2360' Balanced 10 bbl Permafrost C plug from 2500' MD to 2360' MD " The procedure below outlines the steps to perform the final operations to abandon the well and cut off all casings and conductor 3' below tundra level. • • Procedure to Abandon Chev 18- 11 -12: 1. Service and pressure test wellhead. 2. PT wellbore (9 -5/8" casing) to 2500 psi. 3. RU SL and tag TOC (expected 2360' MD) 4. RU EL and punch 9 -5/8" casing at TOC in OA (est. 1800' — 1500' MD). S` 5. Circulate diesel out of 9 -5/8" casing and arctic pack out of OA. Circulate in Arcticset 1 or permafrost blend of 15.8 -ppg Class G cement plug from 1500' MD to surface in both 9 -5/8" casing and OA ( -200 bbls total). 6. Notify AOGCC Inspector to witness Tag and PT (9 -5/8" casing and OA) of cement plug to 2500 psi. 7. Excavate around the well and prep to remove casing and wellhead. 8. Cut off and remove the casing and wellhead a minimum of 3' below tundra. a. Notify Inspector of opportunity to witness cut off prior to welding plate. 9. Top off any unfilled annuli and tubing to surface with cement. 1� h o to cl v C u "Gk � f / - t 10. Place an abandonment plate on top of the cut off casing with the following information: BP Exploration Alaska, Inc. CIicd 181112 RN lel/ i z PTD #180 -108 API# 50- 029 -20511 11. Backfill over Well. h v to " cJoC ✓ v>nrv� "� P � /de-d- �"�►� �1/c O N V k P p /atom, • 0 Chevron 18 -11 -12 Permit No. 80 -108 API No. 50- 029 -20511 Current Status Surface Fr 20" Conductor @ 110' MD 'F Cemented w/ 33 bbls Diesel to 200' MD r , OA downsqueezed with 50 bbls Permafrost C & displaced with " " •/ Cement plug @ 2360' MD - Arctic Pack J 2500' MD, 10 bbls Permafrost C TOC if leading edge of cmt was pumped only to the shoe is 1800' 'V ,..,4:, / " L.O.T. @ 13 -3/8" shoe: MD. (Cmt height is —860' MD) / 0.72 psi /ft = 2000 psi 13 3/8 ", 72 #, L -80 @ 2684' MD " fijii,%, � Cemented w/ 660 bbls / DPZs: � Permafrost II SV (gas) 2780' - 2922' MD Ugnu (gas) 4236' - 4252' MD 9 -5/8" annulus TOC —6300' MD • Ivishak (oil) 9806' — 10,901' MD w/ 30% washout TOC plug —9048' MD /A A EZ Drill Retainer @ 9191' MD w/ 10 bbls — Class G cement on top Top of 7" @ 9243' MD 9 5/8 ", 47 #, L -80 @ 9750' MD Cemented w/ 250 bbls Class G TOC @ —6300' w/ 30% washout. i • Diese l OC tagged @ 10,426' MD, PT'd to � 3000 psi 12/21 /1980 %% Cement E Z -Drill Retainer @ 10,610' MD Arctic Pack � �r squeezed w/ 10 bbls class G _,E Perfs 10,600' — 10,620' MD r 10 ppg NaCl/NaBr Brine , 7 ", 29 #, L -80 @ 10,906' MD Cemented w/ 63 bbls Class G (est TOC w /30% w/o @ —8950' w/ 30% washout — no cmt seen above liner lap • 1 Chevron 18 -11 -12 Permit No. 80 -108 API No. 50- 029 -20511 Proposed Status Surface , 20" Conductor @ 110' MD ' 9-5/8" and OA Cemented w/ 33 bbls A displaced with Cement from —1500' MD to surface A TOC if leading edge of cmt was pumped only to the shoe is 1800' 1 0 ppg NaCI /NaBr Brine MD. (Cmt height is —860' MD) v ' * L.O.T. @ 13 -3/8" shoe: 0.72 psi /ft = —2000 psi 13 3/8", 72#, Cemented w/ MD 660 bbls / DPZs: Permafrost II SV (gas) 2780' - 2922' MD ' Ugnu (gas) 4236' - 4252' MD 9 -5/8" annulus TOC —6300' MD U Ivishak (oil) 9806' — 10,901' MD w/ 30% washout A ' EZ Drill Retainer @ 9191' MD w/ 10 bbls � Class G cement on top Topof7 " @9243'MD 9 5/8 ", 47 #, L -80 @ 9750' MD Cemented w/ 250 bbls Class G TOC @ —6300' w/ 30% washout. TOC tagged @ 10,426' MD, PT'd to Cement 3000 psi 12/21/1980 EZ -Drill Retainer @ 10,610' MD Arctic Pack squeezed w/ 10 bbls class G ■% Perfs 10,600' — 10,620' MD 10 ppg NaCI /NaBr Brine 7 ", 29 #, L -80 @ 10,906' MD Cemented w/ 63 bbls Class G (est TOC w /30% w/o @ —8950' w/ 30% washout — no cmt seen above liner lap • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/11/10 Inspector: Chuck Scheve Operator: BPX Well Name: PBU TR 18 -11 -12 Oper. Rep: Jack Winslow PTD No.: 1801080 Oper. Phone: 659 -5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 12/24/80 Date AOGCC Notified: Sundry No.: Well Completion Rpt Type of Inspection: Initial Wellbore Diagram Avail.? No Well Pressures (psi): Tubing 60 Photos Taken? Yes IA 50 - by Operator OA 0 Condition of Wellhead: No Well house, guard rail is in place. Single master valve only. Condition of Surrounding Surface OK Location: Follow Up Actions none - Needed: Attachments: None REVIEWED BY: C-2 Insp. Supry -igt k Comm PLB 08/2010 2010 - 0911 _Suspend_PBU_TR_18- 11- 12_cs.xls • SIM ARASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Gary Preble Date Management Engineer BP Exploration (Alaska), Inc. ' P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, CHEV 181112 Sundry Number: 310 -439 Dear Mr. Preble: SLANINED IAN 2.011 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • Daniel T. Seamount, Jr. �" Chair DATED this day of January, 2011. Encl. • • • A II RECEIVE • • STATE OF ALASKA • DEC 2 1 2010 ik ALASKA OIL AND GAS CONSERVATION COMMISSION `, APPLICATION FOR SUNDRY APPROVALS oil & b as Cans. Commission 20 AAC 25.280 AnthnraQe 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate0 Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: RENEW SUSPENSION - 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development 0 - Exploratory ❑ 180 -1080 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20511- 00-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ CHEV181112 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028262 - PRUDHOE BAY Field / PRUDHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10906 - 9303 10735 9182 9191' 2500' TOC NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE 110 - SURFACE 110 Surface 2684 13 -3/8" SURFACE 2684 SURFACE 2684 Intermediate 9750 9 -5/8" SURFACE 9750 SURFACE 8428 Production Liner 1663 7" 9243 10906 8030 9308 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10600 - 10620 9084 - 9099 NONE Packers and SSSV Tvoe: NONE Packers and SSSV MD and TVD (ft): 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/4/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended - El 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name e G Prebl Title Data Management Engineer Signature Phone Date ,' .4.----- 564 -4944 COMMISSION USE ONLY 12/21/2010 Prepared by Gary Preble 564 -4944 ('� — 'j (� Conditions of approval: Notify Commission so that a representative may witness Sundry Number: . 3 ) v " / q Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ ,/ 1 Other: _ 4oe.e c 4( /4ce.xo a ra .�c.Q Ate, Z it '4'4 z S. �� h ... I 4-4.,; G h. U �"� ÷I ( /2 3 / � 43 . / ' r Subsequent Form Required: Na..t Al - "] ' APPROVED BY Approved by: + COMMISSIONER THE COMMISSION Date: ) (s /` f 74.,/3 ./7 0 R 1 G Mt JAN U;6 Z01: f2 Form 10-403 Revised 1/2010 Submit in Duplicate • • Prudhoe Bay Unit well TR 18 -11 -12 Technical Justification for Application for Renewal of Suspension Status December 17, 2010 Well Status PBU TR 18 -11 -12 (PTD 1801080) was suspended on 12/24/80 after coring, drilling to TD, logging, cementing casing and testing. The well is located within the Prudhoe Bay Unit on a maintained gravel pad accessible from the PBU road system, about 1 mile north of PBU Z pad. BP Exploration (Alaska), Inc. (BPXA) completed a suspended well inspection of PBU TR 18- 11-12 on 09/11/10. The results of that inspection were submitted with a Report of Sundry Well Operations (form 10 -404) on 09/17/10. PBU TR 18 -11 -12 is secured with cemented casing, a retainer with cement above in the liner above the perforations and two cement plugs in the intermediate casing. The well is mechanically sound based on cemented casing and the plugs and pressure tests after the plugs were set. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe, and not a threat to public health. The strata through which the well was drilled is neither abnormally geo- pressured or depleted. The well is planned to be plugged and abandoned in 2013. There are no production facilities near this well and the Ivishak in this area has been developed from Z pad. Condition of the Wellhead and Surface Location PBU TR 18 -11 -12 is located on an inactive pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. The current well pressure readings are T /I /O = 60/50/0. Request BPXA requests approval for renewal of the existing suspension status for PBU TR 18 -11 -12 through 12/31/2013 to allow time for the planed P &A to be completed. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to be remain suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. MLB 12/17/10 • • TIC WELLHEAD = PBU TR 23- 18 -11 -12 5 : KB. MB/ = BF. = KOP= Max Angle = Q 207 DESe- Datum MD = Datum TVD = 8800' SS 2360' ' -2500' Cae4r PLUG 113-3/8" CSG, 721, L-80. D =12.347" H 264' 1-- III r ®�v e ? TOP OF CEMENT v o ♦ e ■ 4 0 0 ® 0 0 0.440 8 808 8 0+4 8 0 0 e a.4", *.e > 4.,e e e f 0, - 9191' MIDGE PLUG +9 -5/8" CSG, 471, L -80, D = 8.881" H 9750' PERFORATION SUMMARY REF LOG: ? ?? 10426 TOP OF °MINT ANGLE AT TOP PERF: ►08 I 0 0 0 4 0 . • 0 4 Note: Refer to F roduclion DB for historical pert data +++044.8 SIZE SPF INTERVAL ► 8 8 8 8 8 8 8 A OPIVS9Z DA ',MILAN 10 HRETANE R;I 7 4 10600 -10620 S 7 III PETD 10735' �` sylitivicr ►8 8888 88 88 88 88 088 17" LNt, 296, L -80, .0371: ?bpr, D = 8.184" H 10906 ► . 8A . 0 .` 8 , 0 . O .OA DATE REV BY CC tfS DATE REV 6Y COMMENTS CI£/RON TRACT WELL 12124/10 0010111.1. COMPLETION WELL: PBU TR 23-18 -11-12 PERMIT No: / 50108 API No: 50- 029 -20511 SEC 07, T11 N, R12E 808' NSL & 3893' WEL BP Exploration (Alaska) BP EXPLORATION February 21, 1996 .~/'~ / /¢ ¢ ~ Exploration (Alaska)Inc. j..~) /J~Qa'~" f' ~ 9~Ea, Benson~ulevard R ~ ~ ~ Anchorage, Alas~ 9951~6612 (9~) 561-5111 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Dave' Designation Of Operator Suspended Wells in the PBU West End COMM _'~~ COMM ......_. NRO GEOL STAT I am following up my letter of September 30, 1994 in which I indicated that BPX would contact the owners of seven suspended wells in the PBU West End which BPX operated under provisions of the Prudhoe Bay Unit Operating Agreement. The wells have been suspended for between 14 and 16 years and are listed on the attachement. Chevron USA Inc., has assumed operatorship of the Chevron #23-18-11-12 well. Executed Designation of Operator forms evidencing the change in operatorship are transmitted herewith for your further action. Please feel free to contact me if you have any questions regarding this matter. Sincerely, Stu Hirsh, CPL Senior Landman p,E. GE. IVED FEB 2 5 1 96 Suspended BP Operated MPC / Chevron Wells Well Name . APl Number ,Susp. Date Term Well C 029-20356-00 04/25/79 MPC Tract Well 3-10-12 029-20483-00 10/11/80 MPC Tract Well 11-33-11-12 029-20504-00 04/29/81 Chevron Tract Well 23-18-11-12 029-20511-00 12/24/80 MPC Tract Well 31-11-13 029-20536-00 02/20/81 MPC Tract Well 32-30-11-13 029-20546-00 01/18/81 MPC Tract Well 22-31-11-13 029-20545-00 02/14/81 ,, ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name of Owner Chevron U. S. A. Inc. 2. Address P. O. Box 1635 Houston, Texas 77251-1635 Attn: Manager - Non-Op. Joint Ventures 3. Notice is hereby given of the designation Of operato~ship of the oil and gas properties describe~l below: Well Name and APl Number: Chevron Tract Well #23-18-11 - 12 029-20511-00 Property Plat Attached I-! 4. Name of Designated Operator Chevron U. S. A. inc. Address 5. Effective Date of Designation P. O. Box 1635 Houston, Texas 77251-1635 Attn: Manager- Non-Op. Joint Ventures December 1, 1995 6. Acceptance of operatorship for the above property with all attendant responsibilities and obligations is hereby acknowledged. Si~ned~. ~'~AI~~-'~ Title ~e~~~ Date 2.~,~{9~ 7.The ov~r hereby certifies that the foregoing is true and correct Signed Title e~ A~ u, ~ Date Z./(.%./r/.,, " Submit in Duplicate BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 16, 1995 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 / Designation Of Operator Suspended Wells in '~h¢ PBU We$'~ End Dear Russ: I am following up my letter of September 30, 1994 in which I indicated that BPX would contact the owners of seven suspended wells in the PBU West End which BPX operated under provisions of the Prudhoe Bay Unit Operating Agreement. The wells have been suspended for between 14 and 16 years and are listed on the attachement. Mobil Oil Corporation, operator of the Mobil Phillips Chevron Joint Venture, have decided to assume the rights and obligations of operator of six of the wells. Executed Designation of Operator forms evidencing the change in operatorship are transmitted herewith for your further action. We only recently learned that the 18-11-12 well was drilled sole account for Chevron. Consequently, we are in the process of contacting them relative to their plans for the well and will advise you according when we find out. Please feel free to contact me if you have any questions regarding this matter. Sincerely, Stu Hirsh, CPL Senior Landman OCT 't 9 1995 Alask~ 0il ,& Gas Cons. Cosnlission /~ch0rage Suspended BP Operated MPC / Chevron Wells Well Name APl Number Susp. Date Term Well C ' 029-20356-00 04/25/79 MPC Tract Well 3-10-12 029-20483-00 10/11/80 MPC Tract Well 11-33-11-12 029-20504-00 04/29/81 Chevron Tract Well 18-11-12 029-20511-00 12/24/80 I~PC Tract Well 31-11-13 029-20536-00 02~20/81 MPC Tract Well 32-30-11-13 029-20546-00 01/18/81 MPC Tract Well 22-31-11-13 029-20545-00 02/14/81 .... OCT 1 9 199.5 Naska Oit & Gas Cons. Commission ;Anchorage 1. Name of Owner ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 2o AAC 25.020 Mobil Oil Corporation 2. Address P. O. Box 650232 Dallas, Texas 75265-0232 3. Notice is hereby given of the designation of operatorship of the oil and gas properties described below: Well Name and APl Number: Well Name and AP! Number: Well Name and APl Number:. Well Name and APl Number:. Well Name and APl Number:. Well Name and APl Number:. 4. Name of Designated Operator MP Tract Well 3-10-12 MP Tract Well 11-33-11-12 :v:.'- ,. :.~,~: ',A,".-.~', 1 ~.',, I. 19 MP Tract Well 31-11-13 MP Tract Well 32-30-11-13 MP Tract Well 22-31-11-13 Term Well C 029-20483-00 029-20504-00 029-2051 i -00 029-20536-00 029-20546-00 029-20545-00 029-20356-00 Property Plat Attached I'-i Address Mobil Oil Oorporation P. O. Box 650232 Dallas, Texas 75265-0232 l.. .,,J.~ I V 0CT 1 9 1995 5. Effective Date of Designation August 1, 1995 "-, ~chorage 6. Acceptance of operatorship for the above property with all attendant responsibilities and obligations is 7.The owner hereby certifi~ hereby acknowledged. that the foregoing is tree and coffect Date ~); lq r Submit ih Duplicate MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Blair Wondzell, ~~ P. I. Supervisor '~/~ FROM: John Spaulding,Q~. SUBJECT: Petroleum Insp. ~,~ 3~ DATE: FILE NO: October 2, 1994 2991jbbd.doc Suspended Wells Inspection North Slope, Alaska October 1,2&3, _1.994: I accompanied Marian Sloan BPX representative on an inspection tour of BPX suspended wells at various North Slope locations. Travel was by pickup and helicopter. Marian Sloan Informed me that BPX is drafting a program with reasons for leaving wells listed below as suspended, this program will be available to the AOGCC in the very near future Oct. 1,1994 Y-22A / PBU / PTD 88-115; well head on configuration, no pressure on tubing or annulus, area very clean, well is located on a producing drillsite. S-10A / PBU / PTD 91-123; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. U-01 / PBU / PTD92-11; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. Z-32A / PBU / PTD 93-113; wellhead on configuration, no pressure on tubing, 750 psi on inner annulus, 0 pressure on outer annulus, area clean, well is located on producing drillsite. Chevron 18-11-12 / PTD 80-108; wellhead on configuration, no pressure on tubing or annulus, area clean. MP 22-31-11-13 / PTD 81-10; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. MP 32-30-11-13 / PTD 80-152; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. Oct. 2, 1994: A-01 / MPU / PTD 79-40; wellhead is removed with casing hanger still on, area clean, well is located on a active drillsite. A-03 / MPU / PTD 83-01; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a active drillsite. B-02 / MPU / PTD 81-142; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite, C-16 / MPU / PTD 85-116; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. N-01B / MPU / PTD 84-13; wellhead on configuration, no pressure on tubing or annulus, area clean with timbers covering the cellar area and well guard around the wellhead. No Point #1 / MPU / PTD 94-27; wellhead on configuration, area clean, unable to land helicopter to check wellhead for pressures, No Point #1 is scheduled to become part of the F- pad construction at MPU. , NW Milne #1 / MPU / PTD 91-145; wellhead on configuration, area clean, island is suffering from severe erosion on the North side. Oct, ,3, 1994: Sa,q Delta 31-11-16 / PTD 69-14; wellhead on configuration, area clean, has wooden location marker, no pressure on tubing or annulus. Sa,q Delta #3 / PTD 76-80; wellhead on configuration, area clean no pressure on tubing or annulus. Sa.q Delta #4 / PTD 7.7..-15; wellhead on configuration, area clean, no pressures on tubing or annulus. .S..a.q Delta #2A / PTD 77-69;. wellhead on configuration, no pressures on tubing or annulus, timbers and cellar box material, reserve pit open. Sag Delta #5 / PTD 80-129; no wellhead; bell shaped affair was covering the supposed well surface location, area clean. Sa,q Delta #8 / PTD 80-121; wellhead on configuration, timbers and well guard, island is eroding. o Alaska Island #1 / PTD 81-119;. unable to land, area appeared clean from the air, marker post visible on South side of island. Niakuk #4 / PTD 84-200; wellhead on configuration, concrete river weights, cellars open, island eroding. · Niakuk #5 / PTD 85-27; wellhead on configuration, concrete river weights, cellars open, island eroding. Location Clearances; Niakuk #lA / PTD 76-28; area is clean, no visible marker post, island is eroding as planned. (:;Niakuk #2A / PTD 76-79;...area-is-clean;-.no-visible-marker--post; .island-is-eroding as planned. I recommend that the AOGCC consider Niakuk lA & 2A for final abandonment and location clearance. Summary,: I inspected locations of 28 BPX suspended wells. I also inspected 2 wells for final abandonment and location clearances. CONSERVATION COMMISSION ,WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 15, 1994 Steve Horton, Drlg Mgr BP Exploration (Alaska) Inc P O Box 196612 (MB12-1) Anchorage, AK 99519-6612 Re: Suspended Wells Compliance with regulations Dear Mr. Horton: BP Exploration and the predecessor Sohio companies have several suspended wells as shown on the attached lists: BP SUSPENDED WELLS PRIOR TO 1980 and BP SUSPENDED WELLS SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above, or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as r~uire~by 20 AAC 25.110(e), must have well site inspe_c_tion~s ~is ye~o snow covering the locations. David W. ( Johns ton Chairman "-..~ Attachments c: Blair Wondzell bew/llbpsusp /15/94 BP SUSPENDED WELLS SINCE 1980 PAGE 1 AUGUST 1994 PERMIT 79-0040-0 80-0066-0 80-0092-0 80-0108-0 80-0121-0 80-0129-0 80-0139-0 80-0152-0 81-0010-0 81-0119-0 81-0142-0 83-0001-0 84-0013-0 84-0200-0 85-0027-0 85-0110-0 88-0115-0 90-0140-0 91-0123-0 91-0145-0 92-0011-0 93-0113-0 94-0027-0 API NUMBER 029-20376-00 029-20483-00 029-20504-00 029-20511-00 029-20519-00 029-20527-00 029-20536-00 029-20546-00 029-20545-00 089-20018-00 029-20662-00 029-20891-00 029-21053-02 029-21217-00 029-21290-00 029-21364-00 029-21558-01 029-22096-00 029-20765-01 029-22231-00 029-22244-00 029-21924-01 029-22450-00 WELL WELL WELL NAME CLASS STATUS MILNE POINT UNIT A-01 EXP SUSP PRUDHOE BAY U~IT 3-10-12 DEV SUSP PBU MP 11-33-11-12 I DEV SUSP PRUDHOE BAY UI~IT TR 18-11-12 DEV SUSP SAG DELTA 8 EXP SUSP SAG DELTA 5 EXP SUSP PRUDHOE BAY UNIT 31-11-13 DEV SUSP PBU MP 32-30-11-13 i DEV SUSP PBU MP 22-31-11-13 2 DEV SUSP ALASKA ISLAi~D I EXP SUSP MiLNE POINT LTNIT B-02 DEV SUSP MILNE POINT UNIT A-03 DEV SUSP MILNE POINT UNIT N-01B DEV SUSP NIAKUK 4 EXP SUSP NIAKUK 5 EXP SUSP MILNE POINT U~IT C-16 DEV SUSP PRUDHOE BAY UNIT Y-22A DEV SUSP PT MCINTYRE P2-59 EXP SUSP PRUDHOE BaY UNIT S-10a DEV SUSP NORT~-EST MILNE 1 EXP SUSP PRUDHOE BaY UNIT U-01 DEY SUSP PRUDHOE BaY UNIT Z-32A DEV SUSP NO POINT I DEV SUSP STATUS DATE 4/15/80 10/11/80 4/29/81 12/24/80 A/15/81 4/13/81 2/20/81 1/18/81 2/14/81 6/08/82 5/27/82 12/10/83 4/27/84 2/17/85 4/18/85 10/27/93 10/29/88 12/22/90 11/06/91 3/30/92 3/16/92 8/31/93 4/08/94 SECT 23 33 33 07 27 36 05 30 30 11 19 23 30 25 25 10 33 14 35 25 18 19 06 TWP 13N 11N 11N 11N 12N 12N 10N 11N 11N 10N 13N 13N 13N 12N 12N 13N 11N 12N 12N 14N 11N 11N 010E 012E 012E 012E 016E 015E 013E 013E 013E 022E 011E 010E 010E 015E 015E 010m 013E 014E 012E 009E 013E 012E 010E MER U U U U U U U U U U U U U U U U U U U U U U U '15/94 PERMIT 69-0014-0 69-0104-0 70-0060-0 71-0015-0 75-0058-0 76-0028-0 76-0079-0 76-0080-0 77-0015-0 77-0069-0 78-0102-0 API NUMBER 029-20011-00 029-20047-00 223-20006-00 029-20099-00 029-20176-00 029-20156-01 029-20180-01 029-20233-00 029-20245-00 029-20234-01 029-20356-00 BP SUSPENDED WELLS PRIOR TO 1980 AUGUST 1994 WELL WELL WELL NAME CLASS STATUS SAG DELTA 31-11-16 EXP SUSP PRUDHOE BAY UNIT 33-12-13 DEV SUSP KEMIK UNIT I DEV SUSP PRUDHOE BAY UNIT H-01 DEV SUSP SAG DELTA 33-12-16 EXP SUSP NIAKUK 1-A EXP SUSP NIAKUK 2-A EXP SUSP SAG DELTA 3 EXP SUSP SAG DELTA 34633 4 EXP SUSP SAG DELTA 28337 2-A EXP SUSP PRUDHOE BAY UNIT TER~ C DEV SUSP STATUS DATE 4/28/69 12/20/69 6/17/72 6/22/71 4/28/76 4/30/76 3/30/77 3/23/77 3/22/78 12/27/77 4/25/79 SECT 31 33 17 21 04 26 26 35 10 03 TWP 11N 12N 01N 11N 11N 12N i2N 12N 11N 11N RNG 016E 013E 020E 013E 016E 015E 015E 016E 016E 016E 012E PAGE MER U U U U U U U U U U Standard Alaska Production Compa~ 900 East Benson Bok ~, P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 564-,:876 October 28, 1987 G.J. Abraham V,ce President P.B.U. Programs .. ..,./_-, '? · ' ';,"" .: ~ - :.... .. - :,. :.. . . · ,.. . . .;...:.---'-'~ STANDARD' ALASKA PRODUCTIO. : . , . Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 UPHOLE LOGGING REQUIREMENTS - PRUDHOE BAY UNIT WEST END Dear Commissioner Chatterton: Development drilling in the Prudhoe Bay Unit Eileen West End by Standard Alaska Production Company is scheduled to begin in January 1988. Standard Alaska Production Company requests that uphole log data in the following wells be used to satisfy regulation AAC 25.071 paragraph (a) regarding uphole logging requirements: W Pad 21 -llN 12E Standard Alaska Production Company West End Test Well 21-11N-12E A.P.I. 950-029-21033-00 .Standard Alaska Production Company M/P Tract Well 09-11N-12E A.P.I. 950-029-20524-00 Mobil Oil Corporation Kuparuk State ~1 21-11N-12E A.P.I. #50-029-20008-00 The bottom hole location of each of these wells is in the Section 21,. the section in which the pad is located. Z Pad 19 - liN 12E A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Atlantic Richfield Company Highland State #1 24-11N-liE A.P.I. ~50-029-20199-00 Chevron Company U.S.A. Chevron Tract Well t8-11N-12E A.P.I. #50-029-20511-00 RECEIVED OCT iklBsk~ 0%t & G~s Cons, Commissio,~ Attachment I shows both surface and bottom hole location of the above wells. The close proximity of the bottom hole location of each of the wells to the pad location indicates that uphole log data in these wells is representative of the uphole section that .would be logged from any well drilled from W or Z Pad. Attachment II is a listing of the current uphole log data available for each well. The data that is available on all of the above wells is more than adequate to document stratigraphy and fluid distribution. With your concurrence, no further uphole data will be acquired from either W or Z pad unless required by other working interest owners. If you have any questions regarding this request please contact Karen Jay at 564-5360. Si rely, DEK/KLJ/gab:2238G RECEIVED OCT 3 0 BB7 N~Sim Oil & r=;[s Cons. Commission Anchorage CURRENT WELL LOCATIONS EILEEN WEST END 12 7 8 tO ~! ..., · KUPAR~ -. -~:~ ,,, ,, ,, ,,,, m)) m ~4 ~ lq 2~ 1 I ~ I,~ I I Il K~ ~t.I mi i: ' ................... ~ ru~ ~,~ [m ......... , ~iJl~X - SURFACE LOCATIO~ .'.) WEST END LOG DATA Current Available Data. - W Pad Section 21-11N-12E Mobil Kuparuk State %1 21-11N-12E A.P.I. % 50-029-20008-00 SAPC West End Test Well 21-11N-12E A.P.I. ~50-029-21033-00 SAPC M/P Tract Well 16-11N-12E A.P.I. # 50-029-20524-00 DIL/BHC-GR 314' - 11108' MD FDC/CNL-GR 2600' - 11109' MD D IL/BHC-GR FDC-GR 117' - 9960' MD 2600' - 9960' MD D IL/BHC-GR 115' - 8734' MD - Z Pad Section 19-11N-12E ARCo Highland State 24-11N-liE A.P.I. ~ 50-029-20199-00 Chevron Chevron Tract Well 18-11N-12E A.P.I. # 50-029-20511-00 DIL/BHC-GR 106' - 2727' MD FDC/CNL-GR 2716' - 9436' MD DIL/BHC-GR 2681' - 10894' MD FDC/CNL-GR 2681' - 10894' MD RECEIVED OCT o ]987 Naska Oil & Gas Cons. Commissio;~ Anchor,~ge STATE Of ALASKA ADL 28262 ALASKA Oil AND GAS CONSERVATION COMMIS~r~N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ___Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 3. Address P. O. Box 196612, Anchorage, Alask~ 99519-6612 4. Location of well at surface 809' NSL, 3893' WEL, Sec. 07, TllN, R12E, UM At top of productive interval At effective depth At total depth 3695' SNL, 3566' WEL, Sec. 18, TllN, R12E, UM 5. Datum elevation (DF or KB) feet 6. Unit or Property name Prudhoe Bay TTn{t 7. Well number (23-18-11-12) Chevron Tract Well 8. Permitnumber 80-108 9. APInumber 50-- 029-20511 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 10906 9303 Effective depth: measured 10735 true vertical 9182 Casing Length Size Structural Conductor 20" Surface 13-3/8" Intermediate 9-5/8" Production 7,, Liner Perforation depth: measured 10600'-10620' (4Spf) true vertical Tubing (size, grade and measured depth) feet 7" Plugs(measured) feet Retainer at 10610' squeezed perfs with 60 cu. ft. Class G cement. Top of cement 10426' feet 9193dn~(~br~idge Plug 58 cu.ft. Class G feet Cement 2500'-2360' Cement Plug 56 cu.ft. Permafrost C Cemented Measured depth ~ue Verticaldepth 7 cu. yds. Concrete ll0'MD 3720 cu.ft. Permafrost II 2684'MD 1390 cu.ft. Class G; 9750'MD 280 cu.ft. Permafrost C 354 cu.ft. Class G 9243'-10906'MD Reason for extension: This suspended well is being considered for future use as a West End development gas cap observation well. None Packers and SSSV (type and measured depth) 12.Attachments Description summary of pro~p~sal [] Detailed operabons prog a~,~,¢.~.BQP~.,, ,,,,:.,,, sketch [] Request extension under 20 AAC 25.~?_"__'.k.', ",~ ~ ' 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed E, C..~, ~&~.,,...._ Title Division Drilling Engineer Commission Use Only Date ~} 15)~-'/ Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI "7" ,.,¢"/.~ Approved by Form 10-403 Rev 12-1-85 Commissioner by order of '¢"'/¢~ ¢' ./,~.~//? the commission Date Subdnit in triplicate STATE OF ALASKA ALASKA:' OIL AND GAS CONSERVATION COM~r:SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [?, Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension .~ Change approved program ~ Plugging [] Stimulate ~ Pull tubing F_] Amend order [] Perforate [] Other FI 2. Name of Operator .qtandard Alaska Product, on Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 809' NSL, 3893' NEL, Sec. 07, TI]N, R]2E, UH At top of productive interval At effective depth At~t~¢e§~L, 3566' NEL, Sec. 18, TllN, R12E, UM 5. Datum elevation (DF or KB) KBE = 73' ANSL feet 6. Unit or Property name Prudhoe Bay Unit 7..Well number (23-1 Chevron Tract Nell 8. Permit number 80-108 50-- 10. ,~ool ,. ~'ru0noe Bay Oi 1 Pool 11. Present well condition summary ]0906 Total depth: measured true vertical 9303 Effective depth: measured 10735 true vertical 9l 82 Casing Length Size Structural Conductor 20" Surface 13-3/8" Intermediate 9-5/8" Production 7" Liner . Perforation depth: measured 10600'-10620' (4Spf) true vertical feet 7" Elu,as,(measured). feet Ke['alner a~: '10610' squeezed perfs with 60 cu. ft. Class G cement. Top of cement 10426' feet 9191' 9-5/8" Br, dge Plug 58 cu.ft. Class G feet Cement 2500'-2360' Cement Plug 56 cu.ft. Permafrost C Cemented Measured depth True Vertical depth 7 cu. yds. Concrete 110'MD 3720 cu. ft. Permafrost II 2684 'MD 1390 cu.ft. Class G; 9750'MD 280 cu. ft. Permafrost C 354 cu.ft. Class G 9243'-10906'MD Reason for extension' This suspended well is being considered for future use as a Nest End development gas cap observation ~e~l,, E)V E Tubing (size, grade and measured depth) OCT 2 2 1986 None Packers and SSSV (type and measured depth) Alaska 0ii & G~s Cons. uu;nraJssicr Nnnc. .~__nahnrana 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch ~ Request extens,on under 20 AAC 25.]70(b) ],2,3,4 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'q_ (~, ~. ~ Title D'V' s,On Dr,]],ng Eng, neer Date Commission Use Only approval Notify commission so representative may witness ! Approval Conditions of No. [] Plug integrity [] BOP Test [] Location clearanceI /'/ / 'r~9,eturn~.d ~/ Ft~mPr Commissioner the commission Date Sub(mit in'triplicate July 31, 1986 Telecopy No. (907) 276-7542 Mr. R. S. Allan Standard Alaska Production Company P. O. Box 6612 Anchorage, AK 99502-0612 Re: Extension of Suspended Status. PBU MP 11-33-11-12 No. 1 PBUMP 22-31,11-13 No. 2 PBU MP 32-30-11-13 No. 1 PBU M~PC Tract 3-10-12 PBU M~P 43-31-11-13 Put River BP 33-12-13 PBUChevron Traet. 23-18-11w12 Sag Delta No. 3 Sag Delta No. 5 Sag Delta No. 7 Sag Delta No. 8 Sag Delta 34633 No. 4 West Sak 25519 No. 17 West Sak 25523 No. 16 West Sak 25655 No. 14 PBU U-13 West Sak 25548 No. 11 West Sak 25645 No. 9 Sag Delta 33-12-16 No. 1 Dear Mr. Allan: A review of our records shows that the above referenced wells are suspended. Section ll0(a)~of the regulations states the Commission will, in its discretion, approve the suspension of a well if the well is capable of producing hydrocarbons in paying quantities or is reasonably demonstrated to have future value as a service well. Section 105(e) states that "[e]ach well to be abandoned or suspended must be plugged...to prevent the movement of fluid either into or between freshwater and hydrocarbon sources and to _preve~nt all other fluid migration within the well bore." In compliance with Section 170(a) of the regulations, "It]he location of an abandoned well onshore or upon a historically stable island must be cleared within one year following well abandonment .... " Section 170(b) provides the means for~an extension of time if a valid reason exists, and the well bore is properly plugged. ~ Ar. R. S. Allan July 31, 1986 Page 2 We are,. therefore, requesting you to submit Form 10-403, Application for Sundry Approval, with a program which will bring the status of these wells into compliance with the new regulations and provide a schedule for this summer when our field inspectors can accompany your representatives to the well sites for location clearance inspection. Please call Harold J. Hedlund at (907) 279-1433 if you have any questions. ~.~~Sin~erelyl C~' Lonnie C. Smith Commissioner . jo/A.HJH. 06/07 SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 July 22, 1985 Mr, C.V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE': 1985 LO'CATION INSPECTION Dear Mr. Chatterton' In 'compliance with State' Regulation.20 AAC 25.170, attached are Fores 10-403, Sundry Notices and Reports on Wells, for the following wells. 'These notices request that the wells remain in suspended status. BP 41-33-12-1 3 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-1 3 MPC 11-33-11-1 2 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP (22-31-11-13) No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Del ta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Del ta #3 (35-12-16) Sag Delta 34633 #4 Sag Del ta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 Niakuk #4 Niakuk #5 J U~ 2 ~ k!:~ska 0',1 & Gas Cvns. Conm~ission Anchor~q~ Mr. C.V. Chatterton July 22, 1985 Page 2 Sag Delta #11 i-s now ready for final inspection .of the abandoned well. Please advise the undersigned which day during the week of August 19-23 is acceptable for your field inspector to accompany our representative for this annual location inspection trip, Very truly yours, RSA/,C, RM/sh 72285:0530N Attachments cc: Well File #17 R.S. Allan Acting SAPC Drilling Engineer '~'"' STATE OF ALASKA '""~ ALASKA OIL AND GAS CONSERVATION C~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Sohio A1 ~ka Petroleum Ccm%oany 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of Well At surface: 809' NSL, 3893' WEL, Sec. 07, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) ~RW. = 73' AMSL 6. Lease Designation and Serial No. ADL 28262 7. Permit No. 80-108 8. APl Number 50- 029-20511 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number Chevron Tract Well (23-18-1] 11. Field and Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Rec~_est extension under (Submit in Triplicate) 20 AAC 25.170(b) 1,2,3 Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future West End facility or storage Pad. -12) 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ ' ~ Distr~,t~~ ~iilin~ Engineer The space below for Commission use R. H. Reiley Conditions of Approval, if any: Approved Copy J~etu/ned / By Order of Approvedby ~ L0~I[ ~, ~'~!~ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY Mr. C. V. Chatterton Alaska Oil & Gas ConservationCc~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Re: 1984 LOC2tTION INSPECTION Dear Mr. Chatterton: 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 July 10, 19 84 - In compliance with state .Regulation 20 AAC 25.170, attached are Forms 10-403,' Sundry Notices and RepOrts on Wells, for the follc~ing wells. These notices' request that the Wells remain in suspended status o BP 41-33-12-13 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-13) No. 2 k~st Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5. (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Sohio Alaska Petrolet~a Ccmpany 80-108 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20511 4. Location of Well At surface: 809' Nb'L, 3893' ~,, ~. 07, TllN, R12E, ~ 5. Elevation in feet (indicate KB, DF, etc.) KBE= 73' AMSL 12. I 6. Lease Designation and ADL 28262 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number Chevz13n ~-a~ WeLt (23-18-1:] 11. Field and Pool ~'Lldhce Bay Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extension %~__~9r SUBSEQUENT REPORT OF' {Submit in Triplicate) 20 N~C 25,170 (b) 1,2,3 {Submit in Duplicate) Perforate I-] Alter Casing r"] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [::] Other ~[] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reasc~ for extension: This site is being oonsidered for future West End facility or storage pad. RECEIVED JUL 1 01984 Alaska Oil & Gas Cons. Commisslo. Anchorage 14. I har~if¥~fi:g ,$ truDd correct to the best of my knowledge. The space below for Commission use R. H. ~i1k Conditions of Approval, if any: Suspended status is extended until September, 1985. 8'f LQNIIIE ~. $111ll Approved bY "~' COMMISSIONER Approved Copy Returned 8y Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MI M( RANDUM State of Alaska · ALA~Fd% OIL AND GAS CO S ' COMMISSION TH ~ ~nnie C. S~th C~missioner ~ TELEPHONE ~oIe~ Ins~c~r~~ S~s~n~ed ~cations / Listed Below. ,,~_nda¥,_,Aug~t.8, ...I.983: I trammeled this date with Mike Dinger, SohiO's representative to look at the suspended locations listed below~ Chevro~ Tra=t PBU MP MPC Tract Well MPC Tract Well PBU MP #2 MP Tract Well 23-18-11-12 43-31-11-13 11-33-11-12 3-10-12 22-31-11-13 32-30-11-13 Attached to this report are pictures of well heads, drilling pads, reserve pits and a copy of the AO~CC surface suspension location report. It is my recc~mendation to the Commission that the above loca- tions be accepted in regards to location cleanup, well.sign placement, and pit conditions. Attachm~nts Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: ., Operator ~~ Date Suspended Address "_~~ i ~!~i ~_~~ ~ ~~Z .... ' ...... Surface Location of Well Permit No. Sec._D~, T ~; ~, R~ ~, ~ M. Unit or Lease Name Well Field & Pool ~A"~ Condition of Pad Condi' tion 'of Pits ~,~/~"~' Well head - Ail outlets plugged ....Well sign -Attached to well head.~ Attached to well guard .Attached to Information corre6t 'Yes ~ No Ye s No No Cellar- Opened ~~ No Rat Hole 0 n YeS No No No CoVered ~Y~"~ No ~b'5'~ ~"e d Yes No · WaterWell - Plugged off capped Open Explanation Photographs taken to verify above condi'tions Yes No Explanaton Work to be done to be acceptable This well and location is (acceptable) (.u~..ccce~-~ to be classified as suspended for the period of 9_ thru 19_ _. Inspected by:~w Date:.. ~'~ .... ~"~ Revised 8/24/82 SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 276.5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Mr. C. V. Chatt~n Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage., Alaska 99501 1983132X?JtTION INSPECTION ~"DearMr. Chatterton: July 21, 1983 In compliance with State Regulation 20 AAC 25.170, attached are Forms 10-403,~.,~Sundry Notices and Reports on Wells, for the following wells .... TheSe notice's request that the wells remain in suspen..ded status. ,~ BP 41L33-12-13 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) ~=vron Tract Well (23-18,11-I2). MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State ~1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-3~-11-13, No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 ~4 .~{~ag Delta ~5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 Mr. c. v. Chatterton July 21, 1983 . Page Two Water Injection Well GC - lB .(13-11-13) is also now ready for final inspection of the abandoned Well site. Please advise the undersigned which day during the week of August 8th is acceptable for your field inspector to accompany our representative for this annual location inspection trip to the above-named Well sites. Very truly yours, R. H. Reiley .District Drilling Engineer encs cc: Well Files #17 STATE Of ALASKA ALASKA ~JIL AND GAS CONSERVATION C~.,MMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Cc~pany 80-108 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20511 4. Location of Well OTHER At surface: 809' NSL, 3893' WRT,, Sec. 07, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) ~BE = 73' AMSL 6. Lease Designation and Serial No. ADL 28262 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number Chevron Tract Well (23-18-1] 11. Field and Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extension under SUBSEQUENT REPORT OF: (Submit in Triplicate) 20 AAC 25.170 (b) 1,2,3 (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other J~] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future West End development. ,12) RECEIVED J U L 2 1 !983 0il & Gas Cons. Commisslorl ,Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ _~1.~~~ ~ /~istr~lctlte Drilling Engineer Date The space below for Commission use R. H. Reiley Conditions of Approval, ifany:r~is Aocat:ion ~h~a.s inspected by ou~ representative on AuDJst 8, 1983 and clean up was £ound satis£actor7 Eor a suspended location. A subsequent ±t~specl:ion ~Ti_11 be necessary by August 1984. Approved Copy IGIN:AL SIGNED Returned Approved b¥, BY [,O""'E C. S"'TU ~-~ B¥Ordero' Comm .,o. Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMOF- NDUM S te of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: C. terton DATE: November 9, 1982 Cha~,~{Fz%''"'/' --"-"" ,,,,/. ~ ,. FILE NO: 10 8/A Thru: Lonnie C. Smith '~----/~" Commi s sione r TELEPHONE NO: FROM: Doug Amos Pe tr o le um Ins pe cto r SUBJEOT: Inspection of Sohio' s Suspended Locations Listed Below Friday., August 27, _1982 - I traveled this date to Prudhoe Bay where I met Jerry Segar, Sohio representative, and conducted the second clean-up inspection on the locations listed below. Attached to this report are pictures of well heads, reserve pits, drilling pads and a copy of the Form 10-403. I recommend to the Commission that the following locations be accepted in regard to location clean-up, well sign placement, and pit condition. PBU MP 22-31-11-13 No. 2 Term Well ~ (22-20-11-13) Term Well C (34-03-11-12) MPC Tract Well 21-03-10-12 MPC 11-33-11-12 Getty State No. 1 (2-10-13) PBU MP 43-31-11-13 West Sak 25645 #9 (3-11-9) West Sak 25548 #11 (36-12-8) West Sak 25655 #14 West Sak #16 (31-36-13-08) West Sak #17 (44-26-13-09) Kuparuk State 22-11-12 Sag Delta #.5 (36-12-15) Sag Delta #1 (33-12-16) No pictures, ran out of film Sag Delta #2A (10-11-16) " " " " " " Sag Delta #3 (35-12-16) " " Sag Delta .#4 (34633) " " Sag Delta #7 " " Sag Delta #8 " " Sag Delta #9 .. " " Sag Delta #10 " ". MP Tract Well 32-30-11-13" " Niakuk #iA (26-12-15) Niakuk #2A (23-12-15) Chevron Tract Well (23-18-11-12) II II II II II II II II II II II II II II II II II II II II II tl II II II II 11 II In summary, I inspected the above listed suspended locations for clean-up, well signs, and pit conditions. 02-00 ! A(Rev.]. 0/79) suspe?~ed Well and Location Rep¢~ 20 LAC 25, ARTICLE 2 FILE INFORMATION: Operator ~,~ ~~~ ~_~/~ ~, Date Suspended Addre s s Surface Location of Well· · ~ ' Permit No. .... S~ Ft.~_/j~_ ..L, ~_~_Ft. ~_/~__L API No. 50 Se~.~__, T.// ~__, R~_~L, b/~M' Unit or Lease Name_ Condition of Pad Well head - Ail outlets plugged Well sign -.Attached to Well 'he·ad Attached to well guard · Attached to Ye S No No Information correCt No Cellar - Opened Yes ~. Rat Hole Filled -.=:~m, No Covered Yes .- WaterWell - Plugged off Ope n' Exp la na ti on Open Fi 1 led Covered No No Photographs taken to verify above conditions~ No Explanaton Work to be done .to be acceptable This well and location is (ac_ ce~p~ah]a~-. (unacceptable) to be suspended for the period of classified as 19~. Revised 8/24/82 Z () i-'it 0/~ 3111 '°C" STREET ANCHORAGE, ALASKA TELEPHONE {907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 July 30, 1982 Mr. C. V. Chatterton Alaska Oil &,/~:Gas Conservation Commission 3001 Porcupine Drive ':;?';' .:~.:. Anchorage, AlaSka 99501 Dear Mr, Chatterton: In compliance with State Regulati°n 20 !s,~C 25.170, attached are Forms 10-403, Sundry Notices and Reports on Wells, for the following ~alls. These~inotices request that the wells remain in suspended status. BP 41-33-12-13 BP 22-33-11-13 Term Well B (22~20-11-13) Term Well C (34-03-11-12) [~~1t~i~:~2:3~18,1!-12). MPC Tract Well (21-03-10-12) PBU ~ 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-23, No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak ~,16 West Sak #17 Kuparuk State 22-11-12 Sag Del%a ~1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Del~ 34633 #4 Sag Delta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #t0 Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 ~ STATE OF ALASKA L AND GAS CONSERVATION CL. ,VllSSION ALASKA ~-, '" SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] 2, Name of Operator Sohio Alaska Petroleum Company Address Pouch .6-612, Anchorage, Alaska 99502 4, Location of Well At surface: 809' NSL, 3893' WEL, Sec. 7, TllN, R12E, UPM COMPLETED WELL [] OTHER 7. Permit No. 80-108 8. APl Number 50-- 029-20511 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number Chevron Tract Well (23-18-11 11. Field and Pool ~oe Bay 5, Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. KBE = 73' AMSL. ADL 28262 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' ~c~Jt~st e~tension t~d~r SUBSEQUENT REPORT OF' (Submit in Triplicate) 20 AAC 25,170 (b) 1,2,3 (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans ~ Repairs Made [] Other I'-] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future West End development. L-12) Clean-up to date: a) Major structures have been removed. b) Loose debris has been r~. RECEIVED AUG- 3 1982 Approved op¥ Returned Alaska 0il & Gas Cons. C0mmJssl0r~ Anchorago , . 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~C~~~_~~~.,~ Title District Drilling Engineer Date7. gL The space below for Commission use R. H'.~Re~.le~/' Conditions of Approval, if anv:Thls locatlon ~as inspected by our representative on August 27, 1982 and cleanup was found to be satisfactory for a suspended loctioan. A subsequent inspec- tion will be necessary by August 1983. By Order of Approved by. ~ C.SMITil COMMISSIONER the Comm,ssion Date .......... ~_~ Submit "Intentions" ~n Tr~ol~cate Fn,m 10-403 nnH "Subsec]uent Reports" ~n Duplma,'e -ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 TO: SFO/UNIT/ST: Date:3/3/82 # 1405 REFERENCE: . //~OHIO FINAL DATA /yThe following material is bein~'~ubmitted 'herewith. Please acknowledge receipt by signing a v copy of this letter and returning it to this office:-- SFO/UNIT/~STATE:. MUDLOGS (Open Hole) ~hev; ~iTrack.:.Well 23~I'8-ii~2~"~...