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Home My WebLink About180-0137. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU X-07 OA Squeeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 180-013 50-029-20441-00-00 11691 Conductor Surface Intermediate Production Liner 9599 80 2660 10534 1632 10910 20" 13-3/8" 9-5/8" 7" 8926 35 - 115 35 - 2695 34 - 10568 10058 - 11690 35 - 115 35 - 2695 34 - 8639 8237 - 9598 10910 2670 3090 7020 10910 4930 5750 8160 10734 - 10943 4-1/2" 12.6# 13cr80 32 - 9908, 10001 - 10107 8774 - 8954 Structural 4-1/2" Baker S3 Packer 10001, 8189 9820, 10001 8037, 8189 Torin Roschinger Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028313 32 - 8112, 8189 - 8277 OA at surface Pump 7.5 gallons of Wellock. Final pressure = 0-psi 137 138 293 343 3030 5585 1429 1723 231 245 322-564 13b. Pools active after work:Prudhoe Oil 4-1/2" TIW HBBP-R Packer 9820, 8037 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Kayla Junke at 9:59 am, May 17, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.05.16 16:17:59 -08'00' Torin Roschinger (4662) WCB 1-8-2024 RBDMS JSB 051823 ACTIVITY DATE SUMMARY 1/26/2023 T/I/O = SSV/2050/0. Temp = SI. Bleed IAP < 1000 psi (eval IAxOA). ALP= 2050 psi, open @ CV. IA FL @ 8443' ( sta # 2, SO, 452 bbls). OA cemented to surface. Upon arrival OPS holding open bleed on OA (gas). Bled IAP to X-08 production (110') from 2050 psi to 300 psi in 4 hrs. OA stopped bleeding gas, once IAP decreased to 1830 psi. SI OA bleed & installed heater on OA to elimnate JT effect, monitored during IA bleed. OAP increased 20 psi in 3 hrs during IA bleed. Monitored for 30 min. WHP's & IA FL unchanged. Upon departure RD heater & released. Final WHP's = SSV/850/20. SV, WV, SSV = C. IA, OA = OTG. 17:00 1/29/2023 T/I/O = 250/1440/20. Temp = 169°. PPPOT-IC prep for Wellock (eval IAxOA). ALP = online. Upon arrival OPS had heater installed. OA has 3" CV installed @ 9:00 position & 3" blind w/ 1/2" alimite @ 3:00 positon. Bled OAP from 10 psi to 0 psi < 1 min. Final WHP's = 250/1440/0+ PPPOT- IC: Stung into test port (1300 psi). Bled void to 0 psi (gas/fluid). Monitor for 10 min, no increase in pressure. Pressured void to 3500 psi for 30 min test, first 15 min lost 200 psi, second 15 min lost 50 psi (PASS). Bled void to 0 psi. 2/1/2023 ***WELL FLOWING ON ARRIVAL*** T/I/O/OO=250/0/0/0 Pre Wellock. Holding and open bleed in the OA valve, R/D 3' Companion blind, removed 3' McEvoy VR plug and RU OA integral and block valve. Holding Bleed on Comp side, RD 3' McEvoy valve and RU integral and block valve. ***Job Complete*** All parts removed are left in the well house. Final WHPS=200/1400/00. 2/5/2023 T/I/O = 230/1480/20. Temp = 147°. OA WellLock Squeeze (eval IAxOA). ALP = 1480 psi, SI @ CV. OA cemented to surface. Removed 1502 cap & block valve, re- installed hardline 90°. Pumped 4 gallons of WellLock into OA for a flush, 3 gallons of returns to metal bucket. Pumped 2.5 gallons of WellLock into OA in 8 hrs. OAP decreased to 1260 psi @ the 0900 position and 1100 psi @ the 0300 position. Increased OAP to 1480 psi with lift gas from X-07 AL line. Heater installed in well house, man door ajar. Final WHPs = 230/1480/1480. SV = C. WV, SSV, MV = O. IA = OTG. 19:30 2/6/2023 T/I/O = 230/1410/900. Temp = 147°. WHP's (post Wellock). ALP = 1480 psi, SI @ CV. OA cemented to surface. Heater is working and installed @ 6:00 position. Wellock sample is not cured. Increased OAP @ the 3:00 position CV by 450 psi with lift gas from X-07 AL line. OAP decreased 100 psi immediately. Final WHP's = 230/1410/1250. SV = C. WV, SSV, MV = O. IA & OA = OTG. 14:30 2/7/2023 T/I/O = 230/1410/600. Temp = 147°. WHPs (post wellock). ALP = 1480 psi, AL SI @ csaing valve. OA cemented to surface. Heater installed & working properly. Wellock sample is not cured. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00 Daily Report of Well Operations PBU X-07 @g Wellock sample is not cured @ Heater installed in well house, man door ajar Wellock sample is not cured Pumped 4 gallons of WellLock into OA for a flush, 3 gallons ofg returns to metal bucket. Pumped 2.5 gallons of WellLock into OA in 8 hrs Daily Report of Well Operations PBU X-07 2/8/2023 T/I/O = 340/1390/560. Temp = 166°. WHPs (post wellock). ALP = 1480 psi, AL SI @ csaing valve. OA cemented to surface. Heater installed & working properly. Wellock sample not completely cured, but curing properly. Accumulators removed from OA. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:00. 2/8/2023 T/I/O = 300/1400/600. Temp = 164°. WHPs (post wellock). ALP = 1400 psi, AL SI @ casing valve. OA cemented to surface. Heater installed & working properly. Wellock sample not completely cured, but curing properly. SV = C. WV, SSV, MV = O. IA, OA = OTG. 08:45. 2/9/2023 T/I/O = 300/1400/600. Temp = 164°. WHPs (post wellock). ALP = 1400 psi, AL SI @ casing valve. OA cemented to surface. Heater installed & working properly. Wellock samples are completely cured. Released heater. SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:30 2/10/2023 T/I/O = 280/1400/unknown. Temp = 164*. WHP's (post wellock). ALP = 1400 psi, online. OA cemented to surface. Heater was released 2-9-23. Wellock samples are completely cured. Gauge and 90* harline on 09:00 position on OA are wellocked off, pressure unknown. Gauge on 3:00 side reading 400 psi, small amount of dark fluid at surface. SV = C. WV, SSV = O. IA & OA = OTG. 13:30. 2/16/2023 T/I/O = 260/450/20. Temp = 168°. Eval well Lock. ALP = 1500 psi, online. Heater in wellhouse. Bled OAP to 0 psi to bucket on 9:00 side ~5 sec. 1/2 teaspoon of uncured well lock came out of needle valve, followed by foamy dark fluid. Replaced gauge. 3:00 side 1/2 teaspoon of foamy well lock came out of needle valve. Monitor for 30 min. OAP increased to 20 psi on 9:00 side, no increase on 3:00 side. Final WHPs = 260/450/20. SV = C. WV, SSV, MV = O. IA, OA = OTG. 00:30. 2/20/2023 T/I/O = 270/1410/0. Temp = 166°. WHPs (post wellock). ALP = 1410 psi, online. Removed gauges to view wellock in needle valve. Does not appear to be set up. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:00. 2/21/2023 T/I/O = 270/1410/0. Temp = 166°. Increase OAP (post wellock). ALP = 1410 psi, online. Wellock starting to set up in needle valves. Increased OAP on 3:00 & 9:00 sides with lift gas to 1400 psi. 3:00 & 9:00 side did not seem to be in communication with each other when pressuring up. Monitored for 30 min. OAP decreased 10 psi. Final WHPs = 270/1410/1390 SV = C. WV, SSV, MV = O. IA, OA = OTG. 00:30. 2/23/2023 T/I/O = 250/1420/1300. Temp = 165°. WHP's (eval Wellock). ALP = 1420 psi, open @ CV. Heater working & installed w/ WH door ajar. Wellock is starting to set up but not fully cured. Cracked needle valve open @ 9:00 side, Wellock looked foamy. Did not increase OAP. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:430 ) Wellock is starting to set up but@ not fully cured. ) Does not appear to be set up @g Wellock sample not completely cured, but curing properly @g Wellock samples are completely cured. Released heater Daily Report of Well Operations PBU X-07 2/27/2023 T/I/O = 250/1420/1000. Temp = 161°. WHP's (post Wellock).. ALP = 1420 psi, open @ CV. OA cemented to surface. Heater working & installed w/ WH door ajar. Upon arrival Wellock was set up in the guage & jewlery @ 3:00 side, installed new anolog guage @ 3:00 side. Wellock @ 9:00 side seems to have a liquid state to it. Noticed when opening needle valve on 3:00 & 9:00 side gas was leaking by. Monitored for 10 min after reinstalling anolog guages. OAP increased to 490 psi on 3:00 & 9:00 side. Did not increase OAP w/ ligt gas. Final WHP's = 250/1420/490. SV = C. WV, SSV, MV = O. IA, OA = OTG. 10:50 3/1/2023 T/I/O = 250/1420/500. Temp = 162°. WHP's (post Wellock). ALP = 1420 psi, open @ CV. OA cemented to surface. Heater working & installed w/ WH door ajar. Wellock @ 3:00 side seems to be set up but leaking gas by. Wellock @ 9:00 has a lquid state to it & is also leaking gas by, guage repressure to 420 psi after reinstalling. Did not increase OA. Final WHP's = 250/1420/420. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:15 3/3/2023 T/I/O = 280/1420/420. Temp = 141°. WHPs (post wellock). ALP = 1420 psi open @ CV. Heater working & installed w/ WH door open. Wellock @ 03:00 position has gas leaking by. Wellock @ 09:00 position also has gas leaking by. Guage @ 09:00 position reading 420 psi, and guage @ 03:00 position reading 0 psi after 10 min monitor. Final WHPs 280/1420/420. SV = C. WV, SSV, MV = O. IA, OA = OTG. 3/9/2023 T/I/O = SSV/1960/560. Temp = SI. Bleed IAP (pre Wellock). AL open @ CV. OA CV's replaced w/ 2" hardline. IA FL @ 8443' (sta # 2 SO). Bled IAP to OT to 5 psi in 7 hrs 30 min. Bled OAP to 0 psi (1/4 cup of uncured Wellock). Held open bleed for 7 hrs 30 min. IAP unchanged, OAP increased 280 psi. Final WHPs = SSV/5/280. SV, WV, SSV = C. MV = O. IA = OTG. 05:00 3/9/2023 T/I/O = SSV/5/280. Temp = SI. WHPs (eval wellock). AL open @ CV. Heater installed with doors closed, vent on ceiling of wellhouse is open. SV, SSV, WV = C. MV = O. IA, OA = OTG. 09:00 3/11/2023 T/I/O = SSV/6/250. Temp = SI. Re-treat OA w/ Wellock (eval IAxOA). AL SI @ CV. Bleed IAP to 0+ psi, hold open bleed. Bleed OAP to 0 psi in 10 seconds (gas fluid). RU pump to OA and pumped ~1 gal of wellock. Held 2500 psi on OA for 1 hr. Rigged off well, left 1000 psi in OAP. SV, WV, SSV = C. MV = O. IA & OA = OTG. 13:45. 