~MU~tog ' 2"~ : . 10/26-12/11/80 (Analysts/Sch) 2700-10905' Y-3 . Mudlog 2" 6/30'7./29/80 (Analysts/Sch) 90-9915 ' (I can't be sure these mudlogs were issued previously, therefore I am sending these out to assure everyone has their logs with transmittals on record.) SFO/UNIT/STATE: B-6 D_5/ ,, ,, D_6j ,, ,, H-7v'. " " H_8-// ,, ,, Q_2w/ ,, ,, . ~ Q-4 / " " (-Marathon) Pressure Survey & BHPD II II r! PRESSURE SURVEYS (Otis) 2/19/82. (Sch) 2/13/82 (-Sch) 2/8/82 (Sch) 2/11/82 (Go) 2/9/82 (Sch) 2/10/82 (Sch) 2/16/82 (Sch) 2/17/82 OATE .. Alaska Oil &-Gi~s-C~s. Colt, mission Anchora.q~ .~~Ca~~riee_er ~e,~!_opment Geology ~,'~ ~I 1 Eeccrds 02 OO!B IRev 10/"/6~ STATE of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION TO: ~Hoyle H. Hamilton~F/' Chairman Thru: Lonnie C. Smith~ Commissioner FROM: Bobby Foster~; Petroleum InSpector DATE: FILE NO September 11, 1981 TELEPHONE NO: SUBJECT- Inspection of SOHIO's Suspended Locations Listed Below Monday August 31 Thru Wednesday_September 2: I traveled to Prudhoe Bay Monday August 31, 1981 where I met with Jack Barr, Judy Golding and Jerry Stegar, Sohio representatives and discussed the upcoming lOcation inspection. Attached to this report are pictures of well heads, reserve pit, drilling pad, and a copy of surface suspension report. It is my recommendation to the commission that the following locations be accepted in regard to location clean-up, well sign placement, and pit condition. Mobil Phil lips Mobil· Phil lips Mobil Phil lips chevron Tract WeSt Sak West Sak West Sak West Sak Mobil Phil lips MObil Phil lips Mobil Phil lips Term wel 1 Term wel 1 Getty State Niakuk Niakuk Niakuk Niakuk Sag Delta Sag Delta Sag Delta Sag Delta Sag Delta Sag Delta Sag Delta 21-03-11-12 11-33-11-12 22-11-12 23-18-11-12 #9 #11 #16 #17 22-31-11-13 43-31-11-13 32-30-11-13 B C #1 #1 #lA #2 #2A #1 #2 #2A #3 #4 #5 #8 .In summary, I inspected the above listed suspended locations for · clean-up, well signs, and pit Conditions. '~-'~' 20 AAC 25 ARTICLE 2 FILE I NFO}1HA'r ION: ~0 /~Z~ Date Downl~ole P & A Surface Location~ - / ~-- :~ - of Well Penni[ No. ~ -/~. 609 Ft. FW L, 20 AAC 25.120: WELL ~~ HARKF, R: Dia'. Steel Post (4"Min.) ~/~/~ , }{eight Above Final Grade LeVel (4' H.[n'"i)' Top of Marker Pipe Closed with: Cement Plug Screw Cap Set: On Well Head ~, On Cutoff Casing ~, In Concrete Plug Distance Below Final Grade Level Ft. in. Side Outlets: All Valves and Nipples Removed All Openings Closed '/', With Blinds ~ , With Cement INFORMATION BEAI)WELI)EI) I) I. RI~CTELY TO M..IRKER POST: (List t,~ere Different from File Infonnatioa) Operator ~ ~ Well Number Ft. F L~ ,, , Length (10' blin.) /~/_/~ , , [Init or Lease Name , Surface Location of Well: Ft., F L, Sec , T , R , Debris Removed Flat , Compacted , 20 AAC 25. 170: LOCA'rlON CLEAN-UP PITS: ~ Filled In~)~~ Liners Removed or Buried SURFACE OF PAD A~NU/OR LOCATION: Rough , Smooth ~, Contoured Other Welds CLEAN UP OF PAD AHD/OR LOCATION: Clean f..~, Pipe Scrap Paper , Other _ __, Iron ScralJt_, Wood __, blud __, Cement , SURROUNDIN$ AREA: Wooded , Brush Sand , Other , Tundra ~, Grass __, Dirt ___, Gravel , CONDITION SUR~ROUNDING AREA: Clean ~ Trash fr'otn Site Other , Tree~ aqd/or Brush fro,n Clearing Site ACCESS ROAD:./ · Dirt __, Gravel ~'/, Ice__, Qttmr' CONI)£TION AccEss ROAD AND SURROUNI)INC: , , Clean ~ Rougli ' SmOOth ~ ~ Trash from Trees and/or Brush from Clearing Rqad , Spoil from Clearing Road Other REMAINING TO BI'] DONE: RECOblHEND APPROVAL OF ': Yes INSPECTED BY ._ I 05/26/81 No Final Inspection MAll. ANCH(')F~A(.~F. AI. ASKA 99502 August 17, 1981 Mr. :-Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr% Smith: · In compliance with State Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices & Reports on Wells, for the follc~ing wells. These notices request that the wells remain in suspended Status. , Term Well B (22-20-11-13) Term Well C (34-03-11-12) ~hevron Tract Well (23-18.11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-~13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-13, No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2 (10~11-t6) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Niakuk #1 (26-12-15)-abandoned Niakuk #iA (26-12-15) Niakuk #2 - abandoned Niakuk #2A (23'12-15) Niakuk #3 (13-12-15) RECEIVED A!3sk~ Oil & Anc'ho~a,go Mr. Lonnie Smith August 17, 1981 Page Two We would like to have your field inspector present sometime during the week of August 31 - September 4 to accC~Pany our representative fOr final location inspection of the follc~ing wells: Challenge Island #1 Reindeer Island Stratigraphic Test #1 West Sak #4 Kemik Unit ~2 West Kuparuk State 3-11-11 Hurl State 5-10-13 Socal'Mobil 33-29E (29-12-11) Kuparuk State 33-11-12 Kuparuk 9-11-12 MPC 7-11-12 Kuparuk State 21-11-12 MP Tract Well 13-15-11-12 PPJ:JLG: ja Attachments cc: Well Files CC# 37,291 Yours very truly, Manager Drilling STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION C¢~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchoraqe, Alaska 4. Location of Well At surface: 7. Permit No. 80-108 8. APl Number 99502 50-029-20511 809' NSL, 3893' WEL, Sec. 7, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 73' AMSL I ADL 28262 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' Request extension under SUBSEQUENT REPORT OF: 9. Unit or Lease Name Prudhoe Bay Unit. 10. Well Number Chevron Tract Well (23-18-11- 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool (Submit in Triplicate) 20 AAC 25.170 (b) 1,2,3 Perforate [] Alter Casing r-I ~ Perforations Stimulate [] Abandon I-) Stimulation Repair Well I--I Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment I-I [] Other E~ 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, includ!ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future West End development. Clean-up to date: a) Major strUctures have been removed. b) Loose debris has been removed. RECEIVED AUG 2 6 1981 ~Jaska 011 & Gas Cons. C0mmissj0n Anchorage Approved C6py Returned Signed %1 ',~ '~ Tit.eDistrict Drillinq Enqineer Date R H '~.~y The space below for Commission use - Conditions of Approval, if any:~is ~s~n~d lo~tion was i~~ ~ o~ r~res~tative on 9/1/81 ~d ~e cle~-~ ~s f~d to ~ acc~t~le. ~pro~l is gi~n to lea~ the pits o~n, ~e well he~ on, ~d ~e cellar ~en. This appr~l is given ~til 9/1/82. A ,~s~uent i~~ion will ~ n~~ ~ ~-s~r 1982. By Order of Approved by" ~ ~]~t' [],~[~ COMMISSIONER the Commission Date Form 10~03 ~ ~] ~ ~ ' Submit "Intentions" in Triplicate Rev. 7-1~0 ~ [g~'~[ ~' ~ and "Subsequent Reports"in Duplicate 12) Thru~ ALASKA OIL AND ~S CONSERVATION COMMISSION Moyle H. Hamilton~ Chairman Lonnie C. Smith'S/ Commissioner Bobby Foster'~j-~ Petroleum Inspector July 21, 1981 Inspection of SOHIO'S CHEVRON TRACT WELL 23-18-11-12, Sec. 7, TllN, R12E, UM Suspended. Sunday June 28, 1981z I traveled this date to Prudhoe Bay to ~spe~t'~-'sev~r'~'' i~-ti.ons after Hoyle Hamilton, Commission Chairman, received notification of oil spills. As the attached pictures show a small amount of oil did reach the tundra. This was contained with booms and, when I was at the location, was being cleaned up. Some drilling fluid had apparently seeped out of the reserve pit and caused discoloration of a small area - 25'x40' on the back side of the reserve pit. I recommend to the Commission that Petroleum Inspectors inspect this location frequently until these problems have been cor- r ect ed. In ~ammary, I inspected the location at SOHIO'S CHEVRON TRACT ~LL 23-18-11-12. SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company I RES ENG 1 ENG 2 ENG 3111 'C' STREET TELEPHONE (907)265-0 00 MAIL: POUCH ~612 --~. ANCHORAGE. ALASKA 9~50~ 5TAT TEC SOHIO--BP ALASKA PRODUCTION DIVISION TO: STATE OF ALASKA Alaska Oil And Gas 3001 Porcupine Drive Anchorage, Alaska i FILF: Conservation CommissiOn 99501 Attn: William Van Alen REFERENCE: Transmission of core chip samples /~The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- 14 Boxes Of Core Chip Sample~~-,: Prudhoe Bay Unit Well ~(Chevron Tract Well) Interval of 9805.0 ft. thru 10,64f0 ft. 18-11-12 Sent by, /Kevin A, Brown SOhio,! Core Store Technician RECEIVED DATE EB 1981 - Alaska 011 & Gas Cons. Commission SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 SOHIO-BP ALASKA PRODUCTION DIVISION TO: MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 SFO/UNIT/STATE: REFERENCE: 1/29/81 #609 SOHIO FINAL DATA The following material is being submitted herewith. Please acknowledge receipt by signing a · ' ~~turning it to this office:-- '~ .... (23) 18-11-12~J~ud_log 10/26_--12/11/80 .... ., --, ----, __ ~11-13 Mudlog 12/30-1/11/81 ~FO/UNIT/STATE: (C-14 (-Marathon) .~F-2 Bottom Hole Pressure Data Form & Survey (Go) I! f! I! " " " (Go) RECEIVED DATE RECEIVED FEB - 2 1981 19 Alaska 0il & 6as Cons. Commission Anchorage Carol Krieter Well Records 1/25/81 1/18/8'i SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: STATE OF ALASKA -i-co 3111 'C" S'] ANCHORAGE, TELEPHONE (90' MAI L: POUCI ANCHORAGE, AL~ 1/7/81 #564 CgNFER" REFERENCE: c SOHIO FINAL DATE ON CHEVRON TRACK WELL(23-18-11-12) he following material is being submitted herewith. Please acX now l ed ge receipt by signing a opy of this letter and returning it to this office:- DIL/SFL 11/8/80, 12/3/80, & 12/7/80 BHCS 11/8/80 &12/7/80 FDC 11/8/80 &12/7/80 FDC/A 11/8/80 &12/7/80 P. FT 1218/80 Nat. G~=na Ray Spectroscopy 12/8/80 #1,2&3 #2&3 #2&3 #2&3 #1 #3 Magnetic Single Shot Survey Gyroscopic Survey Whole Core Summary Sheet 1o/18-11/1o/8o 12/7/8o Carol Krieter Well Records 2" & 5" 2" & 5" 5" 5" 5" RECEIVED SOHIO ALASKA PETROLEUM COMPANY January 23, 1981 3111 "C" ST MAI L: POUCH 6~*~--F~~ ANCHORAGE, Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Chevron Tract Well 23-18-11-12 Enclosed, in duplicate, is Form 10-407, Completion Report, for the above-named well together with the Well History, Well Logs, Directional Surveys, and Core Summary Sheet. This well has been plugged and suspended. Enclosures cc: Well File ~17 Geology Yours very truly, District Drilling Engineer RECEIVED 'STATE OF ALASKA ~"".~, AND.GAS. CONSERVATION ~.- . MISSION WELL COMPLETION OR RECOMPLETIONREPORT AND LOG ' - '1. Status of Well -- Classification of Service Well OIL [~ GAS [] SUSPENDED ., ABANDONED [] SERVICE [] , , 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Company 80-108 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20511 4. Location of well at surface 9. Unit or Lease Name 809' NSL, 3893' WEL, Sec. 07, TllN, R12E, UPM Prudhoe.. . Bay Unit At Top Producing Interval top Sag R. SST. 10. Well Number 3012' SNL, 3360' WEL, Sec. 18, TllN, R12E, UPM Chevron Tract Well 23--1'8--11' At Total Depth 11. Field and Pool 3695' SNL, 3566' WEL, Sec. 18, TllN, R12E, UPM . Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 73' AMSLI ADL 28262 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. ]15. Water Depth, ifoffshore ,16. No. of ComPletions' 10/20/80 12/6/80 12/24/80[ Ifeet MSL one I · 17. Total Depth (M D+TV D) 18, Plug Back Depth (MD+TVD) i 9, Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10906'MD 9303'TVD 10735'MD 9182'TVE YES [] NO [] none feet MD 1800' 22. Type Electric or Other Logs Run DIL/BHCS/FDC/CNL/GR/Cal, HDT, NGT, R~T, CBL 23. CASING, LINER AND CEMENTING RECORD ' - · SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Conducto:- Surface 110. 26- 7 cu.¥ds, concrete . 13,3/8" 729 L-80 Surface 2684' 17 1/2" 3720 cu. ft. Permafrost II 9 5/8" 47~ L-80-- Surface .9750' 12 .1/4".. !390 cu.ft. Class G;280.cu.ft..Permafro: 7" 299 L-80 9243' 10906' 8 1/2" 354 cuoft. Class G 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) None None ~ 26. ACID, FRACTURE, CEMENT SQuEEzE, ETC. '. ~: - . ! , ~ DEPTH I.NTERVAL(MD) AMOUNT& KIND OF MATERIAL USED ,.~ 9i91'. 9 '5/8". bridge plug - 58 cu. fi ~.,77.~: ~-."/ :~- ~.-,t,~ , .Class G cement ' · --... - . . , , · , , 2_500 ' _2] 0 ' ~.~_m~nt_ z~l t~a - · .: . , . PermafrSst ~C 27. ' pRODuCTION TEST Set'retainer at 10610' and squeezed-pe! DateFirstProducti0n Method of Operation. (Flowing, gaslif_t, etc.) tions with 60 cu.ft. Class G cementi ¢ ~:~ .. Top .of cement at 10426'. Date of Test Hours Tested I PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL C'HOKE SIZE GAS-OIL R~,TIO ;. ' " . ' TEST PERIOD I~ Flo~ ~ub:i-ng Casing Pressure· ,., CALCULATED ~- OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) "Pre~. · .. -' : . . -- 24-HOUR RATE I~ ' ' ' CORE DATA · , -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See attached Core Sunm]ary. Sheet. R E C E IV E D JAN . ,, ,12 ;t C Eora' Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · 29. 30. GEOLOGIC MARKERS FORMATION TESTS I NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea Sag River SST. 9813' " 8404' 3hublik 9851' 8434' Ivishak 10026 ' 8571 ' 31. LIST OF ATTACHMENTS Well History, Well Logs, Directional Surveys, Core sUmnary Sheet 32. I hereby certify that the foregoin~d correct_to the best of my knowledge Signed Title District Drilling Date I-- l ~'-- ~t 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 whe.ther from ground level (GL) or other elevation (DF, KB, etc.). , · Item '23: AttaChed'~supplemental records for this well should show the details of any multiple stage cement, lng and~' ~[.he;~ Ioca. ti.0':q~..ef the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water jection, Gas' Inj~cti6ni'ShUi~-"]n, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ~]',L HIS~OR~ ~ WR~C~ W~r,~, 23-18-11-12 Spudded well at 1500 hours, October 20, 1980. Drilled 17 1/2" hole to 2700'. P~n 68 jts. 13 3/8" 72# L-80 Buttress casing to 2684'. Cemented with 3720 cu. ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2645', tested casing to 3000 psi, okay. Drilled out to 2721', ran leak-off test to ,7~ psi/ft, gradient. Directionally drilled 12 1/4" hole to 9750'. Ran 250 jts. 9 5/8" 47# L-80 Buttress casing to 9750'. Cemented in two stages: First stage with 1390 cu. ft. Class G cement; second stage by down-squeezing 9 5/8" x 13 3/8" annulus with 280 cu. ft. Permafrost C cement follow~ by Arctic pack. Changed mud over to Oil-Faze. Cored from 9805' to 10644', a total of 15 cores; cumulative cores cut 840', cumulative cores recovered 835'. Ran open hole logs. Ran 40 jts. 7" 29# L-80 Buttress liner to 10906'. Cemented with 354 cu. ft. Class G cement. Cleaned out to 10735', tested liner to 3000 psi, ok. ay. ~ ~ Ran CBL. Perforated at 10600' to 10620' (4spf). Ran DST test of perforations. DST of perfo~a~ions ~t 1060-0' t~s{ed Ivishak water table, no flow to surface. Final flow pressure equals 4081 psi. Final shut-in pressure equals 4353 psi. Changed hole to 10.0 ppg. NaC1/NaBr. Set retainer at 10610', squeezed with 60 cu. ft. Class G with 18% salt. Cleaned out cement to 10426'. Tested liner to 3000 psi, okay.. Set 9 5/8" bridge plug at 9191', placed 58 cu.ft. Class G cement on top of bridge plug. Laid 56 cu. ft. Permafrost C cement plug from 2500' to 2360'. Changed over top 200' of hole to diesel. Nippled down BOPE. Installed and tested adaptor flange and single master valve to 3000 psi. Released rig at 1800 hours, December 24, 1980. NOIr: Suspension of Well 23-18-11-12 witnessed and approved 12/22/80 by Harold Hawkins, Alaska Oil & Gas Conservation~ission. RECEIVED SOHIO ALASKA PETROLEUM COMPANY 3111 '°C" STREET ' ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 January 8, 1981 Gentlemen: Enclosed is a report summarizing the drill-stem test and electric line pressure gradient/fluid, sampling., performed ..on ..... the.. Chevron._ ~Tract Well 18~11-12 during December 1-16, 1980. Copies of the Halliburton formation testing report and the Chemical Laboratories Inc. analysis of the RST and DST water samples are also enclosed. If you have any questions regarding the enclosed data or testing operations, please contact Rick Whitlow, Field Engineering, at 265-0563. Very truly yours, G/P: PRW :mlh Encosures JA; } 1 6 1981 Alaska Oil &AnchorageG~$ Cons. C°~r~is$io. CHEVRON TRACT WELL (18-11-12) DRILL STEM TEST AND R~'£ I. INTRO~CTION This report contains a summary of associated operations, data and results pertaining to the DST and RFT on Chevron Tract Well 18-11-12. The objectives for the DST and RFT were as follows: 1. To obtain uncontaminated water samples with consistent resistivity readings. 2. Determine a valid temperature and pressure gradient across the Sadlerochit-Sag River interval. 3. Record well conditions during flowing and shut-in periods for reservoir parameter calculations. II. RESULTS 1. A' pressure gradient from the base of the Sadlerochit to the top of the Sag River was obtained using the RFT (refer to table on Page ~2). 2. A clem 1/2 gal. formation water s~le was t~en with the Schlc~n- burger 1~ at 10,595 ft. BKB (9007 _~S). The s~le had a field reading resistivity of .362 OHM at 60OF ~ a Ch~nical L~boratories Inc. water analysis resistivity measurement of .35 O~ and calculat~ o resistivitY of .34 O~ at 68 F. 3. A one gallon oil/mud-filtrate sample wa t~ken with the I~ at 10,370 ft..BKB (8,837 5'JDSS). ne pressurized s~le was transferred at 4000 psi and 50°F to 5 core lab sample k~ttles totaling 2925 ML of sample for I~ analysis. 4. A valid t~rature gradient was not obtained during the DST t~m%~era- ture survey. ~ne 30 minute stops were not long enough for the temperature reorder to stabilize. .o~.e final shut-in temperature at 10,549 ft. BKB (8972 ~'v]DSS) was 226.8 F. 5. The well did mt flow to surface during the DST. Prc~uced formation water - cushion head and pressure loss into the wellk~re caused the well to be essentially shut-in with the liquid level at 682 ft. BKB. 6. A clean 12 gal. formation water s~le was obtained ~for. om the down, lc DST chs~er. A field resistivity of .360 O~ at 60 F was measured. The formation water samples were sent to Chemical Laboratories Inc. for analysis. The laboratory reported an average measured resistivity of b3.30HMAT69°F ar~ an average calculated resisitivity of .33 OHM at 68 F for the 12 samples. 7. Good charts were obtained from the 3 pressure recorders and tempera- ture recorder. The charts were sent to Halliburton for analysis. Refer to Table 91 for final readings. III. SUMMAR~ OF OPERATIONS 12-8-80 1600 RIH with RFT, tied-in with DIL/GR. Made the following RFT pressure stops and collected a 1 gal. water sample (5 gal. purge) at 10,595 ft. BKB (9007 TVDSS). RFT PRESSURE READING AND SAMPLING SUMMAR~ MD ('BKB) HYDROSTATIC PRESSURE (PSIG) RFT PRESSURE (PSIG) Before After Initial Final 10,770 10,664 10,602 10,595 4977 4979 17 4468 4935 4935 26 4380 4907 4909 11 4364 4904 4904 4220 4363 Took 5 gal. purge and 1 gal. water sample at this depth. 10,554 4881 4888 4330 4343 10,525 4868 4877 3919 4337 10,450 4841 4846 3860 4318 10,301 4787 4790 3665 4284 10,190 4740 4742 4100 4270 10,120 4712 4711 3450 4266 10,035 4675 4678 4134 4260 * 9,949 4638 4646 1900 2082 * 9,932 4633 4636 495 530 * 9.,927 4630 4633 226 284 9,843 4596 4600 50 4265 9,833 4593 4595 35 4249 10,370 4820 4814 40 4301 *Stops in Shublik, very hard and low permeability, final pressures are not reservoir pressure. POH, collected water sample at atmospheric pressure. RIH for oil sample. Took 5 gal. purge and 1 gal. sample at 10,370 ft. BKB (8837 TVDSS). Transferred sample at 4000 PSI and 50°F over Mercury to 5 core lab sample bottles, 2925 ML total sample volune. DR3/A/03 -2- These samples are to be shipped to Core Lab for PVT analysis. · 12-9-80 0300-1600 Ran seismic velocity survey with Birdwell. 12-10 - 11-80 Rig ran 7" liner and c~nented. 12-12-80 Rigged up Otis line heater, flowlines, 500 BBL tiger tank, new lab and Noralco flowco manifold. Wrapped heat tape and insulation on flowline to heater to prevent freeze-up. 12-13-80 12-14-80 Ran CBL/VDL/GR, good cement bonding across complete open hole section. 0000-0400 Flanged up Hydril - 7" Otis crossover. 0400-1100 Perforated 10,600 -. 10,620 ft. BKB interval with two 10 ft., 4" Hyperjet II carrier guns loaded with 4 SPF. Well was overbalanced by about 500 PSI so no wellhead pres- sure was seen after perforating. 1100-1400 Rig up Halliburton DST tools. Refer to Fig. 1 for assembly. Main gauges consisted'of: 1. One flow thru BT 0-6000 PSI pressure recorder. 2. TWo blanked off BT 0-6000 PSI ~r_essure recorders. 3. One blanked off TE 50-350 F temperature recorder. 4. Three maximum reading thermcmeters. All recorders were ran with 48 hour clocks. 1400-1900 RIH with DST tools on 3 1/2 and 5 in. drill pipe. Filled 1560 ft. of 3 1/2 in. and 1440 ft. of 5 in. drill pipe with 9.6 ppg NaC1 for a cushion. The 3000 feet M.D. of cushion was equal to 2300 vertical feet at T.D. (Ave. well inclination of 40 deg.). 1900-2300 Made 30 minute stops for temperature recorder at 9,600, 10,000, 10,400, 10,605 and 10,728 ft. BKB. Pulled packer up hole to 10,517 ft. BKB for DST. DR3/A/04 -3- 12-15-80 0000-0300 03:06 0305-0335 03:36 04:37 05:00 15:07 · Rigged up surface lines and pressure tested to 1,000 PSI with rig diesel. Set packer, open hydro-spring valve. No blow increased to very~ light blow in "Bubble Bucket". WHP = 0 PSI. Close DCIP valve for first shut-in, 60 minutes. Open DCIP valve for second flow period. Started with light blow and 0 PSI. WHP increased to fair blow. Switched gashose from "Bubble Bucket" to gas meter. Second Flow Period Gas Meter Rates Time WHT (OF) Rate (CFPM) 05:00 20 1.2 05:20 20 1.3 05:40 15 1.4 06:00 14 1.8 06:20 14 1.8 06:40 14 2.0 07:00 12 2.0 07:20 13 3.4 07:40 13 2.2 08:00 12 1.8 08:20 12 1.5 08:40 12 1.4 09:00 12 1.3 09:20 11 1.3 09:40 12 1.0 10:00 12 1.0 10:20 14 .9 10:40 14 .9 11:00 16 .8 11:20 15 .8 11:40 15 .7 12:00 16 .6 12:30 16 .6 13:00 16 .5 13:30 17 .4 14:30 18 .3~ 15:00 18 .2 Close DCIP valve for final shut-in. Well had essentially died due to the formation water-cushion head and pressure drop across the perforations. DR3/A/05 . -4- 23:40 24:00 Opened DCIPV reverse circulating port. WHP increased from 0 to 640 PSI. Topped off annulus with 3.5 BBLS. WHPsteady at 680 PSI. Started pumping to reverse circulate. Cushion reached surface after 7.1 BBLS had been p~nped. Adding the 3.5 BBL annulus loss to the 7.1 BBL cushion to surface vol~ne indi- cates that the well had flowed to 682 ft. BKB before shut-in. A total volume of 115 BBls of formation water and oil-faze mud filtrate was produced into the drillpipe during the DST. 12-16-80 01:20 02:15 03:00 04:00 07:00 14:30 Formation water and filtrate to surface. One quart samples were taken every 5 minutes while drill pipe volume was pumped to surface. Samples were very oily from the oil-faze mud filtrate. Drilling mud to surface. Total vol~e pumped to reverse-out was 124 BBLS. Blew down flow lines to storage tank with rig air. Released packer. Rigged down manifolding on rig floor. RIH to 10,695 ft. BKB and reverse circulated the drill pipe. POH with DST tools. Drill collar sample chamber to surface (2, 4 3/4" Jts.). Obtained 12 gal. of formation water sample from drain sub located at the base of the sanple chamber. There was a distinct separation between the formation water and the lighter filtrate oil in the chamber. The water sample had a measured resistivity of .360 OHM at 60°F. The resistivity was measured using a Schlumberger resistivity meter. Samples were collected, labeled and delivered to Chemical Laboratories in Anchorage for analysis. DR3/A/06 -5- 16:00 The pressure and temperature charts were recovered with all clocks and recorders mechanically sound. Please refer to Table 91 for a summary of the DST pressure and temperature field readings. Tne three maximum reading Mercury thermometers, located below th~ TE temperature recorder, had readings of 70©, 220© and 240VF. 18:00 Rigged down and moved test equipment. Enclosed. are copies of the Hal iburton Formation Testing Report with pressure-t~uperature DST charts and the chemical laboritories Inc. analysis of the RFT & DST water sauples. Field work and Report by Rick Whitlow Sohio Drilling Department DR3/A/07 -6- TABLE DST RECORDER READINGS SUMMAR~ Reorder No.: 3636 6103 6104 TE-47 Depth ft.'BKB: 10545 10541 10503 10549 Depth ft. TVDSS: 8969 8966 8938 89~2 Units: PSIG PSIG PSIG VF Range: 0-6000 0-6000 0-6000 50-350 First Flow and Shut-in Periods: Initial Mud Press: Initial Flowing Press: Final Flowing Press: Final Shut-in: 4941 1379 1528 4386 Second Flow and Shut-in Periods: Initial Flowing Press: Final Flowing: Final Shut-in: 4934 4913 * 1373 1371 * 1479 1486 * 4369 4350 226.2 1502 1551 1552 * 4123 4088 4081 230.1 4390 4369 4359 226.8 * Temperature readings subject to intrepretation due to thermal stabilization time of temperature recorder. DR3/A/08 -7- · ('ft. BK~. . · .--~ ~ 3~ 1/2" + 5" Drillpipe to ~face--connected @ rig floor to Halliburton "Wrap-A-Ro~ ]" Flowhead Manifold c/w swivel 10426' 3 1/2" IF Box by 3 1/2" FH Pin x/o Impact reversing sub c/w single alumin~n shear plug (3 1/2" OD, 2.25" ID) DCIPV Valve (3.88" OD, 0.87" ID) Two jts. 4 3/4" Drill Collars: (Capacity = 0.4 bbls.) 7" N-80 29 lbs/ft, casing 10497' 10503'(BT 6104 Sample Drain Sub (3 1/2" IF Box by 3 1/2" FH Pin) Hydro-spring Tester Valve (3.90" OD, 0.625" ID Flow Restriction) · Flow-Through BT gauge recorder carrier (3.87" OD, 3.00" ID) VR Safety Joint (3.88" OD, 0.75" ID) 10517' 10541' (BT # 6103) 10545' (BT 9 3636) 10549 ' (TE-47) 7" "Hook-Wall" Packer Assembly (5.75" OD, 2.18" ID) 20' Perforated Anchor c/w 1/8" slots: (2 7/8" OD, 2.00" ID) Blanked-Off BT Cases #1 & #2 & TE-47 Temperature Recorder (3.87" OD, 3.00" ID) - Perforated intervals (c.f. DIL/GR log) 10600-10620' BKB "~ Formatior,~esting Serv'~ce Report HAl l lBIIR TIIFI SER IlIBE$ DUNCAN, OKLAHOMA .... TIME L Each'Horizontal Line Equal to 1000 p.s.i. ~' ' -' FLUID SAMPLE DA Date 12-14-80 Number 564418 · sam'Pler Pressure ., '~/~7 P.S.I.G. at Surface Kind Halliburton __ of D.S.T. CASED HOLE Location ANCHORAGE Rec?very: Cu. Ft. Gas cc. Oil -ce. Water /2r~L I~)~to' 'rater L.D. PHILLIPS WUne~ R. WHtlLOW - ;./ I ~7 a~'/_ Contractor BRINKERHOFF DRILLING COMPANY DR Tot. Liquid cee , · APl ~. ~ ,F. EQ U I PM E NT & H aL E DATA ,,, Gravity_ Gas/Oil :Ratio mu. ft./bbl.,.. Formation Tested Sad.~:, 1 erocla i t ~t. -- RESISTIVITY CHLORIDE Elevation CO.TE"T 20' 10600-10620' Net Productive Intental Recovery Water .362 @ 60 °F. ppm All Depths Measured From Kelly Bushing ,. =, Recovery Mud ~ @ ~ °F. ppm Total Depth 10735 ' Ft. Recovery Mud Filtrate ~ @ ~ °F. ppm Main Hole/Casing Size 7u ... Mud Pit Sample ~ @ ~ °F. .npm Drill Collar Length62,30' _I.D_2,25" Drm Pipe Length2316-6547-1558'~.D. 4.010-4.276-2.t~{ Mud Pit S0mple Filtrate ~ @ ~ °F. ppm Packer Depth{s) 10517.17 ' . Ft. _ Mud Weight 10.3 vis ~.~~ ec. Depth Tater Valve--- 10497.18' _Ft. TYPE AMOUNT Depth Back ~ Bottom Cushio~ NACE water 3000' Ft. Pres. Valve Choke Needle Choke .625" _ valve Recovered 2198 Feetof 9.6 PPG Nacl cushion (35~ bbls.} Recovered 150 Feetof 10 3 PPG rat hole oil base mud ' Recovered 7642 Feetof fomation water and oil base filtrate Recovered 1'2 gal ~ formation water in drill collar Recovered Feet of Remarks This well was sh~t below oil pay into the water zone, to determine the resistivity, chloride and temperture of water zone. Gauge No. 6104 Gauge No. 6103 Gauge No. 3636 TIME TENLPERATURE · Depth: 10503- 28 Ft. PepS,,,: 10540- 52 Ft. Depth: 10544 5Z~|. (o0:00-z~:0o hrs.) 10548.6' 48 Hour Clock 48 Hour Clock 48 Hour Clock Tool 12'-15-80 Est. 231 I'F. BlankedOff No Blani~eclOffYes BiankedOff Yes Opened 0305 ~ ' Opened 12-16-80 Actual e~ ~ ~ 'F. Pressures Pressures Pressures Bypass 0305 Reported Computed Field Office Field Office Field Office Initial Hydrostaiic 4900 4912,6 4929 4934,3 4932 4941.3 Minutes Minutes mnitial 1356 1370.5 1352 1373.0 1358 1378.6 " --~o Flow ~'c Final 1482 1485.8 1463 1479.3 1542 1527.5 31 27 i"~ Closed in 4345 4349.7 4353 4368.9 4365 4386.4 61 60 ~3 Initial 1546 1552.0 1527 1550.7 1560 I 501.8 ~ Flow Final '4060 ' 4080,7 4081 4087.8 4108 412P.7 63(3 6.35 Closed in 4345 4359.1 4353 4368.9 4365 430(3.1 718 718 , , ~ Initial .~o Flow' · - ~ Final Closed in , Final Hydrostatic 4880.9 4886. ~ 4ql R- q - - '3RM Ill--"~2 -- PRINTED IN U-~.A. FORMATION TEST DATA LITTLI'S 111033 75C, ~/10 4~ -~' ~ ~ : 564418 Cqsing perfs-10'600-10,620.~aotmm c~ok~ .625" ~urf. tem~- 14 _'F Ticket No, Gas grovit'y , Oil gravit7 , GC)R Spec. gravity .Chlorides .npm R,s~, 362 @ 60 'F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED ID ate Choke Surface Gas Liquid !Time a.m. Size Pressure Rate Rate Remarks psi MCF BPD 12-14-80 12:00 Engaged stylus _ 13' O0 Tool s made up 18-48 3000' cushion in pipe, 20'40 ~ ", Drill DiDe ca 9600'. stop for 30 minute~ for temperature survev 222.8° 21 -,23 Dri 11 Di De @ 10.000. wai ted 30 mi nutes 222.8° 21-57 Drill oiDe ca 10400-' 222o 22'28 Drill ~ipe ca 10605' 221.2° !. 22-55 Drill pipe ca 10728'- 220.4° Pulled back uD to oacker depth and hooked uD surface equipment 12-15-80 03'05 1/8"N~ Ooened tool with no blow 03'36 ¢1 osed tool 04'37 0Dened tool with a very weak blow. . increased to a fair blow add started to decr~_a 15'07 £1 n_~d tnnl 23'44 640 £1n~d in ~t ~rfac~_= n?n ~£TP tn reversed out. i2-Zb-~U 03'05 Pulled packer loose and lower to botton to bottom and reverse bottoms up 14:30 Tools to surface .... · , , ~ ~! , i'°"-'--"'-''"'"'''-':'''''''-''''. PRODUCTION TEST DATA P-O 1 2 3 4 5 6 P-O 1 2 3 4 5 6 7 8 9 lO 11 12 13 14 15 P-O 1 2 3 4 5 6 7 8 9 10 11 12 SOHIO ALASKA PETROLEUM COMPANY Lease Owner/Company Name 564418 Ticket Number B.T. 6104 B.T. 6103 B.~. 3636 Depth 10503' Depth 10540.52' Depth 10544.54' 9347-48 9299-48 + ! ! Temp. Log ~ { I Temp. Log Temp. · (-~ Corr. .000' { ! Corr. .000' { ! Corr. ii II 0132 136'4.3 .0127 1373.0 .0119 '1433.8 II .O2-27 1383.2.0218 1393.6.0204- 1463' 2 ~ '' .0321 1432.1.0309 1426.9.0290 1487.1 ii :0415 1455.8 .0399 1450.7 .0375 1514.6 .0510 1485.8 .049 1479.3 .0460 1527.5 5' minui:e intern,als 5 minu'[e inter,als 5 minute intervals *-2 mi~ute int~:rval' *-2 mi lute int..~rval *-2 minute interval First (:IP FIRST DIP FIRST' CIP .000 1485.8 .000 1479.3 .000 1527.5 !1 0471 4349.7 ~ 0481 4367.4 .0467 4386.4 ~ .0538 4349.7~ .0550 4368.9 .0534 4386.4 .0606 4349.7~ ~ .0618 4368.9 .0600 4386.4 .0673 4349.7~ ~ .0687 4368.9 .0667 4386.4 ~ .0740 4349.7~ .0756 4368.9 ,0734 4386.4 I .0808 4349.7~ .0824 4368.9 .0800 4386.4 II .0875 4349.711 .0893 4368.9 .0867 4386.4 II .0942 4349.711 .0962 4368.9 .0934 4386.4 II.1010 4349.711 .1030 4368.9 .1000 4386.4 II4 minu:e inter',al~ II 4 minu~:e inter/als !14 minutl.: intervals II SECOND FLOW !! SECOND' FLOW IIsEcOND :LOW II .000 ].55z.0 II .000 ].550.7 II .000 1501__.8 II .0336 1638.8 II .0331 1633.3II 0335 1712.4 Il .0504 1700.3 II .0497 1692.0 .0502 1776.5 _ II .0672 1766.5 !1 .0662 1.755.5 0670 ]R71.7 Il .0840 1828.0 ,, .o828 1815.8 II.0837 II .]oo~ 1886.4 II .0993 1885 7Il .1004 1957_8 II ..1176 1943.2 II .1159 1939.6 .1172 ~mn.q I 1344 2004.7 II .1324 1996.8 II .1339 Ii i~1~ 2068.2 II .1490 2046.3 II .!507 71z!.1 Il .16R{') 2120.6 il .1655 2100.6 Il .1674 II -,~a~ 2171.4 II .1821 2169.3 II .~]84~1 I - ~n.~,~ 2223.8 I I . 1986 , ~'~'nq ~, I I 9nnR 9~R'~ n Remarks: - PAGE I P-13 14 '15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 SOHIO ALASKA PETROLEUM COMPANY Lease Owner/Company Name 564418 Ticket Number B.T. 6104 B.T. 6103 B~I'. 3636 Depth 10503' Depth 10540.52' Depth 10544.54' 9347 -48 9299-48 10051-48 ii i Time Oefl. Log t + () Temp. Log , Temp. ~ , Temp. .O00" (-) Corr. .O00" ( ! Cor~. .OO0" I ) Corr. CONTINI IEb CONT NUED CONTINUED 'Ill J J .2352 2320.6 .2317 2308.2 2344 2377.2 I1 2520 2374.6 II .2483 2359 4 2511 2441.3 II 2688 2420.6 .2648 2408.9 2678' 2485.3 II il .2856 2474.6 .2814 2463.2 2846 2523.8 II II .3024 2528.3 .2980 2514.3 3013 :;'586.3 II , 3360 2630.9 .3310 2621 0 .3348 2693.0 II ~ .3528 2681.3 .3476 2673.5 .3515 2729.7 ~1 ~ ~ .3696 2736.5 .3641 2726.1 .3683 2781.2 ~1 II .3864 ~7~3.9.3807 2775.4il .38so ~829.o II il .~0~ ~3~.8 II .3972 2826.4II .~0~8 ~87~.9m II il .4200 2881.7 I! ,4138 2878.9 II .4185 2922 7 II :14536 2979.4 .4469 2971. 4520 3021.9 Il .4704 3023.6 .4634 3020 · 4687 3067.7 II '11 .~7~ ~o~7.~ .~oo ~o7o ~ ~o.~11 !1 .~o~o ~.~ il .~ ~ ~o~ ~,~ II II :s~o8 3164.0 II .s~3~ 3166.1 II .s~89 3225.9 II II Il .5544 3261 8 .5462 3250.7 5524'" 3316.8 Il )) .5712 3299.6 I) .5627 3295.5 5692 3357.1 II II .sseo ~3~,0.~ II .~93 ~335.,~ml .5~s9 3~9~.9 II !! .6048 3373.8 .5958 3373.7 ~,~0., II mi 6216 3413.2 .6124 3418.5 .6194 3474.3II mm 6552 3487.3 .6455 3487.2ii.6529 35,47.6ii !) -6720 3522.0 °6620 i. 3522.5 )~-66961 3582.4 II mi I! .7056 3588.6 .6951 3590 0II 7031 3639.1 I[ II .7224 3618.6 .7117 3623.7 II .7198 3663.0 II !1 .7392 3650.3 I! .7za~ 3654.3 II .7366 3699.6 II !1 .7560 3678.8II .7448 3683.2 II .7533 3736.2 II i i .8064 3762 6 .7944 3766 I .8035 :3807.6ii I I .a~3~ 3789.5 Il .8110 3795.8 II _8203 3833.3 I I I I .24oo 3814.8 Il .8275 3821.5 l! .F~370 3858.9. I I I ! .8568 3838.6 I.I .8441 3845.6 Il R.~37 3884.6 II ii .R736 3860.7 ii ,8606 3871 3il 27o5 3910.2 i m I I _ag04 3882.9II.8772 3890.6 II :R877 3932.2i i II .q072 3905.0 II .8937 3913 11 [ 904f) 3952.3 I! ! i o~an ~qp~ n II .ql(13 '~q~9 a I ~en~ ,]3q74.3 J I Remarks: 80- 2860 PAGE _ SOHT(I ALASKA PETROl FIlM COMPA. NY Lease Owner/Company Name 564418 Ticket Number P-56 57 58 59 60 61 62 63 64 P-O 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 t7 18 19 20 21 22 23 24 25 26 B.T. 6104 B.T. 6103 B.T'. 363§ Depth. 10503 ' Depth 10540.52 ' Depth _ 10544.54 ' PAGE 3 iii i i i i i i Time Deft. Log t + 1~ Temp. Log Temp. LOg , . Temp. .000" ~! C, orr. .000' I ! Corr. .000' ! ! Corr. II .9408 3946.2 .9268 '3953.3 .9374 3994.51 .... 11.9576 3974.6 .9434 3977.411.9542 4012.8l .9744 3987.3 .9600 " 3995 1 .9709 4031.1~ II 9912 4004'.7 .I .9765 4011.1 I! .'98~7 4049.411 i I 1.0080 .4028.4 9930 4028.7 I! 1.0044 4060.411 11].o~4~ " 4039.5 1.0096 4046.3 1l'-02" I I ~.o~ 4055.3 1.0261 4063.8I! 1.0379 4097.0I I I I 1.0584 4069.6 1.0427 4078.2 1.0546 4111..711 II 1.n67- 4080.7 1.051' 4087.8 II 1.0630' 4122.71 ] II iff rnin~i~.m int~_"val_~ 10 minUte inter~als I110 minute intervals II I-! *,.~ mi ~ut,_ int,:rval-~ *-5 minjte intervals 1m*-5,minute intervals II II II il SECOND CIPL SECOND ZIP " S'ECONDCIP II II .000 4080.'7 .000 4087.8 .000 4122,711 II .0017' 4341.7 .0017 4340.2 .0017 '" 4'~79.111 i1' .0050 4344.9 .0050 4348.2 .0050 4380.9~1 '" 0067 4346.5 .0066 ' 4349.8' .0067 4382.7~1 .0084 4346.5 .0083 4351.'4 ,, .0054 .... 4382.7, , II .OlO~ .... 4348.1 .00994353.oII '.o~m' 4382.711 ii .0~-8 4348.1 .0116 4354.6 .0117 4382.711 il ..'0134 4348',1 .0132 4356.2 .0134 4384.611 ii .0151 4348.1 .01'49 4357.8 .0151 4384.6I I I! .0168 4349.7 .0165 4359~4' .0167 4386.4[[ II I minU':e i'nter, fals l'minut~ interv]ls' l minui~e interVals II Il' .0337 4351.2 .0329 4361.0 ~'0335 4388.211 !1 .0505 4351.2 .0495 436 .6'11 .0502 4388.211 · 0674 4351.2 .0660 4364.2 ,0669 4388.211 II .0842 4351.2 .0825 4365.8 II ,0836 4388.~11 il 10 minlJte intehvals 10 minute intervals I 10 minute intervals Il .2022 4352':"8 .1979 4368.9 Il .2oo8 · 3033 4354.4 .2968' ' 4368.9 11 .3014 4390.111 Il .4044 4356.0 .3958 4368 9J I ,4019 4390,111 Ii .so s 4357.6 .4947 4368.9II I II .6066 4359.1 I .5937 4368"]9II ,6030 439o,11I Ii 7077 4359.1 .6926 4368.9 Il .7035 Il .8088. 4359.1 .791'5 4368.9 Il .8040 Il .9099 4359.1 .8905 4368.9II .9045 Ii 1.0111 4359.1 .9894 ,, 4368.9 ].n%~ 4_~qn_~ll II, 4359.1 1.0884 4368.9II II 60"min)te"intei~vals 60 minute intercals Il 60 minute intervals Il II 1.210 nte 4359.1 1.1840 4368.9!11.21'130 a~qn_~l I II 5R minJte i *val ' 58 minu~.jnter~al ' I ~8 minute interval' !1 Remarks: 80-2860 O.D. 5" Drill Pipe or Tubing Drill Collars ..................... Reversing 'Sub ' ~ n Water Cushion Valve ............... 5" "3.5" Drill Pipe ....................... Drill Collars ..................... Handling Sub & Choke Assembly ...... 3.5" 3 7 8 II Duo~ aP Valve ................... / Dual CIP Sampler .................. 5" Hydro-Spring Tester ................ Multiple CIP Sampler ............... Hydrospring tester Extension Joint 3 7/8" J. D. 4.010" 2.12" 4.276-2.602" 2.43" .87" .625" 2.25" .625" .625" 3.00" 1.25" AP Running Case ......... '..' ........ 3 7/8" Hydraulic Jar .... Big. J.o. bn ........ 3 7/8" VR Safety Joint .................. 3 7/8" Pressure Equalizing Crossover ......... Packer Assembly ................... 5 3/4" 2.36" Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................. ' 2 7/8" Pressure Equalizing Tube ........... BLANKED OFF BT CASE 3.75" Blanked-Off B.T, Running Case ....... 3.75" Temp. recorder 3,75" Drill Collars ...................... Anchor Pipe Safety Joint ............ Maximum temp. 1.00" Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... 2. 441_" 2.50 " ~. BN" 2.50 " LENGTH DEPTH 2315.66~ 1.00' . 6547.34~i558" 4.5' 6.28' 10425.93' 1.33' Tiqht hole sub 62.30' Drill collar 1.34' Tight hole sub 6.10' 4.92' 5.00' 10497.18' 3.17' 10503.28' 3.60' 10517.17' 20.55' 4.02' 4.05' 4.95' 10540.52' ] 0544.54 ' 10548.59' 1.00' 10553.54' 10735' LITTL£'S 111036 7SC 2/10 ,o,.,,,,_,,,_,,,,,,,,,,,,.,.,. EQUI PMENT DATA CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 Anchorage, Alaska 99509 TELEPHONE (907)-279-4014 274-3364 ANCHORAGE INDUSTRIAL CENTER 5633 B Street OPBRATO]t WELL FIELD. COUNTY 8TATI WATER ANALYSIS REPORT Sohio Alaska Petroleum Company DAT~ December 17,1980 Chevron Tra_ct 18-11-12 LOCATION NQ., ,rth Slope PORMATION INTERVAL Alaska 8AMPLE FROM_. RFT 5955 ~a & CONCLU$ION~'.- Sample taken December 8, 1980 Barium (Ba) mg/1 4 Strontium (Sr) mg/1, 26 Iron (Fe) rog/l, Boron (B) mg./1, , · 0.3 ,130 ckr~um (cr) mg/1 ..... ,<0.1 Cbpper (Cu) mg/1. <0.1 Lead (Pb) m~/1 <0.1 Nickel (Ni) mg/1 .... <0.1 Silicon (Si) rog/1 ..... 27 7750 35 120 22 - 337.13 0.90 5.99 1.81 __ 345.83 55 1.14 11400 321.48 __ 0 ---- 1415 23.21 -- Ohurvld pH .... 20079 Spec~3c ~ ~ 6~'F.: 19752 Obo~v~ 7.3 ~ .... 0.35 0.34 RECEIVED WATER ANALYSIS PATTERN Sample ahoy, de~'n'b~ MEQ per Unit JAN1 6 ]981 Alaska Oil & Q~s Nm Cl 20 Na Cl HCO, Ca 2 HCO, SO~ 2 Mg SO4 CO. 2 Fe CO, MOTE: CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 Anchorage, Alaska 99509 TELEPHONE (907)-279-4014 274-3364 ANCHORAGE INDUSTRIAL CENTER 5633 B Street OPERATOR W~LL NO. FIELD COUNTY STATt WATER ANALYSIS REPORT Sohio Alaska Petroleum 18-11-12 North Slope Alaska DAT~ January 5,1981 ~AB NO. 6015-1 LOCATION . -- FORMATION ..... IIqTERYA~- SAMPLE FROML. Drill Collars ~~S & CONCLUSIONS. sample No. 2, 12-16-80. ~ ..... 72 ~ ...... 200 Mqmmhua ..... 26 8042 349.81 8,d~ 1.84 ~ ...... 9.9 8 C,~t, ..... 2.14 BL:,rbo~to 48 11800 0 1830 8~cific r,sistn~ 0 mtq/l 1.00 332.76 30.01 _ 36 3.77~ 0.34 ~~ 0.34 ,a.~~ Mg WATER ANALYSIS PATTERN Sample aboye descn~ MEQ per Unit Cl 20 Na HCOa 2 Ca SO. 2 Mg CO, 2 Fe MOTE: Mf/I----M~,f::d i~r ~ If,q/l= Bf~Tt,m eq,dvubeu per b Cl HCO$ $04 CO, CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. Anchorage, Alaska 99509 274-3364 5633 B Street OPEKATO]t WELL NO. FIELD COUNTT '~TATI WATER ANALYSIS REPORT Schio Alaska Petroleum flmn~y DATm January '5, 1981 18- ] 1-12 LOCATION North Slope FORMATION INTERVAl. Alaska LAm NO. 6015-2 Drill Collars KEMARE8 & CONCLU$IoN~: sample No. 3, 12-16-80. 8155 354.76 82 2.10 ChkrMo ...... 200 9.98 24 _ 1.97 S~trbo~to ..... - -- O~,.~d pH 368.81 21390 _ Specific redsmnc- 20983 _ OboeFteC .... ,, 6.2 ~ .... 43 0.89 12000 338.40 0 - 1800 29.52 ,m -- _ .... 368.81_ , , , O. 33 0.33 Nm Mg WATER ANALYSIS PATTERN above descn%ed MEQ l~X Unit Cl 20 Na HCO, 2 Ca SO4 2: Mg CO, 2 Fe MOTE: Mr~I=MI~i~c:m IMf JS=r Meq/l= Mi~liTim ~ per Jfiir Cl HCO, S04 CO. CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. Anchorage, Alaska 99509 274-3364 5633 B Street ANCHORAGE INDUSTRIAL CENTER . WATER ANALYSIS REPORT OPERATO:R Sc~io Alaska petroleum ~YD&TE__January 5, 1981 WELL NO. 18-11-12 LOCATION FIELD North Slope FORMATION ... COUNTY INTERVA?- ' 8TAT~ Alaska LAm NO., 60] 5-3 8AMPLE FROM Drill 0ollars ~,,~,zs ~ Sample No. 4, 12-16-80 Po~mdnm ..... 82 Cektmn ...... 207 Mainfudum ..... 25 8178 355.72 I~,Cl oq, dvabut, ,n~l ....... Ob,,~ pH 1.34 10.33 2.06 __ 369.45 Sultan, 50 1.04 ChkwMo 12000 338.40 B~zarbo~t, 1830 30.01 H~ro,m, ..... - -- 21443 21026 6.3 WATER ANALYSIS PATTERN Sclk 8am~e above de~'n'bed MEQ 1~ Ualt Nil Cl 20 Na HCO, 2 Ca S04 2 Mg COs 2 Fe Cl HCOa S04 COs CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 Anchorage, Alaska 99509 TE LEPHON E (907)-279-4014 274-3364 P~NCHORAGE INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT OPE~tTO~ . Sohio Alaska Petroleum fbmpanYDAT]~ January 5, 1981. LAB NO.' 6015-4 ~rmxA, NO., 18-11-12 LOCATION FIELD North Slope FORMATION COUNTY ~ INTERVA?- · ~TAT~ Alaska _. 8AMPLE FRO~... Dri ] 1 (bllars F,~MARKS & CONCLUSIONS.' Sample No. 5.., 12-16-80 ~ m~/l 8odJ=m ...... 8244 Pe4afd=ms ..... 80 C&Jdum ...... 190 Mafnsdmn ..... 23 358.61 8u~ ....... 50 1.04 ' 2.05 Chkw~ 12100 . ~4].22 9.48 C.~~ ..... 0 -- 1.89 Blc~lx~tto 1815 29.77 -- .rctroz~ ..... - -- ToUl Calk,,o .... 372.03 T~ ~ ~ meYl ..... 215'81 NaCl oq~ n~l ....... 21166 Ob,rv~ plf .......... 6.3 0.33 ~u.-~ O, 33 ~m~ WATER ANALYSIS PATTERN Scale Sample above de.ri'bM MEQ l~x Unit NR Mg Cl 20 Na HCO, 2 Ca SO, 2 Mg COo~ 2 Fe Cl COs CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC~ Anchorage, Alaska 99509 274-3364 5633 B Street WATER ANALYSIS REPORT OPZ~ATOR Sohio Alaska Petroleum ~any DAT~ January 5,1981 W~LI, NO. 18.-11-12 LOCATION ~r~x~) . North Slope ~OR~ATXON COUNTY INTERVAT- ~I'A, TB Alaska. SAMPLR; FROM Drill Oollars F.~MAF~ & CONCLU~IONB: Sanp. le No. 6, 12-16-80 Se~mm ...... 8123 ~ ..... 70 Ca.baa ...... 189 M~amaahaa ..... 22 ~ ~ ,,~ll 353.34 S,dmt,, 49 ~.. 79 _ - ~ 11900 9.43 C.~-b~,~st, ..... - 1.8] Blcarbonat~ ..... 1815 -- H~ro.ta, · - 366,37 1.02 335.58 29.77 366.37 'Foul ~ ,omb, mfS1 ..... NeC1 oqsdvabnt, zng/l Ol~r,~ pH 21247' 20831 0,33 0.33 N, Mg WATER ANALYSIS PATTERN Scale ~.tmple above descn'bed MEQ per Unit Cl 20 Na HCO, 2 Ca SO,, 2 Mg CO, 2 Fe MOTE: MS/I = Mflll~rm~ Cl HCOs S04 CO, CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. Anchorage, Alaska 99509 274-3364 5633 B Street WATER ANALYSIS REPORT OPZ~ATOR Sohio Alaska Petroleum .Cc~TD. _any DATe January_ .5.1981 LA! NO. ,6015-6 ~r~LL NO- 18,11-12 LOCATION. FI~LD North Slope .. FORMATION CouN3"~ ,, r~TERVA~- ~TAT~ Alaska -- 8AMPLE FROM_. Drill 0ollars F.~MA~]Z8 & CONCLUSIONa: Sample No. 7, 12-16-80 ~ . . 8021 348.91 S=~,~ ....... 50.. .. '1.04 . ~ ..... 83 2 . 12 CM~k~ ...... ] ] 800 ..332.76 ~ ...... 205 10.23 C,~bemt, ..... O L -- ~ 25 2 . 06 Bi~'bo~t~ ] 800 29.52 _ I,~ ....... - -- H~Iro=m, ..... - -- ~ Catk,~ .... 363.32 74 ~ ~ =~/1 ..... 21070 N,Cl eq~ =eYl - 20656 Obae,,d pH- - ' ......... 6.2 r~=~ ~ ..... 363.22 -- ~ Iii ii ii iii 0.33 ea=~~ 0.34 .a=,~ WAT~ ANALYSIS PATTERN 8amlge above de~n~ MEQ .pe~ Unit N~ Cl 20 Na HCO= 2 Ca SO~ 2 Mg CO · 2 Fe Cl HCO, SOa CO, CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC, Anchorege, Alaska 99509 274-3364 5633 B Street WATER ANALYSIS REPORT OPE~ATO]~ Sohio Alaska Petroleum (~.y DAT~ January 5., 1981. LAB NO. 6015-7 W~LL NO-. 18-11-12 LOCATION FI~LD North Slope FORMATION COUNT~ INTERVA?- . 8TATt Alaska SAMPLE FROM Drill ODllars · .~~8 & CONCLUSIONS.- Sum~.le No. 8, 12-16-80 .8007 348.30 S,~,~, 47 _ . 0.98 88 2.25 ~ 11800 _ 332.76 _ 220 ,, 10, 98 Ctrbo,mt~ - -- 27 . 2.22 _ Bi~-t~t, ..... 1830 30.0~1 _ - - H~,ozm, ..... -- -- xot~ C,t~0m .... 363,75 ToM ~ ~ m~l ..... 21090 NaCt ~,,N~,~ m~t 20674 O~,~ pH ...... 6.2 T~ ~ ...... q6q_ 75 NI Mg WATER ANALYSIS PATTERN ~pl, mbove descn'b,d MEQ p~ U~t Cl 20 Na HCO- 2 Cm S04 2 Mg CO · 2 Fe Cl S04 COs .. ~'- ~ CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. Anchorage, Alaska 99509 274-3364 5633 B Street WATER ANALYSIS REPORT OPERATOI~ , S°h~,,',° Alaska Petroleum CompanY DATL January 5,1981 LAB NO, 6015-8 ~LL NO. 18-11-12 LOCATION,, F~LD Noz-T_h $1op~ FORMATION COUNT~ INTERVAL ~TATR Alaska SAMPLE FROM.. Drill Oollars ~A~S & CONCLUSION0: Sample No.. 9, !2-16-80 ~ ..... 84 ~ ...... 205 ~ ..... 24 · 8028 349.20 8~l~m 49 1.02 2.15 Cm1~44, 11800 332.76 10.23 C,~b~, ..... 0 -- 1.97_ B~tx,~t, ..... 1815 .... 29.77 -- ~rd~xMe ..... - -- Teml C.60,,~ .... . 363.55_ T~al ~ ~ m~;l ..... 21084 NaCI ,qnival,~ m~l 20670 O~ pH . . ......... 6.2 8pectfl~ r, mtstanc* ~ Ob,=,~ O. 33 ~ .... 