3/13/2023 T/I/O = SSV/0/200. Temp = SI. Eval Wellock. AL SI @ CV. Heater working properly. OAP @ 08:30 = 560 psi. Wellock soft but will not pour. OAP decreased 800 psi in 10 hrs 30 min. SV, WV, SSV = C. MV = O. IA, OA = OTG. 00:30 3/14/2023 T/I/O = SSV/0/50. Temp = SI. Eval Wellock. AL SI @ CV. Heater working properly. OAP @ 08:30 = 50 psi. Wellock soft but will not pour. OAP decreased 150 psi overnight. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 3/15/2023 T/I/O = SSV/0/50. Temp = SI. Eval Wellock. AL SI @ CV. Heater working properly. OAP @ 08:30 = 20 psi. Wellock soft but will not pour. OAP unchanged overnight. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00 gg jy@ Wellock @ 9:00 side seems to have a liquid state to it RU pump to OA and pumped ~1 gal of wellock Re-treat OA w/ Wellock )@ Wellock @ 03:00 position has gasg@ leaking by. Wellock @ 09:00 position also has gas leaking by. @ gj Wellock @ 3:00 side seems to be set up but leaking gas by. Wellock @ 9:00 has a@ lquid state to it & is also leaking gas by Daily Report of Well Operations PBU X-07 3/15/2023 T/I/O = SSV/0/300. Temp = SI. Monitor Well Lock (WIE request). AL SI @ CV. Heater off and well house door closed upon arrival. OAP @ 03:00 = 0 psi. OAP @ 09:00 = 340 psi. OAP increased 250 psi since this morning. Well Lock sample was hard. Functioning heater installed and well house door left open. SV, WV, SSV = C. MV = O. IA & OA = OTG. 13:30 3/16/2023 T/I/O = SSV/0/50. Temp = SI. Eval Wellock. AL SI @ CV. Heater working properly. OAP @ 09:00 = 240 psi. Wellock set up. OAP unchanged overnight. SV, WV, SSV = C. MV = O. IA, OA = OTG. 02:30 3/17/2023 SSV/0+/250. Temp = SI. WHP's (post Wellock). ALP = 1960 pis, SI @ CV. OA cemented to surface. Heater installed & working w/ WH door ajar. Wellock sample & bucket are set up but not fully cured. Needle valves on 1502 caps @ 3:00 & 9:00 position seem to have wellock set up in them, wont function. Did not increased OAP. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:30 3/18/2023 SSV/0+/220. Temp = SI. WHP's (post Wellock). ALP = 1960 pis, SI @ CV. OA cemented to surface. Heater installed & working w/ WH door ajar. OAP decreased 30 psi since 03/17/23. Wellock sample & bucket are set up but not fully cured. Needle valves on 1502 caps @ 3:00 & 9:00 position seem to have wellock set up in them, wont function. Did not increased OAP. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:40 3/19/2023 T/I/O = SSV/0/0. Temp = SI. Post Wellock. ALP = SI @ CV. Wellock sample firm, not completely set up. Heater installed in wellhouse and working properly with door ajar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:00. 3/19/2023 T/I/O = SSV/0/0. Temp = SI. WHPs (Post Wellock). ALP = SI @ CV. Wellock sample firm, not completely set up. Heater installed in wellhouse and working properly with door ajar. Moved Wellock samples closer to heat source to have better indirect heat. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:30. 3/19/2023 SSV/0+/150. Temp = SI. WHP's (post Wellock). ALP = 1960 pis, SI @ CV. OA cemented to surface. Heater installed & working w/ WH door ajar. Wellock sample & bucket are set up but not fully cured. Did not increased OAP. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:30 3/21/2023 T/I/O = SSV/0/0. Eval Wellock. ALP = SI @ CV. Wellock samples setting up and close to being cured. Removed gauge on 3:00 & 9:00 sides on OA and inspected, Wellock appears set up in jewelry. Replaced gauge on 9:00 side. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30. 3/21/2023 T/I/O = SSV/0/0. Temp = SI. Eval wellock. Wellock samples in wellhouse appear to be set-up and cured. Wellock is set up in 1502 caps and jewelry. Gauge was replaced on the OA at the 09:00 side showing 150 psi, removed to verify pressure (0 psi). Replaced guage with good guage. Heater is working propperly. SV, WV, SSV = C. MV = O. IA & OA = OTG. 12:35 gj Wellock sample & bucket are set up but not fully cured. @ Wellock sample & bucket are set up but not fully cured. @ Well Lock sample was hard. @ Wellock sample & bucket are set up but not fully cured. Wellock sample firm, not completely set up. Wellock samples in wellhouse appear to be set-up and cured. Wellock is set up in 1502 caps and jewelry Daily Report of Well Operations PBU X-07 3/23/2023 T/I/O = SSV/0+/150. Temp = SI. WHP's (post Wellock). ALP = 1960 psi, SI @ CV. OA cemented to surface. Heater working & installed w/ WH door ajar. Wellock sample & bucket seem to be fully cured. Wellock set up in jewelry @ 3:00 & 9:00 side, unable to close need valves. Removed analog gauge @ 9:00 side to verify 0 psi. Reinstalled analog gauge will monitor next day to see repressurization on OA @ 9:00 side. Final WHP¿s = SSV/0+/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:50 3/24/2023 T/I/O = SSV/10/200. Temp = SI. WHP's (post Wellock). ALP = 1960 psi SI @ CV. OA cemented to surface. Wellock sample & bucket are fully cured. Cleaned out Wellock out of 1502 caps & installed new needle valves @ 3:00 & 9:00 sides. Installed OPS gauge @ 9:00 side. Heater trunk removed & released. Final WHP's = SSV/10/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:20 3/25/2023 T/I/O = SSV/200/40. Temp = SI. WHP's (post Wellock). ALP = 1960 psi, SI @ CV. OA cemented to surface. OAP increased 40 psi since last monitor done on 3/24/23. Removed 1502 cap @ 9:00 side, gassed up Wellock seems to be slowly coming out of OA. Rinstalled 1502 cap & installed Anolog Gauge @ 9:00 side. Wellock is not fully cured (OPS gauge is removed). Ordered heater upon departure. Final WHP's SSV/200/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:40 3/27/2023 T/I/O = SSV/10/100. Temp = SI. WHP's (post Wellock). ALP = 1960 psi, SI @ CV. OA cemented to surface. Heater installed & working w/ WH door ajar. Wellock is not fully cured. Wellock @ 9:00 side seems to be gassed up w/ a liquid state of wellock. Conditions of Wellock @ 9:00 side seem to have gotten worse since 3/25/23. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:30 3/28/2023 T/I/O = SSV/10/100. Temp = SI. WHP's (post Wellock). ALP = 1960 psi, SI @ CV. OA cemented to surface. Heater working & installed w/ WH door ajar. Wellock is not fully cured. Wellock @ 9:00 side is still gassed up & has a liquid state of Wellock. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:50 4/1/2023 T/I/O = SSV/10/150. Temp = SI. WHP's (post Wellock). ALP = 1960 psi, SI @ CV. OA cemented to surface. Heater working & installed w/ WH door ajar. Wellock is not fully cured. Wellock @ 9:00 side is still gassed up & has a liquid state of Wellock. Sample taken. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:00 4/2/2023 T/I/O = SSV/10/240. Temp = SI. WHP's (eval Wellock). ALP = 1960 psi, SI @ CV. OA cemented to surface. Heater working & installed w/ WH door ajar. Wellock is not fully cured. IA @ 9:00 side had a foamy liquid substance. Bled OAP to 0 psi in 1 sec. Monitored for 30 min. OAP increased to 220 psi. Final WHPs = SSV/10/220. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:00 yg W ellock is not fully cured @ Wellockgj sample & bucket seem to be fully cured. Wellock set up in jewelry @ 3:00 & 9:00y side, unable to close need valves. g j Wellock @ 9:00 side is still gassed up & has a liquid state of Wellock @ Wellock isgj not fully cured. Wellock @ 9:00 side is still gassed up & has a liquid state of Wellock. @ Wellock is not gj fully cured. Wellock @ 9:00 side seems to be gassed up w/ a liquid state of wellock.y@ g Conditions of Wellock @ 9:00 side seem to have gotten worse since 3/25/23 @ Wellock isg not fully cured. IA @ 9:00 side had a foamy liquid substance Daily Report of Well Operations PBU X-07 4/15/2023 T/I/O = 350/1960/320. Temp = SI. Assist Ops w/ POP (post Wellock). ALP = 2000 psi, SI @ CV. IA FL @ 8443' (sta # 2, SO). OA cemented to surface. Bled OAP as needed for POP returning gas & ~1/8 cup of fluid. OAP increased 310 psi. Ops unable to flow well due to faulty flow control valve. Stacked TP to 1500 psi. Bled IAP to production from 1960 psi to 780 psi in in 6 hrs. Monitored for 30 min. IAP, OAP, and IA FL unchanged. Final WHPs = 1500/780/310. SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:30 4/26/2023 T/I/O = 1500/800/350. Temp = SI. Manwatch for POP (post Wellock). ALP = 1950 psi, SI @ CV. IA FL @ 8443' (sta # 2, SO, 452 bbls). OA cemented to surface. Heater working & installed w/ WH door ajar. Wellock @ 3:00 & 9:00 position is gased up & has a liquid state to it. Currently attempting to POP. Cont on WSR 4/27/23 4/27/2023 T/I/O=195/530/200 Hot Oil Treatment (HOT OIL TBG WASH) Pump down IA w/ 15 bbls MEOH. Pump down TBG w/ 3 bbls 60/40, Pumped 120 bbls of 190* crude down TBG/FL. Wing found to be partially open after pumping 120 bbls. Wing fully shut and pumped an additional 163 bbls of 190* crude to confirm that well has been displaced down to the top perfs, per Pad Op. Valve Positions - SV/WV/SSV/AL= Closed, MV= Open, IA/OA= OTG FWHPs= 480/1840/0 4/27/2023 T/I/O = 220/1940/340. Temp = 50°. Assist Ops w/ POP, Bleed IAP (Post Wellock). ALP = 1980 psi, SI @ CV. OA cemented to surface. SI WV uppon Arrival. Ops Having issues bringing well online, freeze protect ordered. IA FL @ 7905' (538' above sta #2 SO). Bled IAP to production from 1940 psi to 750 psi in 3 hrs. Monitored for 30 min. IAP & IA FL unchanged. Final WHPs = 220 /750/340. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:00 **WSR continued from 4/27/23** 5/6/2023 ***WELL S/I ON ARRIVAL***(gas lift-rate) R/U HES 759 ***CONTINUE ON 5-7-23 WSR*** 5/7/2023 ***CONTINUE ON FROM 5-6-23 WSR***(gas lift- for rate) RAN KJ, 2' x 1-7/8" STEM, 3.70" CENT, 1-3/4" SAMPLE BLR TO IBP @ 10,931' SLM (empty) SET 4-1/2" WHIDDON CATCHER SUB IN SWN NIPPLE @ 10,063' SLM (10,063' MD) PULLED RK-OGLV FROM STA.# 2 @ 8,443' MD PULLED RK-LGLV FROM STA.# 3 @ 6,612' MD PULLED RK-LGLV FROM STA.# 4 @ 4,873' MD PULLED RK-LGLV FROM STA.# 5 @ 3,004' MD SET 1-1/2" RK-LGLV(16/64" ports, 1603# tro) IN STA #5 @ 3,004' MD SET 1-1/2" RK-LGLV(16/64" ports, 1598# tro) IN STA #4 @ 4,873' MD SET 1-1/2" RK-LGLV(16/64" ports, 1587# tro) IN STA #3 @ 6,612' MD PUMPED 15BBL METH TOTE W/ TRIPLEX SET 1-1/2" RK-OGLV(28/64" ports) IN STA #2 @ 8,443' MD PULL 4-1/2" WCS FROM SWN NIPPLE @ 10,063' SLM (10,063' MD) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** ) Wellock @ 3:00 & 9:00 position is gasedgj@ up & has a liquid state to it. Currently attempting to POP Daily Report of Well Operations PBU X-07 5/8/2023 T/I/O = 1100/1100/310. Temp = SI. Assist Ops w/ POP (post Wellock). ALP = 1950 psi, SI @ CV. IA FL @ 2790' (214' above sta #5, DOME). OA cemented to surface. Bled OAP as needed for POP returning gas & a tiny amount of fluid. OAP increased 310 psi. Ops in the process of stacking out well. Bled OAP to 0 psi upon departure. T FL before departure @ 3432' (1441' above sta #4, DOME). Final WHPs = 1220/1500/0. SV, WV = C. SSV, MV = O. IA, OA = OTG. 05:30 5/8/2023 T/I/O = 1850/1850/150. Temp = SI. Manwatch for POP ( post well lock). ALP = 1900 psi, Open @ CV. OA cemented to surface. T FL @ 5140, (267' below sta # 4 Dome). Bled OAP to 0 psi in < 1 min, (gas/fluid) prior to opening WV. Monitored for 2 hrs. IAP decreased 130 psi, OAP increased 50 psi post POP. Ops put well in low pressure. IA FL @ 8443' ( sta # 2, SO). Ops request to keep on monitor, (still under eval). Final WHPs = 300/1720/50. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:00 5/9/2023 T/I/O = 2500/1720/50. Temp = 142*. Monitor WHP's (post Wellock). ALP = 1840 psi, online. OA cemented to surface w/ Wellock top. OAP unchanged since 5-8-23. SV = C. WV, SSV, MV = O. IA & OA = OTG. 16:30 5/9/2023 RD integrals. RU OA & tapped blind flange. Torqued. RDMO. 5/10/2023 T/I/O = 280/1500/0. Temp = 164°. WHPs (Post Wellock). ALP = 1500 psi, online. OA cemented to surface. OAP unchanged since last shift. SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:00 5/10/2023 T/I/O = 270/1500/0. Temp = 164°. WHPs (Post Wellock). ALP = 1520 psi, online. OA cemented to surface. OAP decreased 50 psi from 5-09-23. SV = C. WV, SSV, MV = O. IA, OA = OTG. 05:00 5/11/2023 T/I/O = 280/1520/0+. Temp = 165°. WHPs (Post Wellock). ALP = 1550 psi, online. OA cemented to surface. OAP unchanged since last shift. SV = C. WV, SSV, MV = C. IA, OA = OTG. 17:00 5/11/2023 T/I/O = 260/1520/0. Temp = 165°. WHPs (Post Wellock). ALP = 1550 psi, online. OA cemented to surface. OAP unchanged from 05-10-23 SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:30 5/12/2023 T/I/O = 270/1540/0. Temp = 164*. ALP = 1560 psi, online. OAPcemented to surface. OAP unchanged, IAP increased 40 psi from 5-10-23. SV = C. WV, SSV, MV = O. IA & OA = OTG. 17:30 5/13/2023 T/I/O = 280/1500/0. Temp = 155°. WHPs (Post Wellock). ALP = 1500 psi, online. OA cemented to surface. OAP unchanged since 5-10-23. SV = C. WV, SSV, MV = O. IA, OA = OTG. 02:00 5/13/2023 T/I/O = 250/1530/0. Temp = 165°. WHP's (post Wellock). ALP = 1530 psi, online. OA cemented to surface. OAP unchanged since 5-10-23. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00 5/14/2023 T/I/O = 250/1530/0. Temp = 165°. WHP's (post Wellock). ALP = 1530 psi, online OA cemented to surface. OAP unchanged since 5-10-23. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:15 5/15/2023 T/I/O = 250/1530/0. Temp = 168*. Monitor WHP's (Post Wellock). ALP = 1580 psi, online. OA cemented/Wellock to surface. OAP uncahnged since 5-10-23. SV = C. WV, SSV, MV = O. IA & OA = OTG. 17:00. () OAP uncahnged since 5-10-23 () OAP unchanged from 05-10-23 Ops put well in low pressure. () OAP unchanged since 5-10-23 () OAP decreased 50 psi from 5-09-23 () OAP unchanged since 5-10-23 () OAP unchanged since last shift ( OAP unchanged since last shift () OAP unchanged since 5-10-23. 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Friday, April 28, 2023 1:33 PM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Oliver Sternicki; Stan Golis; Torin Roschinger Subject:UPDATE UNDER EVALUATION: Producer X-07 (PTD #1800130) Wellock re-squeeze complete Mr. Regg, Producer X‐07 (PTD #1800130) has not yet been put on production after the most recent wellock treatment performed on 03/11/23. The well remained shut in during water washes in early April, repairs to the gas lift flow control valve and slickline gas lift valve work. At this time, the 28 day Under Evaluation clock is being reset to allow for online monitoring to evaluate the performance of the latest wellock treatment to resolve IAxOA. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity Sent: Saturday, April 1, 2023 4:27 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X‐07 (PTD #1800130) Wellock re‐squeeze complete Mr. Regg, Producer X‐07 (PTD #1800130) wellock re‐treatment was pumped successfully on 03/11/23 and appears to have cured. At this time, the well is classified as UNDER EVALUATION and can be put online for a 28 day monitoring period to evaluate if the sustained casing pressure OA has been resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, March 10, 2023 12:41 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB PBU X-07PTD 1800130 J. Regg; 5/1/2023  2 Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Producer X‐07 (PTD #1800130) will re‐treat OA with Well Lock Mr. Regg, During the extended monitoring period, there was still a small volume of Well Lock that did not cure. The uncured Well Lock has been bled off the Outer Annulus and the Inner Annulus Pressure has been bled in preparation to re‐treat the Outer Annulus with Well Lock. The well will be classified as NOT OPERABLE and will remain shut‐in until the re‐treat has cured. Plan Forward: 1. DHD: Re‐treat OA with Well Lock 2. DHD: Monitor treatment, verify Well Lock has cured 3. Well Integrity: Re‐classify to Under Evaluation to POP and monitor Please respond with any questions or concerns. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Thursday, February 23, 2023 11:12 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: [EXTERNAL] RE: UPDATE UNDER EVALUATION: Producer X‐07 (PTD #1800130) Sustained casing pressure OA OK to extend the monitoring period 14 days. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, February 23, 2023 10:49 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Producer X‐07 (PTD #1800130) Sustained casing pressure OA CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 Mr. Regg, Producer X‐07 (PTD #1800130) well lock treatment was pumped on 02/05/23 to resolve IAxOA communication. On 02/16/23 & 02/20/23, the OA was successfully bled to 0 psi with pressure left on the IA which indicates the IAxOA communication has been resolved. During both bleeds however, trace amounts of uncured well lock returns were observed in the OA. With permission, I would like to extend the Under Evaluation period for an additional 14 days for continued monitoring to allow any remaining product to fully cure. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity Sent: Friday, January 27, 2023 4:44 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X‐07 (PTD #1800130) Sustained casing pressure OA Mr. Regg, Producer X‐07 (PTD #1800130) OA was reported by operations to be 1452 psi over NOL on 01/26/23 during an unplanned shutdown. The IA & OA pressures were bled down prior to well restart and it is suspected that the previous well lock treatment on the OA has failed. At this time, the well is classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Pack‐off testing IC 2. Well Integrity: Evaluate further well lock treatment Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity Sent: Monday, September 12, 2022 1:55 PM CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 4 To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer X‐07 (PTD #1800130) Monitor post‐Well Lock Mr. Regg, Producer X‐07 (PTD #1800130) was put on production on 08/27/22. During the online period, the OA has remained at or near zero with no OA re‐pressurization. At this time, the well is classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, August 22, 2022 2:37 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer X‐07 (PTD #1800130) POP & Monitor post‐Well Lock Mr. Regg, Producer X‐07 (PTD #1800130) had an OA down squeeze with Well Lock on 08/01/22 in accordance with Sundry 322‐ 359. The Well Lock has cured and the well is ready to be POP’d. The well is now classified as UNDER EVALUATION to monitor for OA re‐pressurization. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 22, 2022 8:26 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Producer X‐07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X‐07 (PTD #1800130) has been secured with a tubing tail plug and a passing CMIT‐TxIA in preparation for the upcoming OA squeeze job to repair OA repressurization. The well is now classified as NOT OPERABLE. 