0.33 , 363.55 , · WATER ANALYSIS PATTERN above de~cn%~ MEQ per Unit Cl 20 Na Cl HCO. 2 Ca HCO, Mg S04 2 Mg SO~ CO, 2 Fe oqwtvulenM ' per NMr fram CO, CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. Anchorage, Alaska 99509 274-3364 5633 B Street WATER ANALYSIS REPORT OPE~JkTOR Sc~io Alaska Petroleum fkx~_any DAT~. January 5, 198] LAB NO. 6,0.15,9 .. W~LL NO. 18-11-12 LOCATION .......... PIE[J) , North Slope FORMATION COUNI~ INTERVAt ~TATE Alaska SAMPLE FRO~[ Drill 0ollars · .~MA~S & CONCLUSIONS.' San~le No. 10, 12-16-80 ~m ...... 8277 ~mm~mm ..... 79 ~ ....... 214 m~,mm ..... 25 ~.[- ~ m~/l mm~t 360.05 SaE,~ 48 1.00 2.02 . ~ 12200 344.04 10,68_ C~rb~aat, ..... 0 -- 2.06 S~t, 1815 29.77 -- Hrd,~,,~a, - -- Tot~ ~ .... 374.81 T-~ Ca~ .... 374.81 74 a~meh~ ~ ~ ..... 21737- NaCl ,~~ ~1 ....... 21323 O~ pH . . .... 6.2 0.34 eam.~ 0.33 ~~ WATER ANALYSIS PATTERN above described · MEQ p,r Unit Cl 20 Na HCO~ 2 Ca SO~ 2 Mg CO · 2 Fe Cl HCO$ S04 CO, CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. Anchorage, Alaska 99509 274-3364 5633 B Street WATER ANALYSIS REPORT OPZ~ATO]~ Sohio Alaska-Petroleum f~_an¥ D&TE January_ 5, 1981 LA~ NO. 6015-10 W~LL NO- 18-11-12 LOCATION l*reLD - North Slope FORMATION COUNT~ INTleRVA~- ~TAT~ Alaska SAMPL~ FRO~__ Drill Collars Sample No. 11, 12-16-80 ~ ...... 7962 346.33 ~ 82 2.10 Calga~ ...... 210 10.48 ~ ..... 26 2 . 14 T~ ~a~ 361.05 , , _. ?~ ~ ~ m~/l ..... 20934 Ol~,,,~ pH - -- - -. ...... 8~h~, 53 ~ 11700 C~r~=~, ..... 0 B~r~t, 1830 H~/rosta, ..... - ?otm Ank~ 8pet:tile ~ 0 6~'*]f.: 20516 6.2 mq/l 1.10 329.94 30.01 w_ 361.05 _ 0.33 o~.~ 0.33 ~ M~ WAT~ ANALYSIS PATTERN Samplo fdx.,, descn~' MEQ l~r Unit CI 20 Na HCOs 2 Cs ___ S04 2 · Mg COs 2 Fe Cl HCO$ $04 CO. CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. o . o c 274-3364 5633 B Street Anchorage, Alaska 99509 WATER ANALYSIS REPORT OPEHATOR. Sohio Alaska Petroleum ~v DAT~ January_ 5 198] LAB NO. 6015-11 WF~L NO. 18:-11-12 LOCATION .... FIELD North SloDe FORMATION -- -- COUNT"F. INTERVA?- ~TAT~ Alaska ~AMPLE FRO~[ Drill Oollars . CONCLUSIONS:., SanlDle No.. !2, 12-16-80 ~ . . R686 ~ S,~at, 47 0.98 Pee~dam ..... R6 ~,20~ ~ 12300 _ 346.86 Caki,m ...... 212 10.58 ~ ..... 0 -- ~ ..... 25 2.06 BEarbaaat, ..... 1830 . 30.01 ~ . . , .... - -- H~~ ..... - -- 377.85 Teml ~ ~ m~l ..... 22257-: XaCI ~ m~'! - ...... 21842 ~ pH ...... 6.2 0.34 0.32 WATER ANALYSIS PATTERN ~mpl, ahoy, describ~ MEQ per [~ult C! 20 Nm HCOs 2 Ca SO4 2 Mg CO, 2 Fe Cl HCOs CO, per b CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. Anchor.-ge, Alaska 99509 274-3364 5633 B Street WATER ANALYSIS REPORT · . OPERATOI~ Sohio Alaska Petroletm~ ..(~y DATIt January 5e 1981 _ LAB NO. 6015-12 ~FELL lqO. 18-11-12 LOCATION - Fr~%r~ North Slope FORMATION COUNTY. INTERVAL ,. . STATR Alaska. SAMPLE FROM__ Drill Collars ~ & CONCLUSIONS: Sample No. 1 CIW, 12-16-80 CMtom m~/t moq/l Sodlmn . . 8111 352.84 Po~msdmn 98 2.51 Cak:lnm ...... 180 8.98 Mqmsdum ..... 28 2.30 366.63 __ Total dboolvod sends, mgll 21269 · NSC1 oquivabmt, mr/1 . . . 20855 Ob, eyed ~H 6.2 Suth~, 50 ChlarMo 11900 Blctrbeaa~ ..... 1830 sl~ac ~ 0 ~'x.: Oboervo6 0.33 ~ .... 0.33 1.04 335.58 _ 30.01 __ 366.63 _ WAT~ ANALYSIS PATTERN Scale Sample above descn~ MKQ Imf U~tt M~ Cl 20 Na HCO. 2 C~ S04 2 Mg COo 2 Fe Cl HCO, SO~ COo MOTE: lr~l=~f~r,~, p.r I~r M,q;l---- Bflnt~,,m ~ p.r b CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. Anchor~--~je, Alaska 99509 274-3364 5633 B Street WATER ANALYSIS I~PORT OI~ATO~ Sohio Alaska Petroleum Cbmpany DAT~January 5, 1981 . ZA~ NO. 6035-13 _ ~ NO 18-11-12 LOCATION ...... - ~ North Slope FOKNAT~ON COUNTT~, XNTERVA?- ~TAT~. Alaska ~A~P~ FaOm__. Drill 0ollars ~ & CONCLUSIOI~: S.ample No. 2 CIW, 12-16-80 ~ ..... 100 C~k~= ...... 210 ~ ..... 29 8261 359.37 2.56 10.48 2.38_ ---- ~ ~ .... 37.4.79. 21741 21333 ........... 6.2 ~ 47 0.98 Ck~4~ ...... 12200 344.04 ~ ..... 0 -- Bk~rbm~t. ..... 1815 29.77 T~ Ank.m .... 374.79 __ _ Ob~,~ 0.33 ~ Ct~fl~,d .... 0,32 ~ Na Mg above des~r~d MEQ pe~ lJatt CI 20 Na HCO, 2 C~ SO~ 2 Mg COs 2 Fe CI HCO, k,m, um ddm4de ~=b,j, Dwitp ,tit CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC.' Anchorage, Alaska 99509 274-3364 5633 B Street WATER ANALYSIS REPORT OFg~ATO~ Sohio Alaska Petr. oleu~. Cc~an_v ~A'r~ January_ 5_~ 198] _ ZA~ MO. 46.015-14 ~ M_t~ 18-11-12 X,OCAT/ON ~;~ North Slope FOV, MATION ~rA~ . Alaska SAM~ FROM Drill 0ollars ~ · CONCLUSIOI~'~ Sample No. 4 C'IW, 12-16-80 ~ ...... 8032 349.40 ~, . . 51 1.06 l~mmabma ..... 80 2.05 ~ 11800 332.76 Caktmm ........ 215 . ..~0.7~ Carboem, 0 -- ~ 26 . 2.14. lfl~ar~mma 1860 30.50_ , Trna1 Catkam 364.32 Xoe~ ~ ~ rog/1 ..... 21120 ~aCl ~ mg/l ........ 20695 O~,r,~ ~ -* ......... 6.2 ?o~ Amkm~ .... 364.32__ : Ob,er,~ 0.34 ~ ~ .... 0.33 ~ Mg WATER .U~ALYSI~ PATTERN 8ample atmve deecnTbe~ MEQ p.r Unit CI 20 Na HCOs 2 Ca SO4 2 Mg CO, 2 Pe CI HCOs SO4 COs CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. Anchorc~je, Alaska 99509 274-3364 5633 B Street OPEP~TO~ WELL lqO lrl~V-w,. COUNTT rrAT~ WATER ANALYSIS REPORT Sohio Alaska Petroleum ~.y DATe Januarv 5, 1981 18-11-12 lOCATION North Slope i~OHMATiON llqTERVA?- Alaska SAMPLE I~ROM.... NO, Drill Ooll'ars 6015-15 IEMARE~ & CONCLUSlOIq~: Sample No. 5 CTW, 12-16-80 Sodkun . . 8013 348.58 Sure, Po~ddnm 93 2.38 229 11.43 Mxfnsdam ..... 30 2 . 47 ToUl Cations 364.86 , ~ d~olv,d ~ m~l ..... 21149 N~I ~ ~Jl 20720 Ob,eryc6 ~i,1t 6.2 11800 0 1890 ?o~ Ankxm 0.34 0.33 msq~l 1.10 332.76 __ 31.00 __ 364.86~ -- N~ Mg Fe WATER ANALYSIS PATTERN Sample above de.'n-bed MEQ par Unit Cl 20 Na -- HCO= 2 C~ sO, 2 Mg COs 2 Fe Cl HCO, SO4 CO, CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. Anchorc~je, Alaska 99509 274-3364 5633 B Street WATER ANALYSIS REPORT OFg~ATOR Sohio Alaska Petroleum fkmTFpanv D&Tm January 5. 1981 EA~ MO- 60]5-]6 ~ MO 18-11-12 ~.OCAT~ON lrr~.~ ,__n ', .... ~h Slo~ ~O~~ON__ CO~ ~~~- ~ & CONCLUSIOI~: · Sample No. 6 C'I~, 12-16-80 ~ ...... 8030 349.29 -~t~ 47 0.98 ~ ..... 82 2.10 CMock~ 11800 332.76 Catcbmm ...... 213 10.63 ~ - -- ]gmam~l~m 27 2.22 ~ 1860 ' 30.50 364.24 -- Toe] ~ ~ ~ ..... 21115 MaCl ~ ,,~/1 20695 . ~~!~ 6.1 1'o~ Aaim,s .... 3,64,.. 24~ · 0.33 0.33 . NFAT~.~ AN'ALYSX~ PATTERN Scale ~ am~e Sescrmed U~ pe~ u~t Cl 20 Na HCO* 2 ~a S04 2 Mg CO. 2 Fe C! HCO, SO~ COs CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. Anchor.~ge, Alaska 99509 274-3364 5633 B Street WATER ANALYSIS REPORT OpF~RAToRSOhio Alaska Petroleum ~anv_ DATe January_ 5, .1981 LAm NO. 60]5-]7_ WZLL l~O 18-11-12 LOCATION ...... -- FIELD North Slope FOP. WATION COUNT~ INTERVAL - STAT~ _h,.]_~.~]~ 8AMPLN, FROM_ Drill Collars _ REMAR.~S & CONCLU8IOI~8: , Sample No. 7 ~IW~ 12-16-80 827.3 359.89 Su~st, ...... 47 0.9 8_ 95 2.43 C~xMe . 12200 _ 344.04_ 215 10.73 Ca~bona~ ..... 0 -- 30 2.47 Bkmrbonat, ..... 1860 30.50 - - Hraro~ .... - --- ~ Ca6ona .... 375 . 52 ?O~ Annas .... 375.52 _ Tma~ ~ sea~ ,n~/l ..... 21776 NaCl ,~nbab,~ m[/l 21358 Oh~,~d pH .... 6.1 0.34 0.32 M~ WATER ANALYSIS PATTERN above de~cn**D~d MEQ l~r U~dt __ CI 20 Na -- HCO, 2 Ca S04 2 Mg COs 2 Fe Cl HCO, S04 · COs Core SOHIO PETROLEUM COMPANY . CHEVRON TRACK WELL (23-18-11-12) CORE DATA · Interval Cut (Drillers Depth) Recovery (%) . General Lithology Porosity, Hydrocarbon Indications 8 10 11 14 15 9805-9864 95.5% 9864-9923 ',100 % 9924-9984 100.% 9984-10043 10043-10103.5 10103-10163 10163-10223 10223-10282 10282-10340.5 10340.5-10400 10400-10460 10460-10468 10468-10528 10528-10588 10588-10647 100 % 100.% 100 % 100 % 100 % 100 % 100 % 100 % 100 % '94 % 100 % Shale/Sst/Lmst Fair Lmst Nil Lmst Lmst/Sst Sst Nil Nil/Good Good Sst Good Sst Sst/Congl. Sst/Congl. Sst/Congl. Sst/Congl. Sst/Siltst Sst/Siltst Sst/Siltst~ Sst/Congl. Good Good/Fair Good/Fair Good/Fair Good Fair Fair Fair Good Oil Faze Mud, Masked Hydrocarbons E i V E D Alaelm oil & P.O.' BOX , PALMER, ALASKA 9964~ PHONi~ Mr. Brian Rose Sohio Alaska Petroleum Company Pouch 6-612 Amchorage. AX ~9502 , N=¢ember 14, 1980 · .o o, Magnetic Single Shot Survey Job No. ~1180-018 Well :Chevron Tract (18-11-12) Prudhoe Bay' Fiel~ North Slope, AlAska Date of Survey~ Oc~ 18, 1980 to Nov. 10, 1980 Dear Mr. Roses Please find enclos~i the "Original" and six (6) copies of our Magnetic Single,shot Survey on the above well. The metho~ use~ in calculating ~his survey was radius of curvature. ~he depth' interval of the '-survey was 2700 to 9661. ? T, hank you for giving us this opportunity to be of service. Yours very truly, RECEIVED JAN30 1661 AJ#ka 011 &'Ga ns, - ) , ]NPLETION REPORT 3HIO ALASKA PETROLEUM AGNETIC SINGLE SHOT SURVEY ADIUS OF CURVATURE METHOD OF COMPUTATION DMPUTED"FOR CDC BY' FM-EIND'SEYT&"'-'ASSOC. 13 NOV 80 CHEVRON TRACT K B ELEV 7:3.00 wELL 23'18;'11-12 .................................................................. RECORD-OF ALL CALCULATIONS PERFORMED BY SURVEY B M ELECTRONIC COMPUTER EA'S';"-DRI'FT--~/ERY I'C'AL .............. SUB .......... D-~-IF~ ........... ¥6TA'L-CoO~R'Dit~ATE$ ..................... c L' '-0' S""O-'-~ .... E-'-'s ............ 5EVERI TY SECT I ON EPTH ANGLE DEPTH SEA, DIREC DISTANCE ANGLE DEG/IOOFT DISTANCE. 0 0 0 0,00 -73,00 srS'L~E D--V-E R-T' IC'A'L:--TO--2- 76'b . N O,OOE 0.00 $ 0,00 W 0.00 S 0 0 0 W 0.000 0,00 2700 0 O 2700.00 2627.00 N 0 . 00E 0 J 00 ~VO0 .... O---O----2VO0;O0 .... ~'2V-,-'Ob---~-~TO-O-~--- -'~';~O'.A ....... ~'OP-~ ~0;66 '~' 'b' 0 0 ~ 0.000 ..................... O.o. OO.._.._OO 2773 1 0 2772.99 2699.99 N~O.OOW 0.58 N 0.21 W 2865 1 45 2864.96 2791.96 S35.00E 0.29 S , 1.35 W 2960 ..... 4--I-~--2959';-83"~2886'~,83 ..... ~28-JO'O'E 4.52 .... $ .............. ~'23'E 3055 ? 30' 3054,31 2981,31 S27.00E 13,15 S 5.72 E 3117 9 45 3115.61 3042.61 523,00E 21.57 5 9,65 E ~263-I'3 30 ..... 3'258;'59 ......... 31'85.59 .....~i~VOOE~ .... 49;"~'2-'~S ......... ~"95 E 3~20 17 45 3409.75 3336.75- $18.00E 89.32 $ 83.01E 3577 20 30 3558.07 3485.07 S20.OOE 187.95 $ 49,76 E 0.62 N 19 59 59 W ~,370 -0.61 1.39 $ 77 51 0 w ........ Q.834 0...~o ........ '4,'~9 S"~1"~"1~ ..... 2~"E 2.632 4.65 14.34 S 23 ~1 ~3 E B,421 1~.81 23.63 '''53';0'1"S'"22 .... 6--~'E ........... Z.575 51.40 95.23 $ 20 17 '5 E 2.707 9~,0~ 146.65 $ 19 50 B E 1.759 14~.50 3892 29 30 3842.70 3769.70 S20.OOE 26~.65 S 96,75 E 280.84 S 20 9 8 4176 37 30 4079,26 4006.26 S20.OOE 410.92 S 150.35 E 437.56 S 20 5 52 4524 40 30 4349.68 4276.68 S20,OOE 616.69 S 225.25 E 656.54 $ 20 5000 41 0 4710.28 46~7,.28 .... ~l. 8_.,O.OE .... _9_!o.s~6T..$ ........ ~26,~.~0_._E .......... 967~20_~s 19 ~ ~67'~0'-~--"5064;-06 ....... ~991.06 818.50E 1199.97 S ~21.87 E 1271.96 S 19 2 5940 39 0 5427.71 5354.71 S18.00E 1487.20 S 516.58 E 1574.~6 S 19 6189 38 0 5622.58 5549.58 S18.00E 1634.62 S 564.48 E 1729.34 S 19 6687 34 .... 30--6024.13 5951.'1'3 $1'6"00E ......i~-i'6~16"-S ........ 650;56 E ..... 2023"59 'S 18'4 6910 34 15 6208.18 6135.18 S14,00E 2037,77 S 683.14 E 21~9.23 $ 18 3 E E E E E E E E E E 3' 167 ................. 2oa.-7~ .... 2,552 274.48 2,778 427.7~ 3 54 0.862 6~1.88 3 22 0.209 946.80 2 12 0.116 12~6,71 9 17 0.320 15~.26 3 4 0.402 1696.8~ 5'10 0,715 1987'61 ...... 1 59 0.305 2112,56 DHIO TRACT WELL SINGLE SHOT SURVEY 13 NOV 80 : RECORD Of SURVEY AL k ....CAI.C .U I...A..I I. O.N ~...P.E..Bf 0.~ Mg.D___~Y ...... I_..B..~ _M .. [ I. [..C..T.B 0 N. I C :. C O M P..U.. T : , . TRUE DOG LEG EAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L 0 S U R E S SEVERITY sEcTION EPTH ANGLE DEPTH SEA DIRE¢ DI STANCE ANGLE DEG/iOOFT DISTANCE .......... 'i ...... 6 .... ~t- .................... : DEG, -- D M $ 7171 35 0 6422,95 6349,95 5 711,43 7393 35 ~5 6603,97 6530,97 S 1,50E 2311,29 S 722,06 ..... E 7639 37 0 6802,03 6729,03 5 2*OOW 2457,16 5 721,43 E 2560,88 S 16 21 ~4 E 0,724 2533,2~ 8050 42 0 7119,07 7046,07 S 6,50W 2717,72 S 702,06 E 2806,94 S 14 29 4 E 1.312 2788,6~ ~"5'~'~"'"'-"~'~--"~ ......... 7'~"7"0';' 5"7'~ ...... 7 ~ 7'"*'57---S-'~'~0'~'~--~'0' 3"i'~-30""'$ ............ 659";"39 ..... Bg95 ~0 X5 '7826,11 7753,11 &lOeOOW 3337,~7 $ 608,15 E 3392,~2 S ~0 19 37 E 0,381 ~389,~6 9534 38 45 8242,00 8169,00 SI~,OOW : 2673,38 $ ." 539,81 E 37~2,83 S 8 21 35 E 0,3~ 3712,73 9661 ~8 30 8341,22 8268,22 S15,0-0~3"7'5-0-;-'~'0-'S:~ 520-;~63'-E' '3786;"2'6"S- 7 5'4 ....1'2 .... E ............ 0;64'1.................. 3786";'2"67 DTTOM HOLE CLOSURE 3786.26 FEET AT S 7 54 12 E I SOHIO TRACT WELL SINGLE SHOT SURVEY ~-~ASuR£6' DEPTH AND OTHER DA~'--'~'~'--"~V'~-~--Eg'EN'-' %00 FEET OF SUB-SEA DEPTH, ].~ NOV ~0 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL 273 473 .573 673 773 873 973 1073 1173 273. 200 0 0 0,00 S 0.00 W 373, 300 0 0 0.00 S 0.00 ~ 473. 400 0 0 0,00 S 0.00 N 57 3' ............ -5C~5 ........... 0 ...................... '0 ................................................... 0 ;'0'0-'-~ ...................... 0','0 O' ~ 673. 600 .0 773. 70O 0 873, 800 0 97~. 900 0 1073. 1000 0 1173, 1100 0 0 0,00 5 0,00 W 0 0.00 5 0.00 W o ....................................... 0';'06-~ ..................... 0 O,OO S 0,00 W 0 0,00 S 0,00 W ......................................0 0' ;-0'0'-~ ..................... 0 ;"0'0-'~ ~ 1273 1373 '1-~"7'3 1573 1673 1.-773 1873 1273. 1200 0 1373- 1300 0 i~'73~ ..... i'~OU 0 1573, 1500 0 1673. 1600 0 1773; ...... I7'00 O' -- 1873. 1800 0 0 O,00 S 0,O0 W 0 0,00 S 0,00 W 0 .............................................. O'JO"O'-$ ................... 0 ,'00-' W 0 0,00 5 0,00 W 0 0,00 5 0,00 0 O",U'U'-$ ............... 0', 0'0 ..... W ..................... ::- 0 0,00 5 0,00 W 1973 2073 2173 2273 2373 2473 2573 1973, 1900 0 0 0,00 5 0.00 W '~ 2073. 2000 0 ................ 0 6';"00--~ ...................... 6';'"00 "-~ , 2173, 2100 0 0 0,00 5 0,00 W 2273, 2200 0 0 0,00 S 0,00 W 23 73; ........ 23'C~'0- ........ 6 ............................. 0 6; 0'0'-5 O, O0 ~ 2473, 2400 0 0 O,OO '5 0,00 W 2573, 2500 0 0 0.00 5 0,00 W ........ 2673 .................... 2773 2773, 2700 0 0 0,58 N ' 0,21 W 2873 2873, 2800 0 0 0,50 $ ].,21 W .... 29'73 ......................... 2973, ...... 290-0 .............. O- -0 .......................................... 5,Z~2'"5 1,71 E 3074 3073. 3175 3173, 3278 3273, 3381 3373, 3487 3473. ' .....3593 ..... 3573. " 3000 0 0 15,45 5 6.86 E 3100 2 2 31,37 S 13,61 E 3200 .........4 2 52;~6""-~ 21.03 E 3300 8' 4 78,36 $ 29,45 E 3400 13 5 109,21 5 39.64 E 3500 ....... 1'9 6 .... 143.28'5 ' 51.70 E 501'ti[0 TRACT WELL SINGLE SHOT SURVEY 13 NOV 80 ;~-E'A'SURElj- DEPTH AND OTHER'DATA-'~FOR'-'E~ERY-'E'~EN iO0-FE'ET-OF SUB sEA-DEPT~i', ................... TRUE MEASURED VERTICAL SUB MD-TVD VERT!CAL .............. pE_~_.T_H_ ............................ .D,, E_~!~ ........ _~_EA__I:)_Z_F..~,E_R_E...N.__c.£~ ................... ~ORR E C.T.~,ON ........ TOT A .L ..... ~..O,,.O.R.D.I N~'_? E. 5 3701 3673. 3600 28 9 182.38 S 66.27 3813 3773. 3700 39 11 228.30 5 83,70 3927 3873. 3800 53 14 280,10 5 102,74 4045 3973. 3900 72 19 339.14 S 124.23 · ~ .... ~'i~-8-- ..................... 407 3; ......... ~00-~ 95-- 2 3 ...................................... 40'~";'3 6-$ .............. ~'~ 4295 4173, 4100 122 27 479,78 $ 175,42 4424 4273. 4200 151 29 556.11 5 203.20 455 5 ............................ ~"3'7 3' ;-': ........ ~ ~"0-0 ......... ~'8 ~i ........................ ~'0 ...................................... 6 35; 4 ~ -'"S ............. ~' ~2"; 4686 4473, 4400 213 32 715,94 S 260.70 4818 4573, 4500 245 32 797.38 S 288.81 4950 4673, 4600 277 32 879.31S 316.20 5083 4773. 4700 310 33 962.23 S 343.22 5215 4873. 4800 342 32 1044.44 5 369.93 53 ~'7 ........................... ~ 9 ? 3 , ....... ~9 bb'~7 ~ ........................ 3'2 .......................................... 11'2'~' ' Z ~'-~ .......... 5'9 ~ ';' 5479 5073, 5000 406 32 1207,22 S 424.22 5610 5173. 5100 437 31 1287.75 S 450.39 57~0 5273" ......... 520'0--'4~'7 ................................. 30 ..................................... 1367.'10'-5 ........ 5869 5~73. 5300 496 29 1445.30 5 501,58 5998 5~73. 5400 525 29 1521e93 $ 527e87 6'~2 ~ ................... 5'573; ...... 5500-- -55'~ .................................... ~ e ................................... i 59 7, 60'-~ ............ 5'52 625~ 5673. 5600 580 27 1671.80 $ 576,47 6378 5773. 5700 605 25 1743,98 $ 599,23 ............... 6502 .................. 5'8'73; ...... ~0'~ ~'9 ........... Z'~ ............................... r~i.~,O 8--S ....... ~'0'~4 6625 5973. 5900 652 23 ~882,14 5 640,76 6746 6073, 6000 673 21 1948.30 S 659.61 ......... 6867 ...................... 6-173, ........ 6100 694 ............. Z~i ................................. 24 l~,"~O'-'g ........ 6988 6273, 6200 715 21 2080,65 $ 69-3,12 7110 6373.' 6300 737 22 2148.78 S 706.13 ........... 72~ 2 ................... %~73"; .... ~00 -- ~59 ................... --2-~ ................... 22 i8'~'09"'~ ......... 7355 6573. 6500 781 22 2289.17 5 720,88 7478 6673. 6600 805 24 2361.21 5 722.48 ........... 7603 .................. 6773; ...... 6700 ........ 829 ......................... 24 ................. 2435'37-'-5 ........ 721'.46"E 77~9 6873, 6800 856 27 2511,67 S 719,10 7857 6973, 6900 884 28 2592,17 $ 714,17 ........ 7'98'8 ............ 7073~ ........ 7000 ....... 915 .................... 3'[ ............................. 2677~'13-"$ ......... OHIO TRACT WELL SINGLE SHOT SURVEY 13 NOV 80 [A.S.u~ED_~DEPTH AND OTHER DAT6....E.O..~._,,_[_V.E_RY, EVEN IO0_.FEET .OF 5U~ ,SI.A_ D[PTH.. MEASURED DEPTH TRUE VERTI£AL SUB MD-TVD VERTICAL DEPTH SEA DIFFERENCE CORRECTXON TOTAL COORD XNATES 8122 7173. 7100 949 34 2765,61 $ 696.84 £ ' 8257 7273. 7200 984 35 2855,29 $ 686,01 E 8392 ........................ 7373, ......... 7300 ...... 1'01'9 ............................. 35 ....................... 2944,60""'~ .............. 673'~87 ....... E 8526 7473. 7400 1053 34 3033.28 $ 659.07 E 8660 7573. 7500 1087 34 3121.54 5 644.86 E 8'?~"3 ........................ 76'73, .......... 76~0'0--'1'"f'20 ................................... 33 .................................. 3208,0'4-'$ ........... 63~';~9'~E .~'-- 8925 7773, 7700 1152 32 3292,98 S 615,95 E 9056 7873. 7800 '1~83 31 3376,42 S 601,17 E 93X6 8073, 8000 1243 29 3539,48 ~ 569,29 E 9445 8173. 8100 1272 29 3619.14 ~ 552.12 E ~OHI,O TRACT WELL SINGLE SHOT SURVEY L NOV 8O INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, TRUE MEASURED VERT I CAL SUB DEPTH DEPTH ,SEA TOTAL COORD INATE5 1000 ]`000. 927. 0.00 S 0.00 2000 2000. ],927. 0,00 S 0.00 3000 2999. 2926. 7.57 S 2.8/+ 4000 3935. 3862. 315.97 S 115.79 5000 4710. 4637. 910.4(: S 326. ~,0 6000 5474. 5401. 1523.02 S 528.22 7000 6282. 6209. 2087.29 S 694.54 8000 7081. 7008. -2684.72 S 706.z+9 9000 7829. 7756. 33z~0.65 S 607.59 HORIZONTAL~ VIEW SOHIO ALASKA PETROLEUM CO. ,CHEVRON TRACT WELL (25-18-11-12) RADIUS OF CURVATURE - MAGNETIC SINGLE SHOTSURVEY SCALE I "'' I000' NOV. 1:5, 1980 ALL DEPTHS SHOWN ARE TVD. ~56o0 CD - 7200 O~ TVD 8~541' TM D 9661' Sperry-Sun, Inc. P. O. Box 6207 150 W. Dowling Anchoragej'AK 99502- Decdmber 9, . 1'980~ Mr. Gary Plisga Sohio Alaska Petroleum Company 3111C. Street Anchorage, Alaska 99503 Re: Our Boss Gyroscopic Survey · Job No. Boss-16716- .. Well-MPC Tract Well 23-18~11-12 Wildcat Field North Slope, Alaska Date of Survey: December 7, 1980 Operator: Tom McGuire Dear Mr. Plisga: Please find enclosed the "Original" and seventeen (17) copies of our Boss Gyroscopic Multishot Directional Survey on-the above well. Thank _you for giving us this opportunity to be of service. Yours~very truly, SPERRY-SUN, INC. Ken Broussard District Manager ~B/kc Enclosures ~OHIO ALASKA PETROLEUFi COMPANY IILDCAT kLASKA .......................... '. TRUE SUB-SEA qEA'SURE'D VE R'T IC'AI~ ..... VERT'ICA[ INCL DEPTH DEPTH DEPTH DE sPERRY-'SUN WELL SUk/EYING CO~¥~"~'Y ANCHORAGE~ ALASKA -'COhPUTATION' DATE' DEC 8, 1980 · " .&GE 1 FT, DATE OF SURVEY DEC 7'~ 1980 B' 0 S"$-'"6Y R 0 S C'O' ~' 1 C'-'~U~-VS?' ---~' JOB NUMBER BOSS-16716 KELLY BUSHING ELEV. : 73,00 COURSE COURSE I'NATION D'IRKCTEON G MIN DEGREES DOG-LEG SEVERITY DEG/iO0 OTAL .... R E C'T'AN G'U K NORTH/SOUTH EAST/WEST SECTION 1 O0 1'00. O0 27, O0 200 200,00 127,'00 ~00 400.00 327.00 500 500,00 z~27.00 .............. ~' ~~O'O-P. O'~ .................... 700 '700 ;00 627.00 800 -799'99 726,99 1000 999.99 926.99 1100 1099,99 1026,99 ......... I'20-0 ........ 1q"9'97.'99' ................. 1'1~6-, 9'9 1300 1299.99 1226,99 1¢+00 1399.99 1326,99 ................ I5'0'0 ............. 1'499'2"99~ 1 q26 · q9 1600 1599.99 1526.99 1700 1699,99 1626.99 ............ l 8'UU ....... I'79-~ ;99 .......... 17~6 · 99 1900 1899,98 1826,98 2000 1999,98 1926,98 ........ 2'I 50 ............ 2tF99';'98 .......... 20'2 G · 9 8 2200 2199,98 2126.98 2300 2299.97 2226,97 ........... 2 ~0'0 ............ 25~9";'9'5 ......... 2 32 6; 96 2500 2~99,96 2426,96 2600 2599-96 2526-96 ........... 270'0 ........... 2'59'9;'95 ...... 2626 ;'95 2800 2799,9~ 2726.9~' 2900 2899,87 2826,87 ............. 5 DUO" ........ 2-999-;-57 ........ 2 9'26 ' 5 7 0 .... O .......... N':-';'O;:'O' E 0 3 $ 9,10 K 0 12 S 62.69 E 0 6 ......S ........ ~';"2'9 ~ 0 6 S 56*60 E 0 6 S 26,89 W 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 5 3~ S-:..5~':39 E 17 S :1..1.7'9 W "1"6 ........ ' .... ~ ........ 3";'I'9 ..... 9 S 25.19E 7 N 65.20 18 N 16.29 E 7 N 30..70 W I9 ........ N'"62';1'0 15 N 51.29 W 9 N 61,60 W 'l'O ............... ~ ..... 5~",~0 f 10 S 53.10 ~ 15 S 21.69 E 22 ..... S ~6;"60 W '36 S 73,39 W ~5 S 70.29 W 30 .......... S"'7q'-;IO 26 N 76,70 W 3q N 12,10 ~ 28 .......... N '"~'~'60''W 12 S 53.19 E ~3 S 38. 0 E 56 ........ S .... 29.80 E O";'O'O ---~;~ :{Y;O.O .... · 06 ..05 S ~!.OI.E .05 · 17 '. 18 S ~. 1:7!:.:':...:E · 2 0 · 07- .55 S .37 E .55 · 11 .68 S .i38 E .71 .................. ;~i-0 ,96 · 5q -.: 1,~5 · 53 2.02 · 15 2.79 S 1,01 E W .27 2.87 S .9l E · W ................. --,' O ~' - --~'--'~%-7'~--~' · 29 2.~8 S · 2~ 2-1'~ S - . .8 · -2~ ...................... 1";9'2'"~ ............... JSI--K .o9 1.6. s .o~ E · ii 1.~3 s .22 W · 29 1'63 S .20 W ,27 1.9~ S ." ,25 W · 33 2,7~ S lJl~ W · 15 3,12 S 2,28 W .... ~25 ............. ---~';-4'T-~ ~-;55'~W · 25 3.50 S ~13 W - .56 2.92 s ,~.6~ w. 2.86 2.93 '2-; 83 ........ 2.5~, 2,20 1.6q 1,~1 1.'43 " 1.61 1,91 'L~33 2,65 ;5,2'0 ...... 3.17 2,56 1,57 2.22 S 1.59 ~.73 S ....... 3;2T ..... ::? ...... 3-9~ W 1.91 1,63 W ~-59 OHIO ALASKA 'PETROLEUM COMPANY ~EI/R'DI~r-T1T'A'CT""I~ISL1Z'" '"23 - 1'8 - I I-I2 iILDCAT ,LASKA ANCHORAGE, ALASKA ~ DATE OF SURVEY DEC 7, 1980 .......... 