5 Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer WIC Office: (907) 659‐5102 Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity Sent: Monday, July 11, 2022 3:16 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Producer X‐07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X‐07 (PTD #1800130) OA pressure remains near 0 psi while the well is online and warm. Sundry approval for well lock treatment is being processed with AOGCC. The well can remain online as the Under Evaluation period is being extended for an additional 14 days until the sundry is approved. At that time the well will be secured, and pressure tested prior to well lock. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, June 13, 2022 4:53 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer X‐07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X‐07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 06/11/22. The reported pressure was 1016 psi. The X‐07 OA was cemented to surface during a RWO in 2006, in part to repair IAxOA communication. When the OA exceeded MOASP on 6/11/22, the well had recently been shut‐in and was cooling. It is suspected that when the well cools down a micro annulus in the cement allows pressure communication between the IA and OA. The well will be classified as UNDER EVALUATION and is on the 28‐day clock for diagnostics and attempted repair of the OA repressurization. Plan forward: 1. DHD: PPPOT‐IC 6 2. FB: CMIT‐TxIA 3. DHD: OA wellock squeeze 4. DHD/ Ops: Cycle well on/off, monitor for OA repress Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, March 24, 2022 2:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer X‐07 (PTD #1800130) Passed PPPOT‐IC & OART Mr. Regg, Producer X‐07 (PTD # 1800130) passed a PPPOT‐IC to 3500 psi on 03/07/22. The OA pressure was bled to 0 psi on 03/07/22 to start an OA re‐pressurization test. During subsequent monitoring, the OAP BUR was quantified at ~18 psi/day which is manageable by periodic bleeds and indicates the rapid OA MOASP excursion was in fact due to the introduction of cold lift gas. The well will now be classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, March 5, 2022 4:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X‐07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X‐07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 03/04/22. The reported pressure was 1,050 psi. The OA is cemented to surface via RWO in 2006. When the OA MOASP excursion transpired, the well was temporarily receiving ambient temperature lift gas from the FS3 tie in. It is suspected that the introduction of the cold lift gas caused the casing tubulars to contract and intermittently release pressure from a micro‐annulus in the 7 OA cement. The OA pressure was bled off and as the lift gas warmed up, the re‐pressurization ceased. The well will be classified as UNDER EVALUATION and is on the 28‐day clock for diagnostics to ensure competent barriers. Plan forward: 1. DHD: PPPOT‐IC 2. DHD: Outer Annulus Re‐pressurization Test (OART) 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. 8 While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Date:Monday, March 7, 2022 10:49:39 AM Attachments:image001.png X-07.pdf Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, March 5, 2022 4:23 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 03/04/22. The reported pressure was 1,050 psi. The OA is cemented to surface via RWO in 2006. When the OA MOASP excursion transpired, the well was temporarily receiving ambient temperature lift gas from the FS3 tie in. It is suspected that the introduction of the cold lift gas caused the casing tubulars to contract and intermittently release pressure from a micro-annulus in the OA cement. The OA pressure was bled off and as the lift gas warmed up, the re-pressurization ceased. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics to ensure competent barriers. Plan forward: 1. DHD: PPPOT-IC 2. DHD: Outer Annulus Re-pressurization Test (OART) 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: Producer X-07 (PTD #1800130) Sustained casing pressure OA Date:Thursday, February 23, 2023 11:15:24 AM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (OGC) Sent: Thursday, February 23, 2023 11:12 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATION: Producer X-07 (PTD #1800130) Sustained casing pressure OA OK to extend the monitoring period 14 days. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, February 23, 2023 10:49 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Producer X-07 (PTD #1800130) Sustained casing pressure OA Mr. Regg, Producer X-07 (PTD #1800130) well lock treatment was pumped on 02/05/23 to resolve IAxOA communication. On 02/16/23 & 02/20/23, the OA was successfully bled to 0 psi with pressure left on the IA which indicates the IAxOA communication has been resolved. During both bleeds however, trace amounts of uncured well lock returns were observed in the OA. With permission, I would like to extend the Under Evaluation period for an additional 14 days for continued monitoring to allow any remaining product to fully cure. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Friday, January 27, 2023 4:44 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) Sustained casing pressure OA Mr. Regg, Producer X-07 (PTD #1800130) OA was reported by operations to be 1452 psi over NOL on 01/26/23 during an unplanned shutdown. The IA & OA pressures were bled down prior to well restart and it is suspected that the previous well lock treatment on the OA has failed. At this time, the well is classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Pack-off testing IC 2. Well Integrity: Evaluate further well lock treatment Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Monday, September 12, 2022 1:55 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer X-07 (PTD #1800130) Monitor post-Well Lock Mr. Regg, Producer X-07 (PTD #1800130) was put on production on 08/27/22. During the online period, the OA has remained at or near zero with no OA re-pressurization. At this time, the well is classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, August 22, 2022 2:37 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) POP & Monitor post-Well Lock Mr. Regg, Producer X-07 (PTD #1800130) had an OA down squeeze with Well Lock on 08/01/22 in accordance with Sundry 322-359. The Well Lock has cured and the well is ready to be POP’d. The well is now classified as UNDER EVALUATION to monitor for OA re-pressurization. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 22, 2022 8:26 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) has been secured with a tubing tail plug and a passing CMIT-TxIA in preparation for the upcoming OA squeeze job to repair OA repressurization. The well is now classified as NOT OPERABLE. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer WIC Office: (907) 659-5102 Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity Sent: Monday, July 11, 2022 3:16 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) OA pressure remains near 0 psi while the well is online and warm. Sundry approval for well lock treatment is being processed with AOGCC. The well can remain online as the Under Evaluation period is being extended for an additional 14 days until the sundry is approved. At that time the well will be secured, and pressure tested prior to well lock. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, June 13, 2022 4:53 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 06/11/22. The reported pressure was 1016 psi. The X-07 OA was cemented to surface during a RWO in 2006, in part to repair IAxOA communication. When the OA exceeded MOASP on 6/11/22, the well had recently been shut-in and was cooling. It is suspected that when the well cools down a micro annulus in the cement allows pressure communication between the IA and OA. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics and attempted repair of the OA repressurization. Plan forward: 1. DHD: PPPOT-IC 2. FB: CMIT-TxIA 3. DHD: OA wellock squeeze 4. DHD/ Ops: Cycle well on/off, monitor for OA repress Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, March 24, 2022 2:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer X-07 (PTD #1800130) Passed PPPOT-IC & OART Mr. Regg, Producer X-07 (PTD # 1800130) passed a PPPOT-IC to 3500 psi on 03/07/22. The OA pressure was bled to 0 psi on 03/07/22 to start an OA re-pressurization test. During subsequent monitoring, the OAP BUR was quantified at ~18 psi/day which is manageable by periodic bleeds and indicates the rapid OA MOASP excursion was in fact due to the introduction of cold lift gas. The well will now be classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, March 5, 2022 4:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 03/04/22. The reported pressure was 1,050 psi. The OA is cemented to surface via RWO in 2006. When the OA MOASP excursion transpired, the well was temporarily receiving ambient temperature lift gas from the FS3 tie in. It is suspected that the introduction of the cold lift gas caused the casing tubulars to contract and intermittently release pressure from a micro-annulus in the OA cement. The OA pressure was bled off and as the lift gas warmed up, the re-pressurization ceased. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics to ensure competent barriers. Plan forward: 1. DHD: PPPOT-IC 2. DHD: Outer Annulus Re-pressurization Test (OART) 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer X-07 (PTD #1800130) Sustained casing pressure OA Date:Monday, January 30, 2023 8:42:05 AM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, January 27, 2023 4:44 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) Sustained casing pressure OA Mr. Regg, Producer X-07 (PTD #1800130) OA was reported by operations to be 1452 psi over NOL on 01/26/23 during an unplanned shutdown. The IA & OA pressures were bled down prior to well restart and it is suspected that the previous well lock treatment on the OA has failed. At this time, the well is classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Pack-off testing IC 2. Well Integrity: Evaluate further well lock treatment Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Monday, September 12, 2022 1:55 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer X-07 (PTD #1800130) Monitor post-Well Lock Mr. Regg, Producer X-07 (PTD #1800130) was put on production on 08/27/22. During the online period, the OA has remained at or near zero with no OA re-pressurization. At this time, the well is classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, August 22, 2022 2:37 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) POP & Monitor post-Well Lock Mr. Regg, Producer X-07 (PTD #1800130) had an OA down squeeze with Well Lock on 08/01/22 in accordance with Sundry 322-359. The Well Lock has cured and the well is ready to be POP’d. The well is now classified as UNDER EVALUATION to monitor for OA re-pressurization. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 22, 2022 8:26 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) has been secured with a tubing tail plug and a passing CMIT-TxIA in preparation for the upcoming OA squeeze job to repair OA repressurization. The well is now classified as NOT OPERABLE. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer WIC Office: (907) 659-5102 Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity Sent: Monday, July 11, 2022 3:16 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) OA pressure remains near 0 psi while the well is online and warm. Sundry approval for well lock treatment is being processed with AOGCC. The well can remain online as the Under Evaluation period is being extended for an additional 14 days until the sundry is approved. At that time the well will be secured, and pressure tested prior to well lock. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, June 13, 2022 4:53 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 06/11/22. The reported pressure was 1016 psi. The X-07 OA was cemented to surface during a RWO in 2006, in part to repair IAxOA communication. When the OA exceeded MOASP on 6/11/22, the well had recently been shut-in and was cooling. It is suspected that when the well cools down a micro annulus in the cement allows pressure communication between the IA and OA. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics and attempted repair of the OA repressurization. Plan forward: 1. DHD: PPPOT-IC 2. FB: CMIT-TxIA 3. DHD: OA wellock squeeze 4. DHD/ Ops: Cycle well on/off, monitor for OA repress Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, March 24, 2022 2:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer X-07 (PTD #1800130) Passed PPPOT-IC & OART Mr. Regg, Producer X-07 (PTD # 1800130) passed a PPPOT-IC to 3500 psi on 03/07/22. The OA pressure was bled to 0 psi on 03/07/22 to start an OA re-pressurization test. During subsequent monitoring, the OAP BUR was quantified at ~18 psi/day which is manageable by periodic bleeds and indicates the rapid OA MOASP excursion was in fact due to the introduction of cold lift gas. The well will now be classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, March 5, 2022 4:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 03/04/22. The reported pressure was 1,050 psi. The OA is cemented to surface via RWO in 2006. When the OA MOASP excursion transpired, the well was temporarily receiving ambient temperature lift gas from the FS3 tie in. It is suspected that the introduction of the cold lift gas caused the casing tubulars to contract and intermittently release pressure from a micro-annulus in the OA cement. The OA pressure was bled off and as the lift gas warmed up, the re-pressurization ceased. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics to ensure competent barriers. Plan forward: 1. DHD: PPPOT-IC 2. DHD: Outer Annulus Re-pressurization Test (OART) 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Producer X-07 (PTD #1800130) Monitor post-Well Lock Date:Monday, September 12, 2022 1:57:19 PM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, September 12, 2022 1:55 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer X-07 (PTD #1800130) Monitor post-Well Lock Mr. Regg, Producer X-07 (PTD #1800130) was put on production on 08/27/22. During the online period, the OA has remained at or near zero with no OA re-pressurization. At this time, the well is classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, August 22, 2022 2:37 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) POP & Monitor post-Well Lock Mr. Regg, Producer X-07 (PTD #1800130) had an OA down squeeze with Well Lock on 08/01/22 in accordance with Sundry 322-359. The Well Lock has cured and the well is ready to be POP’d. The well is now classified as UNDER EVALUATION to monitor for OA re-pressurization. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 22, 2022 8:26 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) has been secured with a tubing tail plug and a passing CMIT-TxIA in preparation for the upcoming OA squeeze job to repair OA repressurization. The well is now classified as NOT OPERABLE. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer WIC Office: (907) 659-5102 Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity Sent: Monday, July 11, 2022 3:16 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) OA pressure remains near 0 psi while the well is online and warm. Sundry approval for well lock treatment is being processed with AOGCC. The well can remain online as the Under Evaluation period is being extended for an additional 14 days until the sundry is approved. At that time the well will be secured, and pressure tested prior to well lock. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, June 13, 2022 4:53 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 06/11/22. The reported pressure was 1016 psi. The X-07 OA was cemented to surface during a RWO in 2006, in part to repair IAxOA communication. When the OA exceeded MOASP on 6/11/22, the well had recently been shut-in and was cooling. It is suspected that when the well cools down a micro annulus in the cement allows pressure communication between the IA and OA. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics and attempted repair of the OA repressurization. Plan forward: 1. DHD: PPPOT-IC 2. FB: CMIT-TxIA 3. DHD: OA wellock squeeze 4. DHD/ Ops: Cycle well on/off, monitor for OA repress Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, March 24, 2022 2:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer X-07 (PTD #1800130) Passed PPPOT-IC & OART Mr. Regg, Producer X-07 (PTD # 1800130) passed a PPPOT-IC to 3500 psi on 03/07/22. The OA pressure was bled to 0 psi on 03/07/22 to start an OA re-pressurization test. During subsequent monitoring, the OAP BUR was quantified at ~18 psi/day which is manageable by periodic bleeds and indicates the rapid OA MOASP excursion was in fact due to the introduction of cold lift gas. The well will now be classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, March 5, 2022 4:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 03/04/22. The reported pressure was 1,050 psi. The OA is cemented to surface via RWO in 2006. When the OA MOASP excursion transpired, the well was temporarily receiving ambient temperature lift gas from the FS3 tie in. It is suspected that the introduction of the cold lift gas caused the casing tubulars to contract and intermittently release pressure from a micro-annulus in the OA cement. The OA pressure was bled off and as the lift gas warmed up, the re-pressurization ceased. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics to ensure competent barriers. Plan forward: 1. DHD: PPPOT-IC 2. DHD: Outer Annulus Re-pressurization Test (OART) 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 22, 2022 8:26 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) has been secured with a tubing tail plug and a passing CMIT-TxIA in preparation for the upcoming OA squeeze job to repair OA repressurization. The well is now classified as NOT OPERABLE. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer WIC Office: (907) 659-5102 Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity Sent: Monday, July 11, 2022 3:16 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) OA pressure remains near 0 psi while the well is online and warm. Sundry approval for well lock treatment is being processed with AOGCC. The well can remain online as the Under Evaluation period is being extended for an additional 14 days until the sundry is approved. At that time the well will be secured, and pressure tested prior to well lock. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, June 13, 2022 4:53 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 06/11/22. The reported pressure was 1016 psi. The X-07 OA was cemented to surface during a RWO in 2006, in part to repair IAxOA communication. When the OA exceeded MOASP on 6/11/22, the well had recently been shut-in and was cooling. It is suspected that when the well cools down a micro annulus in the cement allows pressure communication between the IA and OA. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics and attempted repair of the OA repressurization. Plan forward: 1. DHD: PPPOT-IC 2. FB: CMIT-TxIA 3. DHD: OA wellock squeeze 4. DHD/ Ops: Cycle well on/off, monitor for OA repress Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, March 24, 2022 2:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer X-07 (PTD #1800130) Passed PPPOT-IC & OART Mr. Regg, Producer X-07 (PTD # 1800130) passed a PPPOT-IC to 3500 psi on 03/07/22. The OA pressure was bled to 0 psi on 03/07/22 to start an OA re-pressurization test. During subsequent monitoring, the OAP BUR was quantified at ~18 psi/day which is manageable by periodic bleeds and indicates the rapid OA MOASP excursion was in fact due to the introduction of cold lift gas. The well will now be classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, March 5, 2022 4:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 03/04/22. The reported pressure was 1,050 psi. The OA is cemented to surface via RWO in 2006. When the OA MOASP excursion transpired, the well was temporarily receiving ambient temperature lift gas from the FS3 tie in. It is suspected that the introduction of the cold lift gas caused the casing tubulars to contract and intermittently release pressure from a micro-annulus in the OA cement. The OA pressure was bled off and as the lift gas warmed up, the re-pressurization ceased. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics to ensure competent barriers. Plan forward: 1. DHD: PPPOT-IC 2. DHD: Outer Annulus Re-pressurization Test (OART) 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Date:Monday, July 11, 2022 4:05:36 PM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, July 11, 2022 3:16 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) OA pressure remains near 0 psi while the well is online and warm. Sundry approval for well lock treatment is being processed with AOGCC. The well can remain online as the Under Evaluation period is being extended for an additional 14 days until the sundry is approved. At that time the well will be secured, and pressure tested prior to well lock. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, June 13, 2022 4:53 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 06/11/22. The reported pressure was 1016 psi. The X-07 OA was cemented to surface during a RWO in 2006, in part to repair IAxOA communication. When the OA exceeded MOASP on 6/11/22, the well had recently been shut-in and was cooling. It is suspected that when the well cools down a micro annulus in the cement allows pressure communication between the IA and OA. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics and attempted repair of the OA repressurization. Plan forward: 1. DHD: PPPOT-IC 2. FB: CMIT-TxIA 3. DHD: OA wellock squeeze 4. DHD/ Ops: Cycle well on/off, monitor for OA repress Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, March 24, 2022 2:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer X-07 (PTD #1800130) Passed PPPOT-IC & OART Mr. Regg, Producer X-07 (PTD # 1800130) passed a PPPOT-IC to 3500 psi on 03/07/22. The OA pressure was bled to 0 psi on 03/07/22 to start an OA re-pressurization test. During subsequent monitoring, the OAP BUR was quantified at ~18 psi/day which is manageable by periodic bleeds and indicates the rapid OA MOASP excursion was in fact due to the introduction of cold lift gas. The well will now be classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, March 5, 2022 4:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 03/04/22. The reported pressure was 1,050 psi. The OA is cemented to surface via RWO in 2006. When the OA MOASP excursion transpired, the well was temporarily receiving ambient temperature lift gas from the FS3 tie in. It is suspected that the introduction of the cold lift gas caused the casing tubulars to contract and intermittently release pressure from a micro-annulus in the OA cement. The OA pressure was bled off and as the lift gas warmed up, the re-pressurization ceased. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics to ensure competent barriers. Plan forward: 1. DHD: PPPOT-IC 2. DHD: Outer Annulus Re-pressurization Test (OART) 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Date:Tuesday, June 14, 2022 8:29:09 AM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, June 13, 2022 4:53 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 06/11/22. The reported pressure was 1016 psi. The X-07 OA was cemented to surface during a RWO in 2006, in part to repair IAxOA communication. When the OA exceeded MOASP on 6/11/22, the well had recently been shut-in and was cooling. It is suspected that when the well cools down a micro annulus in the cement allows pressure communication between the IA and OA. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics and attempted repair of the OA repressurization. Plan forward: 1. DHD: PPPOT-IC 2. FB: CMIT-TxIA 3. DHD: OA wellock squeeze 4. DHD/ Ops: Cycle well on/off, monitor for OA repress Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, March 24, 2022 2:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer X-07 (PTD #1800130) Passed PPPOT-IC & OART Mr. Regg, Producer X-07 (PTD # 1800130) passed a PPPOT-IC to 3500 psi on 03/07/22. The OA pressure was bled to 0 psi on 03/07/22 to start an OA re-pressurization test. During subsequent monitoring, the OAP BUR was quantified at ~18 psi/day which is manageable by periodic bleeds and indicates the rapid OA MOASP excursion was in fact due to the introduction of cold lift gas. The well will now be classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, March 5, 2022 4:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X-07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, Producer X-07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 03/04/22. The reported pressure was 1,050 psi. The OA is cemented to surface via RWO in 2006. When the OA MOASP excursion transpired, the well was temporarily receiving ambient temperature lift gas from the FS3 tie in. It is suspected that the introduction of the cold lift gas caused the casing tubulars to contract and intermittently release pressure from a micro-annulus in the OA cement. The OA pressure was bled off and as the lift gas warmed up, the re-pressurization ceased. The well will be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics to ensure competent barriers. Plan forward: 1. DHD: PPPOT-IC 2. DHD: Outer Annulus Re-pressurization Test (OART) 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. 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Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Producer X‐07 (PTD #1800130) Passed PPPOT‐IC & OART Mr. Regg, Producer X‐07 (PTD # 1800130) passed a PPPOT‐IC to 3500 psi on 03/07/22. The OA pressure was bled to 0 psi on 03/07/22 to start an OA re‐pressurization test. During subsequent monitoring, the OAP BUR was quantified at ~18 psi/day which is manageable by periodic bleeds and indicates the rapid OA MOASP excursion was in fact due to the introduction of cold lift gas. The well will now be classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, March 5, 2022 4:23 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Producer X‐07 (PTD #1800130) OA casing pressure above MOASP Mr. Regg, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Producer X‐07 (PTD #1800130) was reported to have OA casing pressure above MOASP on 03/04/22. The reported pressure was 1,050 psi. The OA is cemented to surface via RWO in 2006. When the OA MOASP excursion transpired, the well was temporarily receiving ambient temperature lift gas from the FS3 tie in. It is suspected that the introduction of the cold lift gas caused the casing tubulars to contract and intermittently release pressure from a micro‐annulus in the OA cement. The OA pressure was bled off and as the lift gas warmed up, the re‐pressurization ceased. The well will be classified as UNDER EVALUATION and is on the 28‐day clock for diagnostics to ensure competent barriers. Plan forward: 1.DHD: PPPOT‐IC 2.DHD: Outer Annulus Re‐pressurization Test (OART) 3.Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 Mt K-07 lSOol3u Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWellIntegrityCoordinator @bp.com] 'Ref 61ILII-; Sent: Monday, June 10, 2013 11:06 AM To: AK, OPS GC3 Facility& Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; Black, Brittany; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D&C DHD Well Integrity Engineer; Walker, Greg (D&C); Holt, Ryan P; Weiss, Troy D Subject: UNDER EVALUATION: X-07 (PTD#1800130) Sustained Outer Annulus Casing Pressure Attachments: Producer X-07 (PTD#1800130)TIO Plot.docx; Producer X-07 (PTD#1800130) Wellbore Schematic.pdf All, Producer X-07 (PTD#1800130)was reported to have sustained outer annulus casing pressure above MOASP on 06/09/2013. The pressures were reported to be inner annulus/outer annulus at 1850/1830 psi. The tubing pressure was not obtainable due to a locked out swab valve. The well is reclassified as Under Evaluation and is placed on a 28 day clock to facilitate evaluation. Plan forward: 1. DHD: Perform OART 2. Wellhead: Perform PPPOT-IC CA-Se A copy of the TIO plot and weilbore schematic are attached for reference. f Please call with any questions. .a° 1 p 53g0r , Thank you, ti yp 34,0 Jack Disbrow SCANNED BP Alaska-Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWelIIntegrityCoordinator @bp.com 1 � ao°o c aOOOO • • M M M_ """i3 X —y _n S g • 111111 c, A 1 f� 1 O - t O M O M! c M O � f- OM c; OOOO ,Ace Q 25 o X1 N a .s ri e i M F— O a a Zi5 - - TREE= 7-1/16"5MCM/ WEf.LHEAD= 13-5/8"5M MCEVOY SAFETY NOTES: ***POSSIBLE IA X OA COMM. ACTUATOR= OTIS X""®7 OPERATING PRESSURE OF THE 13-3/8"ANNULUS KB.ELEV= 73.60' MUST NOT EXCEED 2000 PSI(10/12/02 BF.ELEV= 39.80' �� •• WAIVER)"*4-1/2"CHROME TBG KOP 3200' 4 ••1• , Max Angle 52 @ 5700' ∎•I •A I Iii A 2104' I-4-1/2"HES X NIP,ID=3.813" Datum MD= 10810' Datum TV D= 8800'SS i�-e •i 2172' I-9-5/8"HES CEMENTER 9-58"CSG,404,L-80 TC-11,ID=8.835" H 2183' 2615' I-9-5/8"DV PKR 13-3/8"CSG,72#,L-80,ID=12.347" -I 2693' I GAS LIFT MANDRELS " L p.- 534>;,p5; ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3004 3003 6 MMG DOME RK 16 8/1/10 4 4873 4617 47 MMG DOME RK 16 8/1/10 3 6612 5722 50 MMG DOME RK 16 8/1/10 2 8443 6973 43 MMG SO RK 24 8/1/10 Minimum ID = 3.725" @ 10063' 1 9729 7989 32 MMG DMY RK 0 8/1/10 4-1/2" PARKER SWN NIPPLE I 9799' I--4-1/2"HES X NIP,ID=3.813" `� ›K\— 9820' 1_19-5/8"X 4-1/2"BKR S-3 PKR, ID=3.870" I I I 9844' }-4-1/2"HES X NIP,ID=3.813" 9908' I_I4-1/2"WLEG, ID=4.000 I 4-1/2"TBG, 12.64,13CR-80 VAM TOP, —I 9908' I-- \/ 0.0152 bpf,ID=3.958" 10001' I-I9-5/8"x 4-1/2"TIW HBBP-R PKR,ID=4.0" I I 10052' I-I4-1/2"PARKER SWS NIP,ID=3.813" TOP OF 7"LNR H 10058' I I 10063' LI4-1/2"PARKER SWN NIP, ID=3.725" I 4-1/2"TBG, 12.6#,13CR,0.0152 bpf, ID=3.958" H 10107' I \ 10107' „_I4-1/2"WLEG,ID=3.958" I 10094' IH ELMD TT LOGGED 04/23/91 I 9-5/8"CSG,47#,L-80,ID=8.681" H 10568' I--4 1. PERFORATION SUMMARY t REF LOG:BHCS ON 05/05/80 ANGLE AT TOP PERF:36 @ 10734' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ' 3-3/8" 6 10734- 10761 0 05/16/94 3-3/8" 6 10846- 10876 0 01/03/91 10910' I-3"IBP(FELL DOWNHOLE- 3-3/8" 6 10886- 10906 0 01/03/91 TAGGED 03/25/10) 2-7/8" 4 10916- 10928 S 12/29/90 3-3/8" 4 10938- 10943 S 12/29/90 PBTD 11638' r��vt t ►�1��1�1�1�1�1�� 7"LNR,294,L-80,0.0371 bpf, ID=6.184" -I 11690' ►'•.•.'� A DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/09/80 ORIGINAL COMPLETION 11/02/06 RCT/TLH GLV C/O WELL: X-07 04113/91 RWO 11/16/06 HJW/PJC DRLG DRAFT CORRECTIONS PERMIT No:'1800130 08/24/06 D14 RWO 11/25/09 LRD/SV IBPCORR API No: 50-029-20441-00 10/12/02 JAL/KK WAIVER SAFETY NOTE 08/03/10 MSS/AGR GLV CIO(08/01/10) SEC 7,T1ON,R14E,156'WEL&409'SNL 12/11/03 JDW/TLP CLOSE PERFS BELOW 10906' 10/04/10 KS/SV IBP CORR(03/25/10) 04/13/06 JCM/PJC MIN ID CORRECTION(SWN NIP) BP Exploration (Alaska) I ø¿ jZJ-!c6 STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission RECEIVED SEP 2 2 2006 1. Operations Performed: Anchorage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension ,_ .IoU ~ - 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number:! 'TO CJ I tst BP Exploration (Alaska) Inc. ~ Development o Exploratory 1M n~~305-366/306-273 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20441-00-00 7. KB Elevation (ft): 73.6' 9. Well Name and Number: PBU X-07 8. Property Designation: 10. Field / Pool(s): ADL 028313 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11691 feet true vertical 9617 feet Plugs (measured) 10882' Effective depth: measured 11638 feet Junk (measured) None true vertical 9572 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 30" x 20" 110' 110' Surface 2695' 13-3/8" 2695' 2695' 4930 2670 Intermediate 10568' 9-5/8" 10568' 8671' 8150 5080 Production Liner 1631' 7" 10059' - 11690' 8267' - 9616' 8160 7020 ~~NS~) SEP 2 (' 2005 Perforation Depth MD (ft): 10734' - 10876' Perforation Depth TVD (ft): 8802' - 8918' Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# 13Cr80 9908' 1nnn1' _ 1n1n7' Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" BKR S-3 Packer 9820' 9-5/8" x 4-1/2" TIW 'HBBP-R' Packer 10001' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pulled tubing from 9990'. Cut and pulled 9-5/8" casing from 2163', Run 9-5/8" tieback to surface cemented with 140 Bbls Class 'G' (786 cu ft, 678 sx, Yield 1.16) Ran new Chrome tubinQ. 13. Representative Daily Averaç¡e Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure Tubinç¡ Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Isu~~r ~/A þC'O' Exempt: Contact Doug Cismoski, 564-4303 -,1:/ .J ~) ULJ Printed Name Sondra Stewman / Title Technical Assistant Prepared B~~t - J - ! -:Jt:n,çt~ Phone 564-4750 DatecA - Z I "'r'i,sondra Stewman, 564-4750 Sigl'\a.ture ~".~ '/} x)~ o Form 10-404 Revised 04/20060 R , G \ N A L Submit Original Only RBDMS 8Ft SEP 2 6 2006 · X-OJ L.:wNOTES:***CHROMETBG*** FROM DRLG - DRAFT TREE = , WELLHI?AD = ACTUA TOR = KB, ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum ND = 7-1/16" 5M CM! 13-5/8" 5M MCEVOY OTIS 73,60' 39.80' 3200' 52 @ 5700' 10810' 8800'SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I 9-5/8",40#, L-80 TC-II Fully cemented to surface. Minimum 10 = 3.725" @ 10063' 4-1/2" PARKER SWN NIPPLE I 4-1/2" TBG, 12,6#, 13CR-80, VamTop TOP OF 7" LNR I I 4-1/2" TBG, 12,6#, 13CR, .0152 bpf, ID = 3.958" I 10107' 9-5/8" CSG, 47#, L-80, 10 = 8,681" I PERFORA TION SUMMARY REF LOG: BHCS ON 05/05/80 ANGLEAT TOP PERF: 32 @ 10734' Note: Refer to Production DB for hístorícal perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 6 10734 - 10761 0 05/16/94 3-3/8" 6 10846 - 10876 0 01/03/91 3-3/8" 6 10886 - 10906 C 01/03/91 2-7/8" 4 10916 - 10928 S 12/29/90 3-3/8" 4 10938 - 10943 S 12/29/90 I PBTD I 11690' 11638' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I DATE 05/09/80 04/13/91 06/22/01 07/13/02 10/12/02 12/11/03 REV BY COMMENTS ORIGINAL COMPLETION RWO RNlTP CORRECTIONS JC/KAK CORRECTIONS JAL/KK WAIVER SAFElY NOTE JOWITLP CLOSEÆRFS BELOW 10906' DATE REV BY 4-1/2" HES "X" NIP,ID- 3,813" ST MD 5 3004 4 4873 3 6612 2 8443 1 9729 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 6 MMG DCK RKP 47 MMG DMY RK 50 MMG DMY RK 43 MMG DMY RK 32 MMG DMY RK PORT DA TE 08/08/06 o 08/08/06 o 08/08/06 o 08/08/06 o 08/08/06 ND 3003 4614 5722 6973 7989 9799' 4-1/2" HES "X" NIP, ID - 3.813" 9820' 9-5/8" x 4-1/2" BKR S-3 PKR, ID - 3.875" 9844' 4-1/2" HES "X" NIP, ID - 3.813" 9-5/8" x 4-1/2" TMI HBBP-R PKR, ID - 4.0" 4-1/2" PARKER SWS NIP, ID = 3.813" J4-1/2" PARKER SWN, NIP, ID = 3.813" 10107' j4-1/2" WLEG, ID = 3.958"1 10094' H ELMDTT LOGGED 04/23/91 I 10882' -1 3" IBP- 04/24/91 I COMMENTS PRUDHOE BA Y UNfT WELL: X-07 PERMfT No: 1800130 API No: 50-029-20441-00 SEC 7, T10N, R14E, 156' WEL & 409' SNL BP Exploration (Alaska) . Well Events for SurfaceWell - X-07 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC3 -> X -> X-07 Date Range: 23/Jun/2006 to 23/Ju1/2006 Data Source(s): DIMS, AWGRS Digital Wellfile Events Source Well Date AWGRS X-07 07/23/2006 AwGRS X-07 07/09/2006 AWGßS X-07 07/08/2006 AWGRS X-07 07/05/2006 AWJiR5 X-07 07/04/2006 AWGRS X-07 07/04/2006 AWGRS X-07 07/04/2006 AwGRS X-07 06/24/2006 AWGRS X-07 06/23/2006 . Page 1 of 1 Description TIO = 1380/1500/0. Temp = 51. Bleed WHPs to zero (pre RWO). AL info; casing valve 51, no lateral valve, ALP = 210 psi, ALP was most recently bled by FO on 07/21. TBG FL near surfacè. IA FL @ 200'. Bled lAP from 1500 psi to 0+ psi in 1.75 hrs (all gas). TBGP went on a vac during lAP bleed. Bled ALP from 210 psi to 0 psi in 30 mins. lAP increased to 3 psi during ALP bleed, TBGP stayed on a vac. Re-bled lAP to 0 psi. Monitored for 30 mins. TBGP unchanged, lAP increased to 0+ psi (bled back to zero in 10 seconds), ALP unchanged. FWHPs = VAC/O/O. (continued from 7-8-06) Finish bleeding rig down T/I/O= 200/200/0 Circ. out well [ PRE RWO] Pumped 5 bbl meth spear and 1112 bbls of seawater down tubing, followed by 151 bbls of diesel. U-tubed to freeze protect TxIA. CMIT TXIA passed MIT OA failed CMIT TXIAXOA passed to 2000 psi (see mìt data sheet) freeze protect flowline with 69 bbl dsl and 7 bbls meoh bleed pressures back to 0 FWHP=O/O/O PUNCH THE TUBING WITH 2' SMALL OR "PINK" TUBING PUNCHER FROM 9953-9955' IN THE PUP JOINT ABOVE GLM #1. CHEMICAL CUT THE TUBING AT 9981.5' WITHIN 2' OF THE TOP OF THE PUP JOINT ABOVE THE SWS NIPPLE. CORRELATION DONE OF THE COURSE OF 1.75 HOURS DUE TO REPEATED CENTRALIZER DRAG THROUGH THE PACKER AND GLM #1. AFTER 1.75 HOURS. 