'CO M P U T A T'I O'N "D A T E ............................... B'O:S~-GT~FOSC'OP IU'--SUR'VE~ ................. L__.. DEC 8, 1980 JOB NUMBER B0SS-16716 KELLY BUSHING ELEV. = 73.00 FT. O'P ER ~F1'O R';;M CG'UIR E TRUE IEA'SURED .......... ~ERTI'C"~L ..... )EPTH DEPTH SUB-SEA COURSE COURSE V'ERTIC'AL ..... INCLINATION" 'DIRECTION DEPTH DEG MIN DEGREES DOG-LEG TOTAL SEVERI'T¥ ......RECTA'NGU['A'R ..... COORDI'N'ATL~-VERTICA~ ............ DEG/iO0 NORTH/SOUTH EAST/WEST SECTION ...... 31970- ......... 3'O'gFZG'3 ........... $025';'53 ..................... 9 ........ ~'[~ ......... S"25,6'0-E 3200 3196.7~ 3123.7q 12 33 S 20,80 E 3300 3293.85 3220,85 1~- 55 S 21,19 E .......... 3"~'00 .............. ~'~99~;-~0 .......... 33'17;0'0 ................. 1'6 ...... 56 ..... S ..... 20;$9 E' 3500 3~85.0~ 3412.0~ 19 13 S 19.80 E 3600 3578.72 3505,72 21 39 S 20.89 E 3800 3761.22 3688,.22 26 3900 38~9.30 5776.30 29 ~'0.97 S -2'.'36 6.3,1q S 2.30 . ll?.9q S 2.~6 150.68' S '-~ ............ ~""'20;'89T"~ ......................... i~':.'~3'~ .............. 38 S 20,30' E 2;61 227-01 S 52 S 20.69 E. .5,2~ 271.3~ S 3~-.~'"~ ......... --g i. i b ~+5. O~ E 121.03 57.21 E ' 154,60 ~I'~67~ E~:~' ..........I gi" 8 I · -102-6~ E;' 278.37 4100 q018.39 39~5.39 3~+ q200 4098.86 4025.8~ 37 ......... ~'3'00 .................. ~7'~'~ ......... ~ I '03 ;'6'~ ............... 3 g ~00 ~253.~0 q500 ~330.17 ....... 4600 ........... 4-~';~ " ~700 ~83.51 qBO0 ~559.56 ......... {900 ............ 4-6'3-§-"3'4" 5000 ~711.3~ 5100 ~787.36 ......... ~RO0 ......... ~'H63'2'~7 ..... 5300 ~939.8~ 5~00 5016.29 ............ 5'5~ ......... 5~c]2-;'8~ .......... 5600 5169.59 5700 52~6,67 5900 5~01.93 6000 5~80.18 ........ ~00 ............ 5'5582~'~ ....... 4180.40 39 ~257.17 39 ~'333.92 .... 39 qqlO.51 ~0 qq86.56 ~0 456'2.34' 40 Q638.3q ~0 q71q.36 qO 4790.q7 "' qO qSGG.Sq 40 qgq3,29 ~0 5019.8'~ ....... 39" 5096.59 39 5173.67 39 5251.11 5328.9-3 38 5407.18 38 '5485.8~ 37 6 S 53 S 55 S 53 S 51 S 50 S 5~ S 8 S 50 S 36 'S 28 S 33 S 19 S 5 S 10 S 55 ........ S ~8 S 19 S I'D ...... S' 36 S 2~ S 50 ....... S 2 O; ....... 0'"'~ ............... : .... 2";'27 ..................... 319-;'6I ........ $ ..... 20.10 E. 2.78 371.45 S 139.50 E 381.00 19.80 E 3.05 /+27.2q S 159.75 E 438,16 1 S. 80 ...... E ........ ~ ......... 2';'0"6- ..................... '~'B 6' ;'5'1-'S 19,19 E ,26 547.13 S 201.36 E ' 560,88 18.60 E ',38 607.76 S 222.12"E 622.90 19',1'0'" E ............. ;'35 ................. ~68'; 4'2' S ............. 2"~2';-B3'-E-"~'B'8'zFe-gT ......... 18.50 E ,~5 729.30 S 263.55 E 19.19 E .83 790.74 S 28~.53 E · 18. 0 E .92 913.88 S 326.94 E 18.60 E ,40 975.56 S '347,33 E l'8,1'O''E .............. ;~'0 ............... 10"3'7'4'1'2"S E .50 1098.36 S 388.19 E E .10 1159.~0 S q08.91 E 'E ......... ;'2'~ ................ I~'20'~'3'5-~'~---~9,Sq'-E 7~7.25 810.11 873,15 997.17 112q,73 li87.17 iZ~9.5T 131i.5~ 1373.16 iq~4'z2 149~o80 1555,12 1615e0~-' 18.80 18.69 18;69 19.30 E .qO 1280'96 S ~50.41 E 18,80 E ,58 1341,17 S 471,~0 20';30'E ............ 2~6 ........... ~'~'O~,-B'~-'S 18.89 E 1.05 1~59.9q S 513.qq E 18.50 E .32 1518.92 $ 533.~0 E lB', 19 E .... ~59 ....... 1577';52-S .... ----552'28~ .... E · · ANCHORAGE, ALASKA SOHIO ALASKA PETROLEUM COMPANY D~ATE 'OF SURVEY DE'C'~7', ;'REVRO'N'"TR'~'CT-'~gE['[:-'' 23'18" Il ;; 1'2 ......................... COM PU'T';~ TI:ON DA T E ................................................. B'i~S'S ........ P-:;~ R'~'S'C:O'F]:~-S-U-A-9-E:7 ,tlLD. CAT DEC 8~-1980 ,.lOB NUMBER BOSS-16716 ~LASKA KELLY BUSHING ELEV. = -% :tgBO 73,00 FT.r TRUE SUB-SEA 4E"A'SURED .......... VERTT~A'K ............VERTICAL DEPTH DEPTH DEPTH COURSE COURSE 'I'NCLINATI'O'N ....... DIRECTION' DEG MIN DEGREES DOG-LEG ' }:.:::':i..:::: T.OTAL:" S E ¥ E P, IT Y .... :"'R ET T"'A~fG~ K'A'~---C O~'T~D~,~TATE'-S::: ...... V ~RTI~'A'L- ........ DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 6300 57.17,61 56~.61 6~00 5797*75 572~,75 ............. 650"0 .......... ~"~F;'52 ............. 5~0'5;52 6600 5959.89 5886,89 6700 60~2,15 5969.15 ...... ~'~ ....... -U-~T~S;-O'~ ...... :'"'::'~'~'~2,0~ ...... 6900 6207,96 613e,96 7000 6290,32 6217,32 .......... 7I"00 .......... ~'37~";'3'1 "'6299";'31 '~' 7200 6~5~,36 6581.36 7300 6536,15 6~63.15 ................... 7~'0-0- ........ 6~I7';"61 ...... 65~','61 ...... 35 7500 6698.76 6625.76 35 7600 6779.~1 6706.~1 36 ............ 770U-- ........... 685~;~'2' 6786.~'2 37' 7800 6938o~8 6865.~R 38 7900 7016.29 6943,29 39 ....... '8'-0'0'0 ........ --70'~225"8 ............ 7019.58" ~l 8100 7167,0~ 709~.0~ ~2 8200 72~0.29 7167,29 ~3 ........... 850'0'~ .....7~]3;'57 ......... 72~0,57 42 8~00 7~87.21 731~.2! ~2 8500 7~61,31 7388,31 ~1 ........ 8~OU ............ 7~5;"05 7~63.05 '' ~1 8700 7611,37 7538.37 ~'0 8800 7687,19 761~,19 ~0 ............. 89'0'0 ......... 7-f-65;'~'5 .... 7690.~5' " ~0 9000 78~0.30 7767.30 39 9100 7917.77 78~.77 38 ...... 92'00 ......... -7'9'95';'65 ........ 7922,65 38 37 7 .-S 18'"30 E 36 19 S 18.89 E 35 ....5'5 ................ S""iS;'8'O'E .... , ......... 35 9 S 1~-50 E ,80 3~ 9 $ 17.19 E 1,2~ 3'3-:'":~':~'::~':'i~ji 9?cE .................. ;'~'3 : . 3~ 5- S 1~:"60 E ,93 35 O. S.-'-11'6'0 E 1,92 1~ 3'12:'S:: 1733,i7 17.~9,' 609,75~ E 1~ 1860.67 S 6q7.39 E 190~.56 191~.78 S 66~,82 E 1959.85 202:2 2 07 3~ 52 S 7,30 E 1,71 2190,1~ 35 22 S ~,69 E 1,58 22~7.35 S 728.19 E 2239.23 S 73~.19 E 2296.72 ':-5I .......... T''S',':'"~39 .... E ............... 1;92 ....... 2'3'~5-~-~5 .... . ....... ;-'737-~27':.E..: ...... 2~5~.68 ......... 59 S 0;39 W 1,15 2363,66 S ' 757,78'"E 30 S 1.10 ~ .66 2~22'78 S 737.00 E. 'I3 ................... S ....2;'29"W 1;02 ...... 2'~"8FJ7~--~-' ..... "7~2"E ....... : .... 16 S ~,89 W 1,~ 25~,86 S 731,90 E 32 S ~,60 W 1,3~ 2606,~9 S 727.23 K ....... O ........ $'"':~'5';50 .... W ........... i';56 .............. 2~'7'0'.-~8--S---'-~".-~-[ -'- 1.78 2737.27 S · 37 280~.97 S ..... ;'6'1 ........... · ~6 2939.78 S .6~ 3006.36 S ..... :;'7~ ........... · 62 3137.27 S 71~,79 E ., 707,67 E TiTO~27-E 692,1~ E 683,~9 E 664'98 E · ~1 32ol.88 s 656.P~ E ,87 3329.21 S 637.73 E ' 1.12 3391.~9 s 626.87 E 2~12,97 2~ 7~i.86 '15 3 I75'1'" ..... 2592.20 265~1.,30 2718.07 -----" 2783;75 2850,71 .298'3,9~ 30~9.68 311'q,5'7 $178.79 32~2.55 3305 ;7i~' 336'8.11 3~+29,37 ~+3 S 6.10 ~ S 5.89 ~1 .......... S ......... 646'0 28 S 7,19 53 S 7,60 22 ........... S ....8";'39 53 S 7' 79 :30 S 7~ 60 "6 ............ S ' B';I9 27 S 9.10 58 S 10,69 '44 ............. S 1'1"'3'9 ) ............................................... SPER RY=~DN"gEL-L S'L ANCHORAGE9 ALASKA SOHIO ALASKA PETROLEUM COMPANY DA.YE OF SURVEY DEC 7~ ~ ~EV~"O N'"T'RA CT-~EEL- 23'18-11~I2 ............... C OM'PDT ATI ON"~DATE ................................... NILDCAT ALASKA - .. TRUE ME A'SUR-ED-- ........ 'VEI~TTC'A'E-' DEPTH DEPTH DEC 8e 1980 SUB-SEA COURSE COURSE YERTICAL INCLINAT'ION ...... DIRECTION DEPTH DEG MIN DEGREES 1980 JOB NUMBER BOSS-16716 KELLY BUSHING ELEV. = 75.,00 FT, .................................... (TP'ER'~R'--RC'G~R!?<' ' F-! ' '. DOG'LEG TOTAL EVE R I'TY ........... R ECT KNGU L'AR"--CI~ZIRDIN A-r E~R'TTUA'Ii DEG/iO0 NORTH/SOUTH EAST/WEST SECTION ..... gTO"F-- ........ ~'D77;-~'~ ......... 8 0"0'0'; '6'6 ............ 58 ......... 4"~ ............. ~S'-I'"I';'2"9-'W ................... ;'07'--',$b'7'z[..--~.' ~0 s .......... 602 · ~' L ': .":-'-':'-':- ~5~0'; 08 .... 9400 815i.87 8078.87 38 22 S 11-89 W .51 :: "3575;{~ S 590.01 E 3609.98 9500 8250,2'1 8157.21 38 29 S 12.29 W .28. 36.36-22 S 576.98.E 366).59 ..... g'6"O'O' .......... '~U'B;"7B ....... 8255 ,'78 37 55 ................... S .... 1'3';'6'0' W ................... 2~8 .......... 3'69~2"4'9"-~ .......~'~;-I'2 . 9700 8387.92 8~1~.92 37 25 S [~.~9 ~ .62 3755.83 S 5~8.~ E 3786.68 9800 8~66,90 8393,90 38 l~ S 15, 0 W ,95 3815,i8 S 532,97 E lO000 8623.36 8550.36 38 16 S 15..60 ~ ,'57 ':' 3935.36 S 500,2~ E lOlO0 8701.74 8628.74 38 30 S..:;15.. 29 ~ '30:.',':. 3995.23 S 483.G6 E 10300 8856.77 8783,77 39 47 S 15,69 10400 8933,14 8860,14 40 37 S 16,50.W ..... I-O'5O~ ........ 10600 9083.09 9010,09 A2 5 S 17,69 10700 9156,84 9083,84 42 52 S 18...,10 ........ TO'BOO ......... 10845 9262,50 9189,50 · 59 ~116.98 S q49.90 E 4139.28 .98 4179,00 S q31.99 E A199,76 · 62 ~305.37 S 392-74:E'!;i:!:''' ~32~'77' · '83 .. ~369,65 S ;'5'5 ..... --'4~'5~;'~'~-'s-------~o~.6'~"E'''?'''~' ..... .92 4463,93 S 340,87 E '4476.92 ........... H O'R'TZONT-A~' ,,-'DTS P LA CEM E N'T "~ ..... A A 76 . 9 2 F E E T AT "SOU T H"~'i: ........ 4'-D E~ ......... 22',M I'N';-I?A~S'r--A'T-'PFD'~~ 8 q D · ~ · THE CALCULATION PROCEDURES ARE BASED ON THE USE. OF THREE DIMENSIONAL RADIUS OF ,~;URV'ATURE METHOD. .) ;OHIO ALASKA PETROLEUM COMPANY :HEVR'ON-'TRACT'"WIE'[[ ..... 23'18-11;12 4ILDCAT ~LASK~ ALASKA DATE OF SURVEY DEC 7* 1980 DA'TE JOB NUMBER BOSS-16716 KELLY BUSHING ELEV, = 75.00 FT. ....................... O.PERATOR,~CGU.~..E ANCHORAGE 9 COMPUTATI ON DEC 89 1980 INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASURED VERTICAL VERTICAL D'E'P~ ............'-TDE'PZT'F1 ........................ ,DE P TH' ;.. 0 0,-00 -75, O0 ............ I'0'0"0 ............. g~-g';'g'g .................. '9 26 ;'9 9 2000 1999.98 1926,98 3000 2999,57 2926.57 ............ 4'"0' 0'0 ............... $'cj3'5';~0'1; ............. 3'B-6":~',' 0 1 5000 ~+711.34 4638.34 6000 5480.18 5A07.18 8000 7092.58 7019.58 9000 78~0.30 7767.30 ...... I'0"~00 ...... BG23*3G 8'55'0.36 108~5 9262.50 9189.50 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL 0.00 0.00 0,00 ............ ~;Tg'"'g ......................... 1'.'01 .... ~ ......................... ;0I 1,94 S .25 W .02 .01 11.10 S 2.42 E 913.88 S $26.94 E 288.66 223.67 1518,92 S 533,~0 E 51.9'82 231,15 2077"46"'S .............. 708.57 E ........ 70'9;'6'~' i89";~'~ ........ 2670.88 S 721,5~ E -. ~07,~2 197,75 3329.21S 657.75 E 1159.70 252.28 ~A6~,93 S 340.87 E 1582.50 205.87 .... T'HE'"C~IL'CUL'ATIOI~'-'PR'OCEDURES ARE BASED ON THE "USE ...... OF'~"THREE-'"'D'IMENSION'A'I: .... R'~'DIU'S'-OF"'CUR'Vi~TURIZ--M~'TRo'D';---- .... '";-- ANCHORAGE, ALASKA .- ~,,-,,::: ' SOHIO ALASKA PETROLEUM COMPANY ~.ATE 'OF SURV ,..1980 ~ ~ILOCAT DEC 8~ .1980 dOB NUMBER BOSS-16)16 kLASKA KELLY BUSHING ELEV, = 73.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA OEP TRUE SUB-SEA TOTAL ~EASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ]EDTH ~ OEIDTH ............ NO 0.,- 0-00 -73.00 0.00 T3 .... ~"0'0 ............................... 0;' O0 ........................... · 0'2 '"~J 173.00 100.00 .lq S ,09 E 273.00 200.00 .3! S ,32 E 1'73 273 473 ~73',.00 400,'00 .625 S ~0 E 573 573,00 500.00 .84 S,,~.-~i .31 E ~;7~ 67~;'lIlI' .................. 6'O'll ';' 0'13 ............. 1' ';'2'4'-'S ............... ';"4'zl· 773 773.00 700.00 1.81 S l'w05 E 873 872,9.00 800.00 2.30 S .97 E ...... ~ 9T'S';"13O ...................... 9 00 ;'13'0 .......... 2';-r'-'l-.Ts: .'97'"'E 1073 107,3.00 1000.00 2.89 'S 1.02 E 1173 11725.00 1100.00 2,8.0.: S .... · ..,85 E ....... 1"2'7'3-- ..... I~';'lIIl ........... 1'20'0';'00" 2'~ 62 ...... S ...... ~ .............. ;'7'6 E' 1373 1373.00 1300.00 2.19 S .85 E lZ+73 lZ+73.00 1400.00 1.99 S .65 E 'I5'73-----I'573';"0'0 ........... 1'50"0';"00 1673 1673.00 1600.00 1773 1773,00 1700,00 1,40 S ,28 W o00 .00 · 00 .00 .01 .00 · 01 .00 ;UA ' .... · 01 .00 * .01 ,00 · 01 .00 1';'72'"$ ............ ?--"'"",I'8 E ..................... 7'OA~--------;'O'D ........... .-' 1.47 S .15 W .01 o00 .01 ;OHIO ALASKA PETROLEUM COMPANY :~H'EVFON-~TE/~'CT-I~K1Z-iZ ....... 23" 18 ~ 1'1 ~'I 2 dILDCAT tLASKA ANCHORAGEe ALASKA ~ .DATE OF SURVEY DEC 7~ii,:-:i980 t '. COMPUTATION"DATE ...................................................................................................................................... J DEC 8e 1980 dOB NUMBER BOSS-16716 KELLY BUSHING ELEV. = 73.00 FT. ....... : ................................................................................................................................................... OP'E':F:~'TOR;MCGUI"RrK-' .............. ~ INTERPOLATED VALUES FOR EVEN 100 FEET O'F SUB'SEA DEPTH . ~/.:/{ _ TRUE SUB-SEA TOTAL ~EASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL 7K'P'~ .................. -D'~ ................... D'EF'THZ'.~'~T::*NORTH'/S'0UTH ........... ) 1873 1873:::' O0 1800,00 1.58 $ 1'9'73' ......... -I-9'7'3'-;0'0'; ............... I'90'O";"O'0 ..................... 1,8'2" S ................... 207.'5 2073,00 2000,0'0 . 2,25 S ,27 W 2175 2175,00 2100.00 2 2575 257-~,.00. 2500.00 2~73 2~75'0'0 2qO0'O0 25'73- ..... '-"2573';~ ............... 2500~;~0'0 .............. 5 2673 2673,00 2600,00 2 2773 2773,00 2700,00 ,02 · 66 S .87 W ;02 ,~o s ..:3.,lo u JO.3. · 55 S ::'"':'!::'13.'93 W '0~ · 2~ S ~o.73 ~ ,05 · 88 S ~,3~ W ,05 ,00 ,00 , .00 .01 507~ 3073,00 SO00-O0 19.~9 S. '" 6.83 E .. ........... 3'175 ....... 31"73~;'0'0 ............... 310'0',0'0 ......... 36.20 "S~--~' ......... "I'~';28 .... E- ........ ~- ....... ~2";'72 1";-67 ::::':':: '''''':: '::':::'': :": ........ 3278 3273.00 5200.00 3382 3373.00 3300.00 3593 3575.00 3500.00 3702 3673,00 3600.00 57.96 S 22,6~ E 5,62 83.9q S 32.58 E 9.23 148.56 S 56.¢0 E 20.85 187.85 S 71.~0' E ." 29.36 2.70 :3.81 '5-;"0'2. 6.60 8,51 ;OHIO ALASKA!, PETROLEUM COMPANY IH]~VR'ON-'TI~-/~'CT ..... g'EEL .... 2'3- I B' 1 !; IP JILDCAT ~LA.SKA ~IEASURED DETFTH 3~13 ~.7 '.oo 3700.00. ......... 3927 ............. ~0~5 3973.00 3900.00 4167 4073.00 4000.00 A425 4273.00 4200.00 4555 43,73.00 4300.00 4817 4573.00 4500.00 4949 4673.00 A600.O0 :ANCHORAGE ~ ALASKA ' ',, DATE 'OF SURVEY DEC Tv' 1980 . 'C'O'MP'UTA T I'ON DATE ....................... DEC 8~ 1980 dOB NUMBER BOSS-16716 KELLY BUSHING ELEV. = 73.00 FT, :' ...., ':.: INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB'S-E-A.:.:DEPTH ~' TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL T~P'TFF ....................... DEPTH .......... N0 R'T H'! SO'UT H ............. E'A:'$TZ~E$'T .......'q~'Z'FF'ER'ENC'E'~TON: ........ .. 232,63 S 88,1~ E q0,21 - 10,86 i,: 2 8 4 · 0 8" S .......I"0'7',':5 0'"' 'E ......................... 5' 4",3/~ ............... ---~'zI'-;3.-2 :":~':~':'-': :' .... -" ...... 342,58 S 128,95 E 72,18 17.85 A08.65 $ 153.0A E 94,46 22.27 ~ 8 3; 6'~ :'S ...................... 1'79 ;' 51 "E .............. 1'~"~';.'~"3. ..... · '. '~"'~T.-71~: 562.5~. S 206.75 E 152;53 30.30 5212 A873,00 4800,00 5343 4973.00 4900,00 5'~Tz~ .....-533'73-2,'00 .............. 50'00";"0 O'" 5604 5173.00 5100.00 5734 5273,00 5200,00 ....... 5~8 ~,-2'"'-'---5373¥'0-0 ........... 5'3'0'0 ;0'0 .... 5990 5~73.00 5400.00 6117 5573.00 5500.00 641.62 'S ~ 23'3.56 E 182.78.'..::.'."i::;.:.:~.:.' :::$0.25 :. 7'~ o":'~'~'-'s ............ :..,., ~'~-o-; 7 ~ "E ..................... ~ '~'"~ ;"~'~"-" "~'"~:" '"': '? ~~ ........ '"" ' ":'::' :":" ........ ' ......... 801.72 S 288~36 E 2q~.77 31.51 882.78 S 316.75 E 276.60 31.83 -- -' - ~'~'I ...... '~TO'O ................ ~'70'0';'0'0 ............... 9'63';g I ..... S ~-~$"~1' .... E ........................ 3'0~~"--:.:.~..~.77:' :'~ ?:L':5'1' ~ 0-,' '.:"': "'" zo~,~z s ~?.o'~7. E ~9;50"' '"'.'.:'":~'.':.":':'.:'.~""~0~:"~~ 397'19 E 370~'36 './':::.:'" ' 1283.65 S 451.35 E 1361.59 S 478.15 E '1438"08-S ...........-505".'95 E .......... 1513.52 S 531.59 E 1587.97:S 556.27 E 1124.80 S 120'~';'6'2"'~ .... ~ ..... ~24'T2'~-E .............. ~"o'~';~'3-':'~'''''- ....... ?:':3o./~' ............................................... A31.~4 30.31 461,04 29,60 '~'B92~7 2'8';93 517.83 27.86 544'93 27-,10 ,.. .-, ANCHOR'AGE, ALASKA SOHIO AL'ASKA"PETROLEUM COMPANY WILDCAT ALASKA, FT. DEC 89-1980 dOB NUMBER BOSS-16716 KELLY BUSHING ELEV, = 73,00 INTERPOLATED] .VALUES FOR EVEN I'O0..FEET 'OF .. SUB'-SEA DEPTH i:"i:i:i'.'/ii.,,.' TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL TTE"FTE TTEP:TT~,.~ ................. :'I:TEP'T:RT'" ........... NO 5673,00 5600.0'0 1660.99' S 0.08 E ' ............ 5'7'7'3';"0:0 ................... 57"0'0~;'0'0 ...................... 1732; 5'7' S ............... 6'0'3";'8'5~ "E 6493 5873,00 5800,00 6616 5973,00 5900.00 673'7 .... '----'6~"O"T ............ EO'O0";O"O ...... 6857 '..::6173;00 6100,00 6978 6273,00 6200,00 7222 6~73,00 6~00,00 75~5 6573.00 6500.00 .......... 746'8 ........... '"~"T~;O'O ........66'0'0'00 7592 6.773,00 6700,00 7717 6873.00 6800.00 ............. 7'fl~ ...... ~973~"0'~ .... 690'0.00 797~ 7073.00 7000.00 8108 7173.00 7100.00 ............ ~2'~ ........ '7"27~¥0'0 ...... 720'0;00 ...... 8380 7373,00 7300,00 571,02 5g'6;'~7 620.18 25,91 6~3,03 22.85 8515 7~73.00 7qO0.O0 E 68 ~" 78' :"'::. E 705, "~ E 7q. 9.72 21.88 E 772;20 22.~8 E ................. 7 9'5";-1'6~ ......... -22-, ~J 6:- '~.<:: ":'-":'- .......... :'.-':. E 819,03 E 05' 25:. E ...... 871";"0"0' .... -- ........... 2'6';'~-~ ..... 1801.81 S 627.51 E 1869.z+2 S 650,31 E 1'9 '~'71"2"0"I-T':[' 1999, 3~ S,':: 6'89.75 o 6 6.13 2 220~,02 $ 729 i. 8Zl- 22 73, ~/-+ S 736.25 '2:5'~' 4'~'*'"'9 5:' '$:" ?"5'7 ',;'=}I" 2q. 18,0q. $ 737,09 24'.93; Oq. S 734..80 2'5''7'1 ;~'D 9 ....... S .................... '730,0'2 2653.94. S 723.1'7 E 901.06 274.2.7q S 71q~.20 E 935.11 2926,88 S 693,77 E 1007*7~+ 3016.76 S 682,11 E 10q2,71 30,06 34.°05 35.99 ANCHORAGE, ALASKA SOHIO ALASKA PETROLEUM COMPANY DATE OF SURVEY DEC 7~ 1980 ~HEVTTU~'T~L'T~L--23'~'l~'~'11';I'2 ......................................... COMPUTATI'ON ..... DATE ........................ -~ ........................................... ~-- ~ILDCAT DEC 8, 1980 dOB NUMBER BOSS-16716 ~LASKA KELLY BUSHING ELEVo = 73.00 FT. TRUE MEASURED VERT[CAL DEPTR 'DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD'TVD VERTICAL ~"EP~ ............... NO'RTH;$'OUTH .......... E'~"$'TTWEST,-DTFFERENCt' ....... CO"R'RECllON~ ......... 8649 .7573.00 7500.00 3104.29 S 669.53'.E 1076.20 33.49L. .............. 878T ............ 7'~7'3";"00 ........... 76"0'0";0'0 .............. 3189.87 S ........... 657285 .... E ................... II08~34 ........................ ~'22'I'q:-' ..................... ' ....... ~--' 8912 7773.00 770 9042 7873.00 780 ........... 9i'?~"T'~':7'g'T~'T~O-~ .... 790 9299 8073,00 800 9~26 8173,00 810 ......... 955'~- ............ ~'T$';ffO'' 820 9681 8373.00 830 9807 8473,00 84 .... g'9"55'~----~57~T~'O ...... 85 10063. 8673.00 86 0.00 3273.91 S 646.21 E 1139,68 0.00 3355.78 S 633,~6 E 1169.35 0.00 3513'88 S '~-02.'64 E 1226.16 0.00 3591.8I S. ' .586,56 E . 1253,95 0.00 3744'75 S ~51,24 E -1308,21 26.59 00.00 3819,83 S 531.73 E 1334,77 26.56 OO.O'O ......... 00.00 3973'17 S ~89,70 E 1390.27 " 27.53-~ 28.20'"i'.. ':.:?.' 10191 8i73.00 8700.00 ...... TUJFI ..... 8'E75';'[0 .............. 8800,'OO 10A52 8973.00 8900.00 10586 9073.00 9000.00 ...... 107~--'~I7'~;~0~'- g'IO0'.'O'O 10845 9262.50 9189.50 .... T HE-'-C~L'CUT2'NT~R O'C E O U R E S 'U S E THE NEAREST 20 FOOT MD (FROM A RADIUS 4050.52 S - ~68.~ E~ 1~18;~'7 4~'2s';~"-~ ........ ~'4'~';z~-""~'-~ ..... T~'~'B-;-~3"- .................. ~ .... z9'~5 ......... '""- ........ ': ........ ' .......... 4211~88 S 422.18 E 1~79.60 31.47 ~296.68 S 395.51E 1513.40 33.80 4383";'8~'"'S ................... 4863.93 s 3~0.87 E 1582,50 33.~5 ., LINE,AF-Zi~TE-R.PO~-A~IUN,.,BET~'EN OF CURVATURE) POINTS Check Form for timely compliance with our regulations. Operator, Wel 1 Name and Number Completion Report Reports and Materials to be received by: Date Well History Samples Mud Log ...... Core Chips Required I Date Received Yes Yes Remarks Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data Yes SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION *ARCO .......... To, EXXON ..... ... .. MOBIL .......... . . ~PHILLIPS *** ...... CHEVRON ' *** *SFO ....... : RE FE REf~bJ~; / 3~ 'c' STREET ANCHORAGE, ALAS~ I 3 ~A~L: POUOH ~ j I SmTT~] 1/16/81 #585 t iNETIC LIS TAPE ON CHEVRON TRACK WELL owing material is being submitted herewith. Please ~c~<nowledge receipt by signing a this letter and returning it to this office:- CHEVRON TRACK .~ELL 18-11-12 MAGNETIC LIS TAPE & LISTING #3 #61236 Carol Krieter Well Records _ , .,_.RECEIVED DATE 19 Alaska 0il & Gas Cons. Commission Anchorage SOHIO ALASKA PETROLEUM COMPANY January 12, 1981 ANCHORAGE, A~;~,A] TELEPHONE (907) ..... MAIL: POUCH ~. ANCHORAG E, ALASKA ~9~2~,[',~ ~-~ ..... C~ID~ ~ STAT TEC FILF: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Chevron Tract Well 23-18-11-12 Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of December, 1980. RHR: ja Enclosures cc: Well File ~17 Yours very truly, R. H. Reiley "':: ,.,~ District Drilling Engineer STATE OF ALASKA ~ ALASKW"~IL AND GAS CONSERVATION C "~IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover Operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 80-108 8. APl Number 50- 029-20511 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of Well at surface 809' NSL, 1032' DNL, Sec. 7; TllN, R12E, UPM 5. Elevation in feet (igdicate KB, DF, etc.) KRV. = 73' AMSL 6. Lease Designation and Serial No. ADL 28262 9. Unit or Lease Name Prudhoe Bay Unit ~0. We~ No. (23--18--11--12) Chevron Tract Well 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of December ,1980 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at month-end: 10906 ' Footage drilled: 381' 13. Casing or liner run and quantities of cement, results of pressur9 tests See attached Well History 14. Coring resume and brief description Cored from 9805' to 10644', a total of 15 cores. cumulative cores recovered 835'. Cumulative cores cut 840'; 15. Logs run and depth where run DIL/GR @ 10644' DIL/BHCS/GR @ 10901' FDC/CNL/N~/GR/Cal @ 10902' R~T @ 10595' CBL @ 10717' wt.'U 6. DST data, perforating data, shows of H2S, miscellaneous data See attached Well History Alaska Oil & Gas Cons. C°rnr~ls$iort Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED T~TLEDistrict Drilling EngineerDATE · ~' [ NOTE Re each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate HISTORY CHEVRON TRACT WELT, 23-18-11-12 Spudded well at 1500 hours, October 20, 1980. Drilled 17 1/2" hole to 2700'. Ran 68 jts. 13 3/8" 72# L-80 Buttress casing to 2684'. Cemented with 3720 cu. ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2645', tested casing to 3000 psi, okay. Drilled out to 2721', ran leak-off test to ~72 psi/ft, gradient. Directionally drilled 12 1/4" hole to 9750'. Ran 250 jts. 9 5/8" 47# L-80 Buttress casing to 9750'. Cemented in tv~ stages: First stage with 1390 cu. ft. Class G cement; second stage by down-squeezing 9 5/8" x 13 3/8" annulus with 280 cu. ft. Permafrost C cement follow~ by Arctic pack. Changed mud over to Oil-Faze. Cored from 9805' to 10644', a total of 15 cores; cumulative cores cut 840', cumulative cores recovered 835'. Ran open hole logs. Ran 40 jts. 7" 29# L-80 Buttress liner to 10906'. Cemented with 354 cu.ft. Class G cement. Cleaned out to 10735', tested liner to 3000 psi, okay. Ran CBL. Perforated at 10600' to 10620' (4spf). Ran DST test of perforations. DST of perforations at 10600' tested Ivishak water table, no flow to surface. Final flow pressure equals 4081 psi. Final shut-in pressure equals 4353 psi. Changed hole to 10.0 ppg. NaC1/NaBr. Set retainer at 10610', squeezed with 60 cu. ft. Class G with 18% salt. Cleaned out cement to 10426'. Tested liner to 3000 psi, okay. Set 9 5/8" bridge plug at 9191', placed 58 cu.ft. Class G cement on top of bridge plug. Laid 56 cu. ft. Permafrost C cement plug from 2500' to 2360'. Changed over top 200' of hole to diesel. Nippled down BOPE. Installed and tested adaptor flange and single master valve to 3000 psi. Released rig at 1800 hours, December 24, 1980. NOTE: Suspension of Well 23-18-11-12 witnessed and approved 12/22/80 by Harold Hawkins, Alaska Oil & Gas Conservation Commission. SOhiO PETROLEUM COMPANY, Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION -- TO: SFO ~NIT/STATE: ~ _ ,, 1/14/81 #577 SFO - J_l I ILL__ REFERENCE: 0N TRACK WELL FINAL DATA //The following material is being submitted herewith. Please acknowledge receipt by signing a v copy of this letter and returnir~g it to this office:-- Chevron Track Well 18-11-12 Drill Stem Test & RFT Halliburton Formation Testing Report Chemical Laboratories Water Analysis Report Carol Krieter Well Records DATE 19 Nasl~ 0il & Gas Cons. C0mmissi0n Anchorage TRANSNITTAL AND ACKNOWT.~ OF REC~TrPT OF NATERIALS EXP-140 Undor oeD~-*e ee~-'?~, ~ are forwarding the following material, via COMM --~OMM RES ENG ~ 2 GE0_~__- -- --3-~[6L ~ 'Fl[F= , , :~wlpLE~ ReEks: ~.z~-z~o (~-c~-8-6z) Printed in U.S.A. SOHIO ALASKA PETROLEUM COMPANY December 15, 1980 Alaska Oil & Gas Conservation Co~ission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Well s A-16, M-14, & Chevron Tract Well-23~18-11-12 & Y-11 R/D#1 Gentlemen: 3111 "C" STREET ANCHORAGE, ALASKA / MAIL: POUCI~_6~6` ~i~M~, ANCHORAGE, AL S,~(~~ | R~S ~N~ I~ ~'~o ..... t~]'- 3 ~EO~ ! JZ'jI STAT TEeN .... t STAT TEC Enclosed, in duplicate, are Forms 10-404, Monthly Report of Drilling and Workover Operations, for the above-named wells for the month of November, 1980. RHR:ja Enclosures cc: Well File #17 Yours very truly, District Drilling Engineer - STATE OF ALASKA ;%MISSION ~ ALASKAf*~,L AND GAS CONSERVATION CL., MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 80-108 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20511 9. Unit or Lease Name 4. Location of Well at surface 809' NSL, 1032' EWL, Sec. 7, TllN, R12E, UPM* *Corrected 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 73' AMSL ADL 28262 Prudhoe Bay Unit 10. Well No. Chevron 23-18-11-12 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of. Nove~r ,19 80 712. Depth at end of month, footage drilled, fishing jobs, directional drilling problems,, spud date, remarks Depth at month-end: 10525 ' Footage drilled: 3684 ' 13. Casing or liner, run and quantities of cement, results of pressure tests Ran 250 jts. 9 5/8" 47# L-80 Buttress casing to 9750'. Cemented in 2 stages: 1st stage with 1390 cu. ft. Class G cement (lost circulation); 2nd stage completed by down-squeezin¢ 9 5/8" x 13 3/8" annulus with 280. cu.ft. Permafrost C followed by Arctic Pack. Tested casing to 3000 psi, okay. Performed formation competency test to 0.7 psi/ft, gradient at 9805'. 14. Coring resume and brief description Cutting well cores at month end. 15. Logs run and depth where run DIL/BHCS/FDCCNC/GR at 9750'. ,1 6. DST data, perforating data, shows of H2S, miscellaneous data L~i~.'~, .1. ~ i~,:, Oil & Go.s Cons. Commissio~ 17. I hereby certify that the foregoing is true and correct tO the best of my knowledge. ~;SIGNED TITLEDistrict Drilling EI~c3ineerDATE ~' % 9' ~ NOTE~-R'ep~ form is required for-'~h calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate SOHIO ALASKA PETROLEUM COMPANY Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 November 7, 1980 TELEPHONE (907~,~-0000' 2 ENG' MAIL: POUCH 6-612 ' ,? ANCHORAGE, ALASKA 99502 4 ~'~ ~ ~.:OL.,.' ~'~ .... :" "T 'F~C .... : , 1.,.. F~ F: Attn: Mr. H. H. Hamilton Gentlemen: As requested by M~. Blair Wondzell of your office, enclosed are three copies of: 1) The well pad map showing the proposed well course of Chevron Tract Well 23-18-11-12; and 2) as built and surveyed surface location. Very truly yours, SOHIO ALASKA PE COMPANY W. R. Hicks Acting District Drilling Engineer WRH: mlh Enclosures cc: Well File ! HEREBY/-'~ERTIFY; THAT I APl PROPERL': EGISTERED AND LICENSED TO.PRACTICE LAND SURVEYING IN ,\ - THE STATE OF ALASKA AND THAT · J ~ " DETAILS ARE CORRECT AS OF:' ':" WELL 23-18-11 12 . ii SOHIO ALASKA PETROLEUM COMPANY November 10, 1980 ~["~ ~ "t 3111 "C" STREET. ~.,,~'< ANCHORAGE, AL~ MAIL' POUCH 6-612~ ANCHORAG E, ALASKA C~ID~~ jF1{.F: Alaska Oil & Gas Conservation~ission 3001Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Chevron Tract Well (23-18-11-12) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of October, 1980. WRH:ja Enclosures cc: Well File ~17 Yours very truly, Acting District Drilling Engineer STATE OF ALASKA ALASKA-rOIL AND GAS. CONSERVATION COMMISSION MONTHLY REPO'RT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum ~y 80-108 3. Address 8. APl Number :Pouch 6-612, Anchorage, Alaska 99502 50-029-20511 4. Location of Well at surface 900' NSL, 1000' AWL, Sec. 7, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 73.00' AMSL ADL 28262 9. Unit or Lease Name Prudhoe Bay.Unit 10. Well No. Chevron Tract 23-18-11-12 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of. October ,1980 12. Depth a.t end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud well at 1500 hrs., 10/20/80. Depth at month end: 6841 '. Footage drilled: 6841' 13. Casing or liner run and quantities of cement, results of pressure tests Ran 68 jts. 13 3/8" 72# L-80 Buttress casing to 2684'. Permafrost II cement. Tested casing to 3000 psi, okay.. at 2721' to 0.7 psi/ft, gradient. Cemented with 3720 cu.ft. Performed leak-off test 14. Coring resume and brief description i5. Logs run and depth where run None 16. [DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certifyt~hatthefore~ing is true and correct to the best of my knowledge. t ~ D\~,'~'~-~~~ Acting District Si NE / TITLE Drilling Engineer '1 I ' NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1 !"-- I00' Thru: ALASKA OIL'& Hoyle Hamilton Chai~/Commt ssioner Commi s s toner Bobby Foster i ~ ' .~' Field Inspector GAS ..~ CONSERVATION COMMISSION October 30, 1980 ' Witness.BOPE,test ~ ............ ::' ...... on'sohio's Chevron '~'~' ........... "Trac% Well #23-i8-ii-12 '~ .......... sec,'18, TllN,~!2E UPM ~:~' ' ...... ' '' permit %80-108 Wednesday ~ October 22, 19'~8~: I traveled this date to Che~on Tract Well ~23 18~T~[.::; :.. ~ :. ;' .. ::.~; ... :'. .... " Th~,sday, October 23 ~ .198%~_._ Friday, October 24, 1980-:~ ~St~ing ~y.~for BOPE te~t Saturday, Oc~ber 25, .19~0 w~er, -eq~{pm~' "failur~ wrong elevatiOn, the BOpm' concluded at 1~ 00 am, 0c~e~ :~ ~6 ~ -' f980 ~ .... The' two' failures were the mnsmde Kill lmne valve, which was repaiFed.a tested.and the upper Ke1i~%~1%e~id~'90dla~n0t This wmll be repaired/ repX~&6~:~n~':&h~"A:0:G:~.C: "office notified. _. In sugary, I witnessed t~ BOPE test on Sohio~s Chevron Tract 23-18-11-12 well a~'kilX&a~out test report which is 0ct6~r 28, 1 , ~d said upper Kelly Valve had ~e~ BF ~ 0&G # 4 4/80 ~ STATE OF ALASKA ; ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspecto~ 'Operator -~b/~~' ' Well Location: Sec Drilling Co~tracto r ~ '~~~ Rig Date /~J ~-- (~0 RepresentatiVe ~O~A ~~J, erm, t /~Cas ing Se t~~) ~ /ft. e e entat w Location, General Well Sign General Housekeeping Reserve pit ,, Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure JO~6~ psig Pressure After Closure/~6~d3 psig 200 psig Above Precharge Attained: -- rain/-~ sec Full Charge Pressure Attained:. j min/5 sec Controls: Master ~/~_~ ~Remote 5~ Blinds switch cover~F~ / Kelly and Floor Safety Valves Upper Kelly. / Test Pressure Lower Kelly / Test.Pressure Ball Type / Test Pressure Inside BOP / Test Pressure /~/~ Choke Manifold &f~ ~ Test Pressur~d90 NO. Valves No. flanges Adjustable Chokes / H]'drauically operated choke. / Test Results: Failures '.~ .. Test Time 7~/~-'' hrs. . R~pai'r or Replacement of failed equipment to be made within ~ days and Inspector/Commission office notified. Remarks:~ ~ !~~/'~ //~=$ cc - Operator cc - Supervisor Inspect September 22, 1980 Mr. R. H. Reiley District Drilling Engineer Sohio Alaska Petroleum Company Pouch. 6-612 Anchorage, Alaska 99502 Re: Prudhoe Bay Unit Chevron Tract 18-11-12 Sohio Alaska Petroleum Company Permit No. 80-108 Sur. Lou.= 900'NSL, 1000'EWL, Sec 7, T11N, R12E, Bottomhole Loc.: 2200'NSL, 1600'EWL, Sec 18, T11N, R12E, UM. Dear Mr. Reiley: Enclosed is the approved application for permit to drill the above referenced wel 1. Well samples and a mud log are not required. Core chips and a directional survey are required. If available, a tape contain- ing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter 'surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacte~ by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. R~ H. Reiley -2- Prudhoe Bay Unit Chevron Tract 18-11-12 September 22, 1980 commencing opera~ions you may be conta=ted by a representative of the Department of-Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We woula al~o like to be notified so'that a repre- sentative of the coau~ssion may be present to witness testing of blowout preventer equipa~nt before surface casing shoe is drilled. In the event, of suspension or abandonment, please gave this office adequate advance notification so that we may have a witness present. Very truly yours, Hoy l~&z H. Hami 1ton . Chairman of -~¥ O'~ Alaska Oil a Gas Conse~ation EnClosure cc= Department of Fish & Game, Habitat Section w/o enc1. Dep&rtment of Environmental Conservation w/o/encl. Department of Labor~ Supervisor, Labor Law Compliance Division w/o encl. SOHIO ALASKA PETROLEUM COMPANY 15 September 1980 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 CONFIDENTIAL Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Re Chevron Tract Well (23-18-11-12) Gehtlemen: Enclosed are the following documents, in triplicate, along with our check for $100 to cover the permit filing fee: 1. Application for Permit to Drill; 2. Proposed Drilling Program Outline; 3. Surveyor's Plat showing well location; 4. Blowout Prevention Equipment Diagram; 5. Pad Map showing well course. Very truly yours, SOHIO ALASKA PETROLEUM COMPANY R. H. Reiley District Drilling Engineer RHR:mlh Enclosures cc: Well File #17 Form 10-401. REV. 1-1-71 la. TYPE OF WORK STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL r-~ DEEPEN r-] b. TYPE OF WELL OIL GAS r--~ WELL [] WELL [ [ OTHER 2. NAME OF OPERATOR Sohio Alaska Petroleum Ccmpan¥ 3. ADDRESS OF OPERATOR Pouch '6-612, Anchorage, Alaska 99502 4. LOCATION OF WELL At surface 900' NSL, 1000' EWL, Sec.' SINGLE F--~ ZONE L~ 7, TllN, R12E At proposed prod. zone 2200' NSL, 1600' E~L, Sec. 18, TllN, R12E 13;' DISTANCE IN bflLES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 25 miles west of Deadhorse SUBMIT IN TRI TE (Other instructio,,~ on reverse side) MULTIPLE F-~ API #50-029-20511 6. LEASE DESIGNATION AND SERIAL NO. ADL 28262 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. Chevron Tract Well (.23-18-11-12) 10. FIELD AND POOL, OR WILDCAT Prudhoe Ba¥,Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 18, TllN, R12E 12. 14. BOND INFORMATION: TYPE Blanket surety and/or No. American Insurance Co. 3348616 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 1000' east of ADL 28245 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, Fr. 5200' S of 23-07,11-12 16. No. OF ACRES IN LEASE 2560 ' 19. PROPOSED DEPTH 9385'TVD 10917'MD 21. ELEVATIONS (Show whether DF, RT, CR, etc.) est. KBE = 65' AMSL 23. PROPOSED CASING AND CEMENTING PROGRAM Amount $500,000o O0 17. Ne. ACRES ASSIGNED TO THIS WELL 160 '20. ROTARY OR CABLE TOOLS 22. APPROX. DATE WORK WILL START September 1: 1980 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE MD SETTING DEPTlq~VD Quantity of cement 26" 20" 94# K-55 80 ' :80 ' 11 cu.yds. Arcticset concrete 171" 13 3/8" 72# L-80 .~670' ' '2670 ' 4650 cu. ft, P~rmafrost II 12¼" 9 5/8" 47# L-80 )808' 8415' 1391 cu. ft. Clang G ~p~, R,~h 8~" 7" 29# . ~L-80 if requ~ ~red ~,?il do %ec~ ¢~/~ ~,H ~¥ ~ ,~ a ,od~. ~. a.' .~ ~//~ /do. See attached proposeddrilling program outline. 1N ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If prOposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby cer~i~i~hat thel~orego~d (~ect ~s space for S~te office u~) ~NDITIONS OF ~PROVAL, IF ANY: s,.~ ~ ~ c=~ ~O~I~D I .UD ~ ~. REO~M.~S: D~S ~NO [ ~YES ~NO C' ~ ~f DIR~IONAL SURLY REQUIRED. ~P.I. ~CAL CODE ~ ~o 573 - o %.9 -'z. o ~,'/i District TITLE Dr~ll~n~ PERMIT NO. ~f ~ / g APPROVAL DATE APPOVED-BY ~~~'~ ~~ TITLE C~:a'~ wm~r~ ~ BY 0~ ~ THE~COM[~SSiONSee Instruction On Rev~r;;"'~- gepEeml~r 22; 1980 DATE 09/22/80 PROPOSED DRILLING & CC~PLSTION PROGRAM CHEVRON TRACT WELL (23-t8-11-12) Dry bucket 26" hole to 80' below ground level and cement 20" conductor to surface using 11 cu. yds concrete. Install diverter system and drill 17 1/2" hole to 2700'. Cement 13 3/8" 72# L-80 Buttress casing to surface using 4650 cu. ft. Permafrost II cement. Blowout Preventer Program consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer frcm 13 3/8" casing point to T.D. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss (based on original reservoir pressure). Maximum possible surface pressure is 3330 psi based on a gas column to surface frem 8600' TVDss and an oil column to 8800' TVD. Directionally drill 12 1/4" hole to 8415' TVD. Run 9 5/8" 47# L-80 Buttress casing to 8415' TVD and cement first stage with 1391 cu. ft. Class G cement. 9 5/8" casing will be hung at surface. ~Drill and core 8~ 1~2" ~le in oil-base fluid .to T.D. at 9385: TVD. Well will be completed, suspended, or abandoned depending on evaluation results. JM: ta SOHIO ALASKA PETROLEUM COMPANY Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr Blair Wondzell , ~'~'-'i' 'REs ENG j "c" ANCHORAGE, ~.A.S_K~ 2 ENG~ ' " ...... TELEPHONE (907} 265~0~ ":.' ~~ ; / 4 ENG ~ I ' ~AIL: POUCH 6-B12'l i~E~i~I ~NCHORAG E, AL~S~O~. :~ ~ .STAT T~C-- . ~ ~T,ATTE~ CONFEr: Please find enclosed in duplicate Chevron Tract Well (23-18-11-12) plat maps. District Drilling Engineer RHR: sw 51 I I I PR 1 OPOSED ,4CHEVRON TRACT ,W, ELL (23-18-11-12) ,/LAT.: 700 / I ooo'---J ~j~ X= 598,6~1 ~PROPOSED ~ ~ ~T BOTTOM ~ ~ , I ~1 HOLE ~ ~ I SCALE: 1" : I ~ILE iT. Il N. CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details are correct / "Date Surveyor Changed Welt Number from (18-11- t2) to (2~5-18-11-12) PJR 9/10/80 II I i i ii iiiii11 I I i i [11 i i i iiii iii i i i I I i i PROPOSED CHEVRON TRACT WELL(25-18-11-12) Located in sw i.~ PROTRACTED _S_E_C_._ 7_~T._II N_LN_=LR_~I ~.E~._._~L.U__.M ALA SEA Surveyed for SOHIO ALASKA PETROLEUM CO. Surveyed by F.M. LINDSEY 81 ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2.502 West Northern Lights Boulevard Box 4-081 Anchorage Alaska GROUND LEVEL FLOWLINE DRILLING RISER 10-3/4" ~fDRAIIL IC ~ 12" I~X. 20" 2000 PSI WP ANNULAR PREVENTOR DRILLING SPOOL DIVERTER SYSTEM DETAIL DRILL. DEPT. MARCH 1980 20" CONDUCTOR PIPE 3O NOTE: DIVERTER LINE HAS TWO DIRECTION DISCI-L~ CAPABILITY AFTER LEA. " ~RI~ SUB-BASES. B.O.P/*~,STACK CO N FIG U R ~,,T.~..~ 5/8" TRIPLE RAM STACK 5000 PSI WP _ DRILLING ANNULAR PREVENTER PIPE RAMS P'" KILL LINE CH ECK GATE GATE BLIND RAMS DRILLING SPOOL 4," CHOKE LINE GATE HYDR. ASST.. GATE PIPE RAMS 33 CHECK LIST FOR NEW ~LL PERMITS Item Approve Date (1) Fee ~/~_ ~.'~i 1. /! ..... 3. ..... 5'? (2) I~c. (3) kimin ., Yes No Is the permit fee attached ...................................... . Is well to be located in a defined pool ..............' . . Is a registered survey plat attached ............... Is well located proper distance frcm property line Is well located proper distance frcm other wells .. 6. Is sufficient undedicated acreage available in this pool 7. Is well to be deviato:t .............................................. 8. Is operator tlae only affected party ................................ 9. Can permit: be approved Before ten-day wait ......................... 10. IX~s operator have a t~nd in force .............. 11. Is a conservation order needed ...................................... 12. Is administrative apuroval needed ................................... 13. Is conductor string provided ........................................ ~ ..... Lease & Well NO. /~ U. Remarks (4) Cas~. ~ 14. Is enough cement used to circulate on conductor and surface ......... ~ .. 15. Will cement tie in surface and intermediate or production strings ...... 16. Will cement cover all known productive horizons ..................... ~ ... 17. Will surface casing protect fresh water zones ...................... ~ 18. Will all casing give adequate safety in collapse, tension and burst. 19. Does BOPE have sufficient pressure rating - Test to :~ooo Approval ~ec~ed: Additional Requirements: Geology: Engineering: / rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To imProve the readability of the Well History file and to 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. 11 '000006 7777777777. =dO0000 7777777777 {1 000000 7777777777 000000 7777777777 ll!l oo oo 7~ oo oo 1111 O0 O0 77 O0 O0 77 11 00 0000 77 O0 0000 77 11 00 0000 77 00 0000 77 ll O0 O0 O0 77 O0 O0 O0 77 11 O0 O0 O0 77 O0 O0 oo 77 11 0000O0 77 0000O0 77 11 0000O0 77 0000O0 77 1.1 O0 O0 77 O0 O0 77 11 O0 O0 77 O0 OO 77 11111.1 000000 77 000000 77 111111 000000 77 000000 77 ol3- IF'-Il- 666666 11 222222 333:33] 666666 666666 11 222222 ]3.3333 666666 66 1111 22 22 33 ]3 66 66 1111 22 22 ]3 33 66 66 11 22 33 66 66 11 22 33 66 66666666 11 22 ]3 66666666 66666666 11 22 ]3 66666666 66 66 11 22 33 66 66 66 66 11 22 ]] 66 66 66 66 11 22 33 3] 66 66 66 66 11 22 33 33 66 66 666666 111111 2222222222 333]33 666666 666666 111111 2222222222 333.333 666666 CCCC K R ,~ Y PPPP RRRR U O DDDD H iq OOO EEEEE C K I~ y ~/ P P R R O O D D ~i H 0 O E C K K Y Y P P R R O O D D H iq O 0 E KKK Y ..... PPPP RRRR U U D D HHHHH O O EEEE K t(. ~ P R R U U D D H H 0 O E K K ~t P Iq la U U D D H H O 0 'E K K ¥ P .R R UUUUi! DDDD H H [300 EEEEE $START* USER PCAL [10707,61236] dOB SHiP SEQ. 3,362 DATE 13-DEC-80 22:04:47 MONITOR SWS KLIOE40 N[']V-80. *START* · ( · · START* USER PCAL [{0707,61236] JOB SHIP SEQ. 3362 [)ATE 13-DEC-80 22.34.47 MONITilR SWS KLI. 0E40 N(]~/-80o *START* · ~SSSSSSS HH HH II SSSSSSS$ HH ~ II SS HH HH SS HH HH SS HH ~H SS H~ HH SSSSSS HHHHHHHHHH SSSSSS HHHHHHHHHH SS HH HH SS HH HH SS HH HH SS HH HH SSSSSSSS HH HH I1 SSSSSSSS HH HH II I I II II I I II II II 1I II Ii II II II II II II II I1 PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTTTTTTTT OOOOO~! TTT'rTTTTTT TT ~0 OU TT O0 OO TT O0 TT 00 TT OO TT 00 00 TT OO O(J TT 00 00 TT O0 O0 TT O0 OO TT 000000 TT 0,0000~ *START* USER PCAL [1.0707,6123611 ,lOB SHIP SEO. ))62 DATE 1)-DEC-80 22:04:47 MONi~f)R S~ KL10E40 NOV-80. *START* , FILE. DSKH:SHIP.~O<255>[16707,612)6] CREATED: 13-DEC-80 I7.58.42 PRINTED. II-DEC-80 22:05:01 OUEUE SNITCHES: /FILE:FORT /COPIES:! /SP~ACING:I /LiMIT:141 /FORMS:NORMAL SHIPPING INSTRUCTII}NS ISSUED II-DEC-80 17:58 PCCC THAN~S....... BY C~¥ PCCC YV VV EEEEEE~iEEE RDRRRRR~ VV YV EEEEEEEEEE RRRRRRRR VV YV EE R~ RR YV YV EE RR RR VV VV EE RP RR VV VV EE ~R RR VV VV EEEEEEEE ~RRRRR~g VV VV EEEEEEEE R~RRRRRR VV VV EE ~ RR VV VV EE RH RR VV VV E~ R~ RP VV VV EE RR RR VV EEE~EEEEEE RR RR VV EEEEEEEEEE RR RR IIiiii iIIIII II Ii Ii Ii II II II II II ii IIIIII IIIIII YY YY YY YY YY YY Y¥ ¥¥ YY Y¥ ¥¥ YY YY Y¥ 000000 000000 5555555555 000000 000000 5555555555 O0 O0 O0 O0 55 O0 O0 O0 O0 55. O0 0000 O0 0000 555555 O0 0000 O0 0000 555555 O0 O0 O0 O0 O0 O0 55 O0 O0 O0 O0 O0 O0 55 0000 O0 0000 O0 55 0000 O0 0000 O0 55 O0 O0 O0 O0 55 55 O0 O0 O0 O0 55 55 000000 000000 555555 000000 000000 555555 *START* USER PCAL [10707,61236] dOB SHIP SEQ. MONI~JR 6WS ~L10E40 NOV-80 *START* , fILE: DSKH:VERIFY.005<057>[10707 61236] CREATED: PRINTED: 13-DEC-80 22:0~:10 QUEUE SWITtHES. /FII,E:FORT /COPIES:I /SPACING:I /LIMIT:141 /FORMS:NORMAL DATE 13'DEC-80 ~-DEC-80 22:03:35 22:04:47 SCHLUMBERGER COMPUTING CENTER 10707,61236 REEl, HEADER I,ENGTH: 132 BYTES REEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CONIINUA~IUN NUMBER: O1 PREVIOUS REEL NAME: COMMENTS: L1S FORMAT CUSTOMER TAPE DATE: 80/12/13 TAPE HEADER LENGTH: 132 BYTES TAPE NA~E: 61236 [)ATE: 80112113 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O1 PREVIOUS TAPE NAME: C(}MMENTS: TAPE COMMENTS CASING DRILLER 1].370268].O/BIT S1ZE 12.25/FLUID LOSS 5.! DENS 10.1/¥ISC 42.0/PH 9.0/FLUID TYPE LIGNOSULFONATE/ RM 3.87~8~ F/RMF 2.89~81 F/RMC 4.2~74 F/MAX REC T~P 157 ********TAKEN FROM RUN~I DIL LOGGED 8NOV80 CASING DRILLER q.625~9750/BiT SIZE 8.5/FL[JID T'¥PE (]iL FAZE/ DENS IO.1/VISC 62.0/FLUID LOSS 3.0 i'4L/MAX REC TMP 179.0 F/ ***~** TAKEN FROM RUN#3 DIL LOGGED 7/DECSO , , , , , , * , , , , , , , , , FILE HEADER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM'PHYSICAL RECORD LENGTH: 1024 BYTES PREVlOUS FILE NAME: FILE C£]M~ENTS *****IN RUN~3 NO SFhO & SP ON OIL WELL SITE INFORMATION RECORD I,ENGT~; 163 BYTES COMPA N~L CHEVRON [,ISA ~ [ELD: SECTION 23-18-11-12 W 1LDCI7 12E lin ? N.SLOPE DATA fOI4M/~T SPEC.I[FICATIF]N LENGTH: 850 BYTES i~::NTR:~ BLOCKS: :¥PE 0 SIZE REP CODE ENTRY 1 66 0 DATUM SPECIPICATI(]N BLOCKS: ENTRY lC TOOL 1 DLPT 2 SP DIL 3 ILD 4 ILM 5 SFLU DIL 6 GR DIL 7 SGR CNL 8~ CALI CNL g DRHO CNL I0 NPH1CNL ll RHOB CNL !2 NRAT CNL 1~ NCNL CNL 14 FCNL CNL 15 GR. BHC 16 DT EHC 17 SGR NGT 18 THOR 19 URAN 20 P[]TA 21 GBST SVOBD# UNITS APl AP1 AP1 AP! FILE# SIZE EXP PROC SAM REP DkJPT SHIFT ['T 0 0 0 0 0 4 0 0 1 68 0 0 MV 7 1 0 0 0 4 0 0 1 68 0 0 OH~M 7 12 46 0 0 4 0 0 1 68 0 0 OHMN 7. 12 44 0 0 4 0 0 1 68 0 0 OHMM 7 22 1 0 0 4 0 0 1 68 0 0 GAPI 7 31 32 0 0 4 0 0 1 68 0 0 GAPI 42 31 32 0 0 4 0 0 1 68 0 0 IN 42 28 1 0 0 4 0 0 I 68 0 0 G/C] 42 44 0 0 0 q 0 0 I 68 0 0 PU 42 68 2 0 0 4 0 0 1 68 0 0 G/C3 42 35 I 0 0 4 0 0 1 68 0 0 C/C 42 42 1 0 0 4 0 0 1 68 0 0 CPS 42 ~4 92 0 0 4 0 0 I 68 0 0 CPS 42 34 93 0 0 4 0 0 I 68 0 0 GAPI 60 31 32 0 0 4 0 0 1 68 0 0 US/F 60 52 32 0 0 4 0 0 1 68 0 0 GAPi 42 31 32 0 0 4 0 0 I 68 0 0 PPM 0 0 0 0 0 4 0 0 1 68 0 0 PPM 0 0 0 0 0 4 0 0 1 68 0 0 NONE 0 0 0 0 0 4 0 0 1 68 0 0 GAPI 0 0 0 0 0 4 0 0 1 68 0 0 DE PTH 10930.000 10900.000 10800.000 1 0700,000 1. O6OO.000 10500.O00 10400.000 10'{O0.000 10200.000 MN E.M t JN 1 C BP Git NPHI FCNL THOR SIP Git NPHI FCNL THOR SP GR NPHI F C N,la THOR SP GR NPHI FCNL SP GR NPH1 PCNL TH{JR SP GR NPHI FCNL THOR SP NPHI ECNL THFIR SP GR NPHI FCNL TH(JR 6P NPHi FCNL 'VALUE -1000.000 54.875 -1.855 0.000 10.961 -1000.000 54.875 -2.832 0.0OO 12,086 -1000.000 48.656 12.939 2470.000 7.281 -1000.000 89.500 27.I97 1538.000 1.1.289 -1000.000 14.359 18.066 2142.000 3.645 -1000.000 46.688 5.322 4024.000 8.68O -1.000.000 14.219 19.336 1650.000 4.047 -1000.000 16.734 12.402 2486.000 4.207 -1000.000 16.547 18.311 1700.000 4.090 MNEMON lC i L D SGR GR URAN iLD SGR RHOB Git URAN ILD SGR RHOB GR U R A N ILD SGR RHOB Git []RAN 1LD SGR RHOB GR URAN IBD SGR RHOB GR URAN iBD SGR RHOB GR URAN ILD SGF, GR URAN ILD SGR RHOB GR URAN 'VALUE 4.02'7 0.000 .875 ~3. ~162 4.023 O 000 lO0 7.406 65 ] 75 2 ~547 48.656 1. t95 4.211 93.56] 2.436 89.500 1.755 2.498 26.438 2.375 14.~59 0.202 O.219 67.188 2.656 46.688 0.706 6.242 2].609 2.295 14.219 -0.275 26.084 25.953 2.400 16.734 -0.045 24.469 2.240 16.547 -0.040 MNk.MONIC CALl NRAT DT POTA II~M CALl NRAT DT~ POT h ILM DT P {:1T A CALl NRAT DT Pf)TA 1LM CALl NRAT DT POTA ILM CAI, 1 DT POTA IBM CALl NRAT DT POTA IbM CALl NRA'].' DT POTA IL~. CALI NRAT DT PUl' A VALUE 4.43q 2.393 0.000 74.188 0.02I 4.441 7.340 0.000 ~ 026 8.164 .70,{ .89] MNEMONIC VALUE SFBU -1000.000 DRHO -6.945 NCN,L O.000 SGR 101.063 GRST 75.750 SFLU -1000.000 DRHO ~:07~ NCNI, 000 C' S .,R 101 875 (;RST 9 3: o6 a SFLU -1000.000 DRHO 0.028 NCNB 4816.000 SGR 56.594 GRST 45.438 4.570 SFLU ~1000.OOO 9.039 DRHO 0.012 2.877 NCNL 4648.000 82.000 SGR 105.125 0.022 GRST 91.063 3.014 8.969 2.260 87.750 0.002 11.352 8.750 1.387 63.188 0.014 6.367 8.844 2.334 86.188 0.004 32.625 8.820 1.865 75.750 0.002 84.438 8.898 2.271 93.000 0.002 SFLU -1000.000 DRHO -O.012 NCNB 4808.000 SGR 19.813 GRST 18.188 SFLU -1000.000 DRHO 0.014 NCNL 5444.000 SGR 66.063 GRST 60.406 SFLU -1000.000 DRHO 0.017 NCNB 3890.000 SGR 18.875 GRS? 21.078 SFLU -1000.000 DRHO 0.011 NCNL 5040.000 SGR 19.250 GRST 19.609 SFLU -1000.000 DRHO -0.006 NCNB 4044.000 SGR 20.844 GRST 21.172 DEPTH 101O0,00O 10000,000 0900,O00 0800,000 9'700. 000 9600.000 0500,000 9400,000 930 0. 000 MN EMON1C VALUL MNEM[}NIC SP -1000.000 iLD (;R 1,6 ~31 SGR NPHi 16[.97 EHOB PCNL 201,6.000 GR TH()E 3,848 URAN SP -1000.000 ILD GR 78,125 SGR NPHI 21.387 RHOB FCNL 1362.000 GR TH('IE 10.531 ORAN SP -1000,000 iLD GR 74.313 8GR NPH1 20.898 RHOB ~'CNL 134].000 GR THOR 9.359 URAN SP '1000,000 ILD GE 110,000 SGR NPHI 33.789 RHOB FCNL 706.500 GE THOE 13.500 URAN SP -17.500 ILD GR 117.813 SGR NPHI .38.281 RHOB FCNL 399.000 GR TH(JR -999.250 URAN SP -21.500 ILD GR 100.938 SGE NPHI 37.500 RHOB FCNL 390.250 GR THOE -999.250 URAN SP -23.000 ILD GR 95.000 SGR NPHI 40.186 RHOB PCNL 403.250 GR THOR -999.250 URAN SP -24.500 ILD GR 84.750 SGR NPHI 28.076 RHOB FCNL 458.250 GR THOR -999.250 OEAN SP -27.500 ILD GR 75.000 SGR NPHI 21.680 RHOB FCNL 766.500 GR THiJE -999.250 [IRAN VALIIE 46.938 445 16,531 -0.250 6,672 100,56.3 2,648 121 17.219 ] 063 8:604 383 2. 117 063 2:637 110,000 2. 055 1.513 127.750 2.385 117.813 -909.250 1,406 115.313 2.479 100.938 -999.250 ].748 99.188 2.424 95.000 -999.250 2.313 98.125 2.506 84.75O -999.250 2.889 75.063 2.607 75.000 -999.250 MNEMF]NIC iLM CALl NRAT UT POTA NRAI DT POTA IbM CN ALI RAT POTA ILM CALl NRAT DT POTA ILM CALl NRAT DT POTA ILM CALl NRAT DT POTA CALl NRAT DT POTA ILM CALl NRAT DT POTA ILM CALl NRAT DT POTA VALUE 63.000 8.492 2.1:37 78.000 0.006 461 ooo *o7:o o 20.734 .484 .412 7~. 000 017 , MNEMONIC VALUE SFLU -lO00.000 ORHO 0 021 NCNL 4504:000 SGR 21.875 GRST 23.875 SFLU -1000,000 RHO 0.013 CNL 3448.000 GR 93 563 RST 60~594 SFLU -1000.000 RHO 0.023 CNL 3410.000 GR 89.125 RST 62.094 1.639 12.008 3.775 115.750 -999.250 1,518 12.344 3.734 108.188 -999.250 1.931 12. 398 3.910 98.375 -999.250 2.438 15.406 3.197 96.56:3 -999.250 3,115 14.305 2.738 84,188 -999.250 SF'LU 2.1'76 DRHO 0.05b NCNb 1721.000 SGR -999.250 GRST -999.250 SFLU 1.830 DRHO 0.107 NCNb 1719.000 SGR -999.250 GRST -999.250 SFLU 2.688 DRHO 0.117 NCNb 1776.000 SGR -999.250 GRST -999.250 SFLU 2.713 DRHO 0.134 NCNL 1695.000 SGR -999.250 GRST -999.250 SFLU 3.570 DRHO 0,104 NCNb 2264.000 SGR -999.250 GRST -999.250 DE PTH 9200.000 9100.000 9000.000 8900'000 8800.000 8700.000 8600. 000 8500.000 8¢00.000 MNEMONIC SP GR NPHi FCNL THOR SP GR NPHI ?CNL TBi)R SP GR NPHI F'CNL THOR SP GR NPH I FCN L THO[~ SP GR NPHI FCNL THOR SP GR NPH 1 FC NL TH(JR GR NPHI FCNL THOR GR NPH I FCNL THOR SP GR NPHi P CNL TH[]~ VALUE -29.500 6'7.688 21.436 721.500 -999.250 -26.5OO 93.000 ]5.547 436.000 -999.250 -29.000 90.625 36.768 430.25O -999.250 '34.000 86.750 36.230 430.250 -999. 250 -34.500 78.500 30.322 500.500 -999.250 -39.000 72.0OO 23.047 750.000 -999.250 -38.000 64.563 19.092 849.50O -999.250 -30.000 99.625 35.400 407.000 -999.250 -35.000 90.500 32.86t 475.000 -999.250 EMON lC I L D SGR RHUB GR URAN ILD SGR RHOB GR lJ R A N ILD SGR RHOB GR URAN iLD SGR R H O B GR URAN 1LD SGR R H O B GR URAN ILD SGR RHOB GR URAN ILD SGR RHOB GR URAN ILD ,SGR RHOB GR URAN ILD SGR RHOB GR URAN V A b U E 2.988 69.188 2.535 67.688 -999.250 1.492 102.625 2.379 93.000 -999.250 1.632 97.938 2.453 90.625 -999.250 1.685 9.3.06.3 2.391 86.750 -999.250 2.990 90.500 2.441 78.500 -999.250 3.O80 73.063 2.455 72.000 -999.~50 3.441 72.375 2.46] 64.563 -999.250 102.875 2.379 99.625 -999.250 1.730 95.125 2.4.]2 90.500 -999.250 MN EMf'INIC iLM CALl NRAT DT POTA ILM CALl NRAT DT Pf]TA ILM CALl NRAT DT POTA ILM C AL 1 N RAT DT POTA ILM CALl NRAT DT POTA 1LM CALl NRAT DT POTA CALl NRAT DT POTA CALl NRAT DT P()TA ibm CAL 1 NRAT DT POTA VALUE 3.152 16.~ 86.750 -999.250 1.619 281 111.563 -999.250 I .727 770 103. 188 -999.250 1.775 15.008 3.721 110.188 -999.250 3.008 14.883 3.330 98.563 -999.250 3.248 14.445 2.832 90.563 -999.250 3.052 14.609 2.574 86.375 -999.250 1.423 15.359 3.676 107.561 -999.250 1.797 15.039 3.500 99.375 -999.250 MNEMONIC SFLU DRHU NCNL GR RST SFLU DRHO NC Nb RST SFLU DRHO NCNL SGR GRST SFLU DRHO NCNL SGR GRST SFLU DRHO NCNb SGR GRST SFLU DRHO NCNL SGR GRST SFLU DRHO NCNL SGR GRST SFLU DRHO NCNb SGR GRST SFLU DRHO NCNb SGR GRST VALUE 3.342 0.045 2330.000 2999. so 999.250 1.778 -0.005 1718.000 -999.250 -999.250 2.156 -0.002 1791.000 -999.250 -999.250 1.867 0.011 1817.000 -999.250 -999.250 2.637 0.045 1905.000 -999.250 -999.250 3.166 0.023 2032.000 -999.250 -999.250 3.535 0.004 2470.000 -999.250 -999.250 1.467 0.012 1716.000 -999.250 -999.250 1.770 0.039 1795.000 -999.250 -999.250 DEPTH 8300.000 8200.000 8100.000 8qO0.O00 7900.00O 7800.000 7700.000 7600.000 7500.000 MNEMON lC SP GR NPHi [~'CNL TH(lB SP GR NPH I FCNb THOR SP GR NP}tI FCNL TH()B NPH I ~,~CNL THOE SP GR NPHI F'CML THOR SP GR NPH I FCNL THF}R SP GR NPHI FCNb THOR NPHI f:CNL ~I'HOR SI> GH NPHI I~CNL T}ilJR VALUE -39.000 86.438 33. 301 469.000 -999.250 -40. 500 8'7,813 32.031 483.500 -999. 250 -43.500 86.56'~ 3I .738 464.000 -999.250 -48.500 73,125 20,752 677.5~0 -999.250 -46.000 93,875 35.107 441.750 -999.250 -46,000 90,000 39,014 375,750 -999,250 -49,000 83.063 32.129 427.000 -999,250 -53. 000 93.625 33.350 475,000 -999,250 -53.500 129.125 41,748 360,750 -999.250 MN Eh]ON lC ILI) SGR RHOB GR U~AN ILD SGR RHOB GR URAN I LB SGR RHOB GR URAN ] LD SGIq RHOB GR URAN ILD SGR RHOB GR URAN ILD GR URAN ILD SGR RHOB GR URAN ILD SGR RHOB GR URAN ILD RHOB URAN V Ali liE 3.480 92.688 2.443 86 4]8 -999:250 ',~. 545 93.813 2.434 87.81] -999,250 3.646 90. 063 2.410 86,563 - 999,250 3.424 68 000 2;480 7]. 125 -999.250 2.869 89,000 2.342 93,875 -999,250 1,876 88,50O 2.529 90,000 -999,250 1 .~48 8].563 2.420 83,063 -999.250 2.234 90.625 2. ~65 93.625 -999.250 3.262 137,875 2,299 129.125 -999.250 MN E MI") N lC I LM CALl NRAT DT P{]TA I L~. CALl NRAT DT POTA ILM CALl NRAT Pf]TA CALl NRAT DT POTA CALl NRAT DT Pf)TA CALl NRAT DT POTA ILM CALl NRAT DT POTA CALl NRAI~' DT POTA 1LM CALl NR.AT DT POTA VALUE 3.557 15.156 3.533 91.375 -999.250 3.533 17.20 3 3.504 85.750 -999.250 3.658 18.234 3'512 -999,250 3.613 17.813 2.768 84,375 -999,250 2.930 16.828 3,693 110.375 -999.250 1.944 16.625 3,943 111.750 -999,250 1,979 16,781 3,498 117,563 -999.250 2.311 17.828 3.605 104.188 -999.250 3.215 15,875 4,102 124.56.~ -999.250 M N EMONIC SFDU DRHU NCNB SGR GRST SFLU DRHO NCNB SGR GRST SFLU DRHO NCNB SGR GRST SFLU DRHO NCNB SGR GRST SFLU DRHO NCNL SGR GRST SFLU DRHO NCNL SGR GRST SFLO DRHO NCNb SGR GRST SFLU DRHO NCNb SGR GRST SFLU DRHO NCNB GRST VALUE 3.1.00 0.017 1800.000 -999.250 -999.250 3.277 0,028 1854.000 -999.250 -999.250 3.117 0.011 1829.000 -999.250 -999.250 3.596 0.042 2086.000 -999.250 -999.250 2.662 0.018 1714.000 -999.250 -999.250 1.963 0.051 1718.000 -999.250 -999.250 1.862 0,049 1628.000 -999.250 -999.250 2.668 0.020 1786.000 -999,250 -999,250 3.664 0.02] 1610.000 -999.250 -999.250 EPI'H 7400.000 7t00.000 7200,O00 7100,000 7000.000 6900,000 6800,000 6700,000 6600,000 MNEMI.)NiC SP NPH I FCNL THOR SP GR NPHI k'CNL THOR SP GR NPHI FCNL THOR SP GR NPHI ~CNL THOR SP GR NPHI P'CNL THOR SP GR NPH1 F'C NL THOR SP GR NPHI FCNL THOR SP NPHi ~CNL THOR NPHI ~CNL VALUE -55,000 204.375 39,160 365,250 -999.250 -64.500 150,875 39.258 354,25O -999.250 -57.500 89,250 34,81~ 462,000 -999,250 -53,000 86,875 37,500 414,000 -999,250 -56.000 121.438 33.105 501.000 -999,250 -60,500 146,250 3],447 490.500 -999.250 -47,000 135,375 35,506 427,250 -999,250 -50,500 129,250 35,693 422,750 -999,250 -47,000 128,000 35.107 444,750 -999.250 MN EMUN lC iBD SGR RH{]B GR URAN IBD SGR RHOB GR [IRAN ILD SGR RHOB GR URAN ILD SGR RHOB GR URAN ILD SGR RHOB Gt~ URAN 1LD SGR RHO8 GR []RAN ILD SGR RH[)B GR ORAN ILD SGR RHOB GR URAN ILD SGR RHOB GR URAN VAI.,I.tE 2.164 211.625 2.391 204 ~75 -999~250 2,500 155 625 2i287 150 875 -999,250 ], 490 938 89 250 -999: 250 4.742 93,438 2,293 86,8'75 -999.250 ~. 1371. 117,625 2. 121,438 -999,250 3,~54 157,625 2,.387 146,250 -999,250 2,234 155,000 2,303 1 35..{75 -999,250 1.976 135.625 2.~96 129.250 -999.250 2,580 15].000 2,336 128,000 -999,250 MNEMON lC IbM CALl NRAT DT POTA CALl NRAT DT P [1T A 1LM CALl NRAT DT P[]TA ILM CALI NRAT DT POTA CALl NRAT OT POTA iLM CALl NRAT DT POTA IbM CALl NRA~I DT POTA IbM CAbI NRAT DT POTA ibm CALl NRAT DT POTA VALUE MNEMONIC VALUE 2,451 SFLU 3.541 14,750 DRHO 0,031 3,904 NCNb 1598.000 110 750 SGR -999,250 -999~250 GRST -999,250 2.504 SFLU 2.760' i 305 D,RHO 0.042 1 ~898 NCNb 1683.000 121 563 SGR -999,250 -999 ~ 250 GRST -999. 250 3.736 SFLU 4.129 14.156 ORHO 0.014 3.605 NCNb 1902.000 106,750 SGR -999.250 -999.250 GRST -999.250 4,977 SFLU 8.500 13.391 DRHO -0.001 3,762 NCNb 1656.000 112.56,3 SGR -999.250 -999,250 GRST -999,250 3.5,t9 SFLU 4'.309 14,258 DRHO -0.002 3,496 NCNL 1802.000 109,563 SGR -999.250 -999.250 GRST -999.250 3,541 SFBU 4.215 14.156 DRHO -0,002 3,516 NCNB 1892,000 104.000 SGR -999.250 -999,250 GRST -999,250 2,078 SFbU 2,504 12.859 DRHO 0,008 3,623 NCNb 1927,000 92,563 SGR -999,250 -999,250 GRST -999,250 1,957 SFLU 2,549 13.604 DRHO 0.020 3,650 NCNb 1702.000 105,750 SGR -999,250 -999,250 GRST -999,250 2.541 SFLU 2,697 13.516 DRHO 0,002 3.607 NCNL 1'761.000 102.000 SGR -999.250 -999.250 GRST -999.250 DEFT}-{ 6500. 000 6400.000 6300.000 6200.000 6100.000 6000,000 5900.000 5800.000 5700.000 MNEMOi~ lC SP GR NPHi FCNL THOR SP GR NPH1 FCNL 8P G~ NPH1 FCNL TH{lB SP GR NPHI FCNL THO~ 8P GR NPHI FCNL THOR SP GR N P H I ~C N L THOR SP GI~ NPHI FCNL THfJR SP GR NPHI FCNL TH(JR SP GR NPHI FCNL THOR VALUE -56.500 107.750 29.883 495,250 -q99.250 -54.500 90 188 321324 5,35.000 -999.250 -55,0O0 78.375 31.738 498.750 -999,250 -54,000 79,250 27.734 588.500 -999,250 -55.000 73,438 28,174 558.00O -999,250 -56.500 84,438 34.180 447.750 -999.250 -59.000 77.875 28.076 029.500 -999.250 -69.000 71,563 28.125 616,500 -999.250 -67,500 94.125 31,982 476,250 -999,250 ILD SGR RI-lOB GR I, LD SGR RHOB GR URAN IbD SGR RHOB Gl{ URAN ILD 8GR RHOB GR ORAN ILD SGR RHOB GR URAN ILD SGR RHOB URAN ILD SGR RHOB GR URAN ILD SGR RHOB GR URAN IbD SGR GR URAN 'VAL!IE: 2,945 117.]1] 2,484 107 750 -999:250 2.617 9~..875 · 408 90.188 -99q.250 2.234 89.063 2,416 78.375 -999.250 2.779 82.500 2 361 79!250 -999 250 2.666 78.813 2.~73 73.438 -999.250 2.783 88,313 2,]61 84.438 -999.250 4.008 89.688 2.324 77.875 -999.250 5.203 77,438 2.361 71,563 -999.250 3.455 106,688 2.]79 94,125 -999,250 MNEM(]NiC IbM CALk NRAT POTA ILM CALl NRA/ DT POTA ILM AT DT POTA CALl NRAT DT POTA ILM CALl NRAT DT PUTA i LM CALl NRAT DT P()TA ibm CALl NRAT DT POTA ILM CALl NRAT DT POTA 1LM CALl NRAT DT POTA VALUE 2.998 15.555 3.320 98,000 -999.250 2.592 ] 508 1 ';477 .100.188 999'250 MNEMONIC VALUE SFbO 3.383 DRHO ~0.01 ! NCNL ~85= .000 SGR -999 250 GRST -999:250 SFLU 2.719 ORHU 0.029 2oo .ooo 2,287 SFLU 2,352 15.766 DRHO -0 001 3,447 NCNL 1868[000 97 000 SGR -999.250 -999:250 GRST -999.250 2,840 14,703 3.154 95.188 -999,250 2.674 14,766 3.189 98.750 '999.250 2.756 15.260 3.594 99.375 -999.250 3.840 14,047 3.162 94.375 -999.250 5.727 13.195 3.145 89.188 -999.250 3.371 17,453 3.508 103,563 -999,250 SFLU 2'838 DRHO 0.006 NCNL 2042.000 SGR -999.250 GRST -999,250 SFLU 2.932 DRHO 0.021 NCNb 195'7.O00 SGR -999.250 GRST -999.250 SFLU 2.732 DRHO 0.019 NCNb 1888.000 8GR -999.250 GRST -999.250 SFLU 3.768 DRHO 0.021 NCNb 2222.000 8GR -999.250 GRST -999.250 SFbU 6.266 DRHO 0,032 NCNb 2082.000 8GR -999,250 GRST -999,250 8FbU 3.160 DRHO 0.028 NCNb 1816.000 SGR -999.250 GRST -999.250 DEPTH 5600.000 5500.000 5400.000 5300.000 5200.000 51OO.000 5000.OO0 4000. 000 4~00.000 MNEMONIC SP GR NPHI ~'C NL T H O P SP GH NPH1 I;CNL T H L} R SP GR NPH1 FCNL SP GR NPHI ~CNL THOH SP GR NPHI ~'CNL 8P GE NPHI FCNL THU~ SP GR NPHI FCNL THOR SP GR NPHI FCNL THOR SP GE NPHI ~CNL VALUE -60.500 95.438 29,785 531.500 -999.250 -58.500 69.625 32.715 500.000 -999.250 -66.500 80.000 29.492 520 000 -999~250 -59.000 73.063 29.639 49"7.250 -999.250 -55.719 63.063 31.787 430.250 -999.250 -75.750 66.56] 25.439 527.000 -999.250 -86.750 67.750 ]1.299 452.000 -999.250 -112.500 54.813 31.885 469,500 -999.250 -83.563 83.250 35.352 402.500 -999.250 MNEM[JNiC VAL{IE ILD 3.602 . P. HC}B 2~ 387 GR 95 438 UR,AN -999:250 SGH 3. i 04 RHOB 420 GR 69.625 ORAN -999.250 ILD 3.730 SGR 8~.188 RHOB .412 GR 80.000 ORAN -999,250 ILD 3,055 SGR 72,250 RHOB 2.307 GR 73,063 URAN -999,250 ILD 3.]28 SGR 71 250 RHOB 2]307 GR 63.063 ORAN -999.250 ILD 4,766 SGR 76,938 RHOB 2, ]63 GR 66,563 ORAN -999,250 ILD 3.533 SGR b5,875 RBOB 2,270 GR 67,750 ORAN -999,250 iLD 3,809 SGR 59,.]13 RIiOB 2.]20 GR 54,813 {IRAN -999,250 ILD 4,629 SGR 79,813 RH(IB 2,]50 GR 83,250 ORAN -999,250 NN EMONIC IBM CALl NRAT OT POTA ILM CALl, NRAT DT POTA CALl NRAT DT POTA IL:M CALl NRAT DT POTA CALl NRAT DT IBM CALl NRAT DT P{}TA ILM CALl NRAT DT POTA ibm CALl NRAT DT POTA CALl NRA'.[ DT P U T A V.AUUE ].56~ 17,453 3.363 104 375 3.088 64 100 000 - 99 so 3,648 16,859 ~3.330 .104.1fl8 999.250 2.881 17.328 3.350 107.563 -999.250 3.277 14,836 3.426 103.188 -999.250 4.824 15.523 3.021 88,750 -999,250 3,869 1.4.703 3,389 115.188 -999,250 4.305 14.242 3.418 102.56~ -999.250 4,398 18.203 3.748 102,000 -999.250 MNEMONIC VALUE SFLU 3.330 DRHO 0 039 NCNB 1895~000 SGR -999.250 GRST -999.250 8FLU 3.193 DRH0 -0.003 NCNb 1903.000 SGR -999.250 GRST -999.250 SFLU 3.398 DRHO 0 032 NCNB 1843;000 SGR -999,250 GRST -999,250 SFLU 2,520 DRHO 0.007 NCNb 1849.000 SGR -999,250 GRST -999.250 SFLU 4.430 DRHO 0,059 NCNb 1589.000 SGR -999.250 GRST -999,250 SFLU 5.801 DRHO 0,103 NCNB 1796.000 SGR -999,250 GRST -999,250 SFLU 4,359 DRHO 0,064 NCNb 1608.000 SGR -999,250 GRST -999.250 SFLU 7.727 DRHO 0,015 NCNb 1773.000 SGR -999.250 GRST -999.250 SFLU 5.301 ORHO 0,050 NCNB 1645.000 SGR -999,250 GRST -999.250 Dk. PTI~ 4700.000 4600.0O0 4500.000 4400:.000 4300.000 4200.000 4100.000 4000.000 ]qO0.O00 MNEMONIC SP GR NPHI FCNL THOR SP GR NPHI ~'CNL THOR SP GR NPHI FCNL TH(JR SP GR NPHI FCNL T lq O R SP GR NPHI I;'CNL SP GR NPHI FCNL SP NPHi ~CNL THf}R SP GR NPHI FCNL THi}R SP GR NPH1 FCNL THQR VALUg 61.969 34.326 424,500 -999,250 -124.063 54 313 37~354 407.750 -999.250 -102,063 60.625 34,375 399.500 -099.250 -I18,063 59,125 32.910 486,250 -q99.250 -66,000 78.000 39.063 395.000 -999,250 -121,500 46,906 ]4,521 475,250 -999,250 -77,750 53.625 34,766 596,500 -999,250 -94,000 62.094 41.699 370,000 -999,250 -78,563 58.969 33.643 388.750 -q99,250 NN EMON IC ILl) SGR RH(}B GR U RAN ILD RHOB GR ORAN i LD SGR RHOB GR ORAN ILD SGR R H 0 B GR URAN ILD SGR RHOB GR ORAN ILD SGR RHOB ORAN ILD SGR RHOB GR ORAN ILD SGR RHOB ORAN ILD SGR RHOB GR ORAN VALUE 5,266 64 438 2:]46 61,969 -999,250 ~. 4:30 53 1,25 54.]13 -999.250 4.523 6~.844 .320 60.625 -999.250 4.750 61.094 2.299 59.125 -999.250 4.828 82.81,3 2.]13 -999 50 3.~03 ~4 250 2:045 46,006 -999,250 5.727 5b.219 2.287 5].625 -999.250 4,445 62,969 2,141 62,094 -999,250 4.242 59,438 2.172 58,969 -999,250 MN EMONiC ILN CALl PUTA 1LM CALl NRAT DT POTA C,AL i NRAT DT P{JTA IL~ CALl NRAT DT POTA CALl NRAT DT POTA ILM CALl NRAT DT POTA ILM CALl NRAT DT P()TA ILM CALl NRAT DT POTA IL~ CALl NRAT DT POTA VALUE NNEMtbN lC VALIJE 5,379 SFLU 5.72] 008 DRH 0.025 I ~598 NCNb 1742.000 107 188 SGR -999,250 -999~250 GRST -999.250 4,035 SFLU 4.402 133.3'75 SGR -999 250 -999.250 GRST -999:250 430 DRHO 0.007 -o 9. so c.sr - 99. so 5,672 12.484 3.438 109.750 -999.250 4,375 14.883 3.902 114.563 -999,250 4,203 12.719 3,547 125,750 -999.250 5.953 14.211 3.602 110.375 -999.250 4,684 14,805 4,070 125.563 -999,250 4.199 15.922 3.576 119.375 -999.250 SFLU 9'008 DRHO 0.021 NCNb 1893.000 SGR -999.250 GRST -999.250 SFLU 3.816 DRHO 0.094 NCNb 1669.000 SGR -999.250 GRST -999.250 SFLU 7,129 DRHO -0.009 NCNb 1838.000 SGR -999.250 GRST -999.250 SFLU 4.047 DRHO 0.000 NCNb 2520.000 SGR -999.250 GRST -999,250 SFLU 5,027 DRHO 0,007 NCNL 1709.000 SGR -999,250 GRSI -999,250 SFLU 4,152 DRHO 0,010 NCNb 1644.000 SGR -999.250 GRST -999,250 DEPTH 3800.000 3700.000 3600.000 3500.000 3400.000 3300. 000 3200.000 3100.000 3000.000 MNEM[]N1C VALUE ~NEM[)NiC VALUE SP -84.625 ILl) 4.461 GR 70.188 8GR 79.563 NPH1 45.947 RH[)B 2.t21 FCNL 1318.750 GR 70.188 THOR -999.250 I/RAN -999.250 SP -103.563 ILD 5.523 GR 60.063 SGR 57.938 NPHi 36.i3] RHOB 2.086 FCNL 384.250 GR 60.063 THOR -999.250 ORAN -999.250 GR NPHI FCNL THOR MN EM~NiC 1LM CALl NRAT DT POTA iLM CALl NRAT DT =81.563 ILD 6.621 ibm 80.563 8GR 76.813 CALl 38.770 RH[)B 2.211 NRAT 363.000 GH 80.563 DT -999.250 URAN -999.250 POT-A SP -91.563 ILD 6.500 GR 66.438 SGR 62.344 CALl NPHI 37.891 RHOB ~.201 NRAT FCNL 434.500 GR 66.438 DT THOR -999.250 URAN -999.250 POTA SP -129.625 ILD 7.543 ILM GR 31.500 SGR 32.719 CALl NPHI 32.861 RHOB 2.025 NRAT P'CNL 464.250 GR 31.500 DT THOR -999.250 URAN -999.250 POTA SP NPHI FCNL THOB -132.625 ILD 7.570 39.906 SGR 3'/.156 38.232 RHOB 2.023 365.500 GR 39.906 -999.250 URAN -999.250 SP -81.56~ ILD 4.438 GR 84.000 SGR 79.!88 NPHI 42.969 RHUB 2.143 PCNL 300.500 GR 84.000 THOR -999.250 [IRAN -999.250 SP -88.063 ILD 7.785 GR 65.500 8GR 69.563 NPH! 41.943 RHOB 2.166 FCNL 309.250 GR 65.500 TH(DR -999.250 URAN -999.250 iLM CALl NRAT DT POTA ILM CALl NRAT DT POTA IbM CALl NRAI DT POTA 8P -106.063 ILD 13.695 IbM GR 51.375 5GR 51.250 CALl NPHI 47.559 RHUB 2.063 NRA~ P'CNL 309.000 GR 5~.{75 DT THOR -999.250 ORAN -999.250 POTA VALUE 4.156 15.023 4.352 141.500 -999.250 5.867 1~.344 .668 132.~50 -999. 50 6.313 15.266 3,893 139.000 -999.25O 6.359 13.313 3.783 122.000 -999.250 7.906 12.828 3.441 151.000 -999.250 7.953 12.367 3.781 152.000 -999.250 3.949 16.766 4.203 139.750 -999.250 6.902 17.172 4.148 136.125 -999.250 13.195 13.469 4.418 166.000 -999.250 MNEMON itC SFLU DRHO NCNb SGR GRST SFLU DRHO NCNb SGR GRST SFLU ~DRHO GRST SFLU DRHO NCNb SGR GRST 8FLU DRHO NCNb SGR GRST SFLU DRHU NCNb SGR GRST SFLU DRHO NCNb 8GR GRST SFLU DRHO NCNb SGR GRST SFLU DRHO NCNL SGR GRST 'VALUE 3.250 o.017 1523.000 -999.250 -999.250 6.535 -0.011 1698.000 9992250 6.059 0 016 1643 ooo -999.250 -999.250 6.398 -0.002 1543.000 -999.250 -999.250 8.414 -0.011 1678.000 -999.250 -999.250 8.711 -0.001 1649.000 -999.250 -999.250 4.074 0.035 1432.000 -999.250 -999.250 6.965 O.O5O 1467.000 -999.250 -999.250 14.023 -0.002 1442.000 -999.250 -999.250 DEPTH 2900. 000 2800.000 2700.000 2670.000 MNEMONIC GR NPHI FCNL THOR SP GR NPH I ~CNL THOR SP GR NPHI FCNL TH~R SP GR NPHi FCNL TH(IR V A L U E -107,063 51.188 45.508 274.000 -999.25O -92.56] 53,031 39,258 34'7 750 -999:250 -100,563 52,250 44.141 323.~50 -999. 50 -50,563 41.656 46,973 273,000 -999.250 MNEMUNiC I L D SGB GR []RAN 1LD SG}4 RHOB GR ORAN ILD SGR RHf.]B GR ORAN ILD SGR GR [}RAN VALUE 29.203 54.719 1,830 51.188 -999,250 11.945 70,375 2,098 53,031 -999~250 14,578 49.469 1,986 52.250 -999,250 37 906 917 41,656 -999,250 MNEMONIC ILM CALl N Rh'r D T POTA' LM ALI R A T DT POTA 1LM PflTA ILM CALl NRAT DT POTA VASUE 20.125 16.828 4.371 203.750 -999.250 1.0.148 19 813 4:04] 137.000 -999.250 12. '773 15 375 4:246 129 000 -999:250 44.906 12 656 42359 56,375 -999,250 M N EMUNIC SFLU DRHO NCN5 SGR GRST SFLU DRHU NCNL SFLU DRHO NCNL GR~ SFLU DRHO NCNL SGR GRST 21.938 0,054 1353.000 -999,250 -999.250 9.984 0,090 1544.000 11.203 0.094 1398'000 -999.250 -999.250 46.000 -0.670 1357.000 -999.250 -999,250 SUMMARY OF DATA RECORD8 NUMBER (]1;~ REC]RDS: I, ]77 LENGTH UF RECORDS: 1014 BITES I.,~, GI'H OF LAST RECtJ~D: 762 BYTES FII.~E TRAILE~ LENGTH: 62 BITES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECtlRD LENGTH: NEXT FILE NAME: EOF 1024 BYTES , ,[ , , * , * , , * * * , , , , TAPE TRAILER I,ENGTH: 132 BYTES TAPE NAME: 61236 SERVICE NAME: EDiT TAPE CONTINUATION NUMBER: 01 NEXT TAPE NAME: C(]MM~NTS: DATE: 80/12/13