3 REPEATED CORRELATIONS ALLOWED FOR CONFIDENCE IN CUT DEPTH DUE TO SMALL WINDOW OF 2'. TUBING AND IA PRESSURES BLED DOWN TO 200 PSI DURING TUBING PUNCHER AND CHEMICAL CUTTER RUNS THROUGH THE FLOWLINE TO THE LOW PRESSURE HEADER. WING SHUT IN PRIOR TO PUNCHING AND CUTTING. LOG CORRELATED TO TUBING TALLY DATED 12-APRIL-1991. ********JOB COMPLETE********* T/I/0=380/360/0 Assist E-Line / Test fasdrill plug (Pre RWO) - Pump 9 bbls diesel down tubing to pressure to 2000 psi, Tubing lost 200 psi in 15 min, Good test, Bleed TP, RD tubing, RU lA, Pump 95 bbls diesel down IA to help pre-load for upcoming CMIT Final WHP's=400/180/0 SET 4.5" HES FASDRILL COMPOSITE BRIDGE PLUG IN THE FIRST FULL JOINT BELOW THE PACKER AT 10030'. LITTLE RED TEST PLUG TO 2000 POUNDS PUMPING 9 BBLS DIESEL. TUBING PRESSURE FELL TO 1800 PSI AFTER 15 MINUTES. LITTLE RED PUMPED 95 BBLS OF DIESEL DOWN THE IA. PRESSURE FELL FROM 360 TO 150. STRING SHOT THE TUBING FROM 9971.5-9976.5. TOP 5' OF STRING SHOT FIRED. PRIMA CORD DAMAGED RIH BELOW THIS POINT. CORRELATE LOGS TO TUBING TALLY DATED 12-APRIL-1991. ********CONTINUED 07/05/06********** T/I/O= 330/320/0. Temp= 51. Tbg & IA FL ( for E-line ). Tbg FL @ 192'?? (2.9 bbls). IA FL @ 3858' (206.4 bbls). ***CONT FROM 6/23/06 WSR*** DRIFT W/4.5 BLB, 3.71 GUAGE RING TO 10200' SLM ***WELL LEFT SHUT IN*** *** WELL SHUT IN PRIOR TO ARRIVAL *** PULL P-PRONG @ 10026' SLM. PULL 4.5 PXN PLUG @ 10036' SLM. DRIFT TUBING W/ 4.5 BLB, 3.71 GUAGE RING ***CONT ON 6/24/06 WSR*** http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default. aspx 9/22/2006 · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-07 X-07 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/30/2006 Rig Release: 8/22/2006 Rig Number: 14 Spud Date: 4/14/1980 End: 8/22/2006 7/30/2006 18:00 - 19:00 1.00 MOB P OECOMP PJSM - Skid rig floor 19:00 - 21 :30 2.50 MOB P DECOMP PJSM - Move off well X-15A to X-07A and spot rig 21 :30 - 22:00 0.50 MOB P OECOMP Skid rig to drill position 22:00 - 00:00 2.00 MOB P OECOMP RU - Prepare rig for acceptance - Spot and berm rockwasher- Rig accepted at 00:00 hrs 7/31/2006 00:00 - 03:00 3.00 CLEAN P CLEAN RU on tree w/ círculating lines and OSM lubricator- Pull BPV- RD lubricator 03:00 - 06:00 3.00 CLEAN P CLEAN RU tíger tank, hard lines & choke- Test for leaks wI air 06:00 - 07:30 1.50 CLEAN P CLEAN Reverse circ. 50 bbls out tubing- Pump down tubing and displace 170 bbls from annulus- 7 bpm 1150 psi 07:30 - 08:00 0.50 DHB P OECOMP RU & test FasOril plug at 10,030' to 1000 psi f/15 min on chart- Test good 08:00 - 10:30 2.50 WHSUR P DECOMP Install TWC- Attempt to test from top- TWC leaking- Test to 1000 psi from bottom- Test good- Re-test from top- No success. Call DSM for lubricator & new TWC- 10:30 - 12:00 1.50 WHSUR N SFAL OECOMP RU lubricator- Pull TWC- Install new TWC- RD lubrícator 12:00 - 14:00 2.00 WHSUR N SFAL DECOMP Attempt to test TWC from top- Oetermined that upper seals on hanger failed allowing pressure to bleed off through SSSV ports. Test TWC from bottom to 1000 psí- Test good 14:00 - 15:00 1.00 WHSUR P DECOMP ND Tree & adapter flange- Plug SSSV ports- Screw 7" IJ4S XO into hanger to verify. 15:00 - 17:00 2.00 BOPSU P DECOMP NU BOP stack wíth 3 foot spacer spool 17:00 - 18:00 1.00 BOPSU P DECOMP RlU to test BOPE 18:00 - 23:00 5.00 BOPSU P OECOMP Test BOPE - Test annular, 2718" X 5" VBR's, Blind rams, 3 1/2" X 6" VBR's, HCR kill/choke, Manual kill/choke, Choke manifold, IBOP's, Surface valves to 250 psi low - 3500 psi high for 5 minutes each. Tested upper VBR's with 4" and 4 1/2" tst joínt. Performed accumulator test. Chuck Scheve wíth AOGCC waived witnessing of BOP test. 23:00 - 23:30 0.50 EVAL P DECOMP RID test equípment - Blow down kill and choke lines 23:30 - 00:00 0.50 EVAL P OECOMP RlU riser and OSM lubricator 8/1/2006 00:00 - 01 :00 1.00 EVAL P OECOMP Pull TWC - RID lubricator 01 :00 - 01 :30 0.50 FISH P OECOMP Mobilize and MU spear assembly 01 :30 - 02:00 0.50 FISH P DECOMP Spear 41/2" tubing hanger and pull to floor (PU 160K, no over pull) 02:00 - 03:30 1.50 FISH P OECOMP CBU @ 268 gpm = 1100 psi 03:30 - 04:00 0.50 FISH P DECOMP Release spear and LD hanger 04:00 - 05:00 1.00 PULL P DECOMP RU to LD 4 1/2" TDS 13cr tubing usíng compensator & single joint elevators - RU control line spooling unit 05:00 - 09:30 4,50 PULL P DECOMP PJSM - LID 2020' of 4 1/2" tubing using compensator 09:30 - 10:00 0.50 PULL P DECOMP LID SSSV - LlO control line spooling unit - Retrieved 27 clamps, 4 bands 10:00 - 18:30 8.50 PULL P OECOMP Continue LID 41/2" 12.6# 13CR-80 tubing with compensator to 1545'- Dropped 39 jts of tubíng down hole (see remarks sectíon)- Layed down 216 jts tubing- 3 GLM's- SSSV 18:30 - 19:30 1.00 MOB P OECOMP Clear ríg floor of tubíng equipment- Mobilize fishing BHA to rig floor 19:30 - 21 :00 1.50 EVAL P OECOMP Safety stand down and investigation on dropped pipe- PJSM on use of secondary restraint while pícking up DP from pipe skate. 21 :00 - 23:30 2.50 FISH P OECOMP PJSM - MU Fishing assy - Overshot - Bumper Sub - Jars - POS - DC's - XO's 23:30 - 00:00 0.50 FISH P OECOMP RIH wíth 4" OP 1 X 1 from pipe shed Printed: 8/2812006 10:42: 14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-07 X-07 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/30/2006 Rig Release: 8/22/2006 Rig Number: 14 Spud Date: 4/14/1980 End: 8/22/2006 81212006 00:00 - 04:00 4.00 FISH P DECOMP Con't RIH w/físhing assy - Picking up 4" OP 1 X 1 from pipe shed to 5997' 04:00 - 04:30 0.50 FISH P DECOMP Adjust brakes on draworks 04:30 - 06:30 2.00 FISH P DECOMP Cont. RIH - PU 4" DP from pipe shed to 8430' 06:30 - 07:00 0.50 FISH P DECOMP Screw ín TD - Obtaín parameters- Break circ. wI 5 bpm 640 psi- PU wt 172k SO wt 150k - Wash down, Tag T.O.F at 8460' - Engage fish (observe pressure increase) - Pull 50k over to free fish- PU 30' w/ 190k (18k over) 07:00 - 08:00 1.00 FISH P DECOMP Circulate bottoms up w/10 bpm 1940 psi- PU wt 190k SO wt 160k 08:00 - 12:00 4.00 FISH P DECOMP POH wI fish to BHA 12:00 - 13:00 1.00 FISH P OECOMP Stand back OC's - Release O.S.- LO jars 13:00 - 14:00 1.00 FISH P DECOMP PJSM - RU to LO tubing 14:00 - 16:00 2.00 FISH P DECOMP LO 4 1/2" tubing - Recovered 2' of curled up tubíng and other large pieces of metal inside of shoe 16:00 - 17:00 1.00 FISH P OECOMP RD Long Bales - Compensator- Power tongs - Clear rig floor 17:00 - 18:00 1.00 EVAL P DECOMP RU -Test Casing to 3500 psi for 30 mins. - Recorded on chart- Test Good 18:00 - 18:30 0.50 CLEAN P DECOMP Mobilize BHA to rig floor 18:30 - 20:00 1.50 CLEAN P OECOMP PJSM - MU BHA - Dress Off shoe assy 20:00 - 21 :00 1.00 CLEAN P OECOMP PJSM - Cut and slip drilling line - Rig Service 21 :00 - 21 :30 0.50 CLEAN P OECOMP Lubricate rig - Top drive - Blocks and Crown 21 :30 - 00:00 2.50 CLEAN P OECOMP RIH wI 4" Dríll pipe f/ 323' to 8482' 8/3/2006 00:00 - 01 :30 1.50 FISH P OECOMP PU 4" DP to 9964' 01 :30 - 02:00 0.50 FISH P DECOMP Screw in TO - Obtain parameters - PU 206k SO 165k ROT 173k - 6 bpm 970 psí - Wash down & tag top 41/2" stub at 9983' shoe depth. 02:00 - 08:00 6.00 FISH P DECOMP Wash over stub- Mill 1 ft of 41/2" stub - Shoe depth to 9988' 08:00 - 1 0:30 2.50 FISH P DECOMP Pump HV sweep - Spot in annulus - Reverse circulate 10:30 - 12:00 1.50 FISH P DECOMP POH f/ 9988' to 6110' 12:00 - 14:00 2.00 FISH P DECOMP Cont. POH f/6110' - 323' 14:00 - 15:30 1.50 FISH P DECOMP LD BHA - Stand back collars - LD Junk baskets 15:30 - 16:00 0.50 FISH P DECOMP Mobilize BHA to ríg floor 16:00 - 16:30 0.50 FISH P DECOMP Lubricate rig 16:30 - 18:30 2.00 FISH P DECOMP MU BHA - Wash over assy. 18:30 - 22:00 3.50 FISH P DECOMP RIH f/333' to 9980' 22:00 - 00:00 2.00 FISH P DECOMP Break circulation - Obtain parameters - PU 230 - SO 150 - RPM 70 - TQ 5 - GPM 300 - PP 1330 - Wash down from 9987' to 9998' tag junk - Did not see top of stub - Mill on junk from 9998' to 10000' top anchor - PU to 9980' - Wash to bottom - Top of stub 9987' - Work junk from 9998' to 10000' - Pump 35 bbl Hi-vis sweep 8/4/2006 00:00 - 01 :30 1.50 FISH P DECOMP Con't milling on junk from 9998' to 10000' - Losing mud - Lost 78 bbls over 45 mins - Píck up to 9980' - Shut down pumps well on vacuum - Monítor well for 15 mins - Fill hole 58 bbls to fill - Wash to bottom - Top of stub 9987' wash to 10001.90' taking weight (no millíng requíred) - 1.90' deeper - PU to 9998' wash down to 10002.70' taking weíght (no milling requried) - .80 deeper - PU to 9980' - RIH Tag top of stub 9990' - 3' deeper - Con't wash to 10002.70' taking weight - Rotating required to get over the top of the stub 01 :30 - 02:30 1,00 FISH P DECOMP PU monitor well - Losing 138 bbls hr 02:30 - 04:00 1.50 FISH P OECOMP POH from 9980' to 7165' using double displacement while Printed: 8/28/2006 10:42: 14 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-07 X-07 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/30/2006 Rig Release: 8/22/2006 Rig Number: 14 Spud Date: 4/14/1980 End: 8/22/2006 8/412006 02:30 - 04:00 1.50 FISH P DECOMP waiting on DHD to arrive (Shoot fluid levels) 04:00 - 07:00 3.00 EVAL P OECOMP Let hole balance f/ 30 min. - Shoot fluid level (588')- Wait 30 min- Shoot fluid level2x (1014' & 1016')- Wait 30 min.- Shoot level2x (1213' & 1230') - Wait 30 min - Shoot level2x (1284' & 1284') 07:00 - 08:00 1.00 FISH P OECOMP POH f/7165 ' using double displacement to 6413' 08:00 - 09:30 1.50 FISH P DECOMP Work on draw works brake bands. 09:30 - 12:00 2.50 FISH P DECOMP Continue POH to BHA at 323' 12:00 - 13:00 1.00 FISH P DECOMP Stand back OC's- LO shoe & wash pipe 13:00 - 13:30 0.50 FISH P OECOMP Clear floor - Mobilize BHA to ríg floor 13:30 - 14:30 1.00 FISH P DECOMP MU 8 1/8" Overshot Assy 14:30 - 17:00 2.50 FISH P OECOMP RIH f/310 to 9511' 17:00 - 18:30 1.50 FISH P OECOMP PJSM - Cut drlg line (Pump 10 bbls fluid down hole every 15 min) 18:30 - 19:00 0.50 FISH P OECOMP RIH from 9511' to 9990' - Tag fish - Latch fish (SWS nípple) @ 9993' - PU 225 - SO 160 - Pull anchor free 25K over string weight 250K 19:00 - 23:00 4.00 FISH P OECOMP POH with fish from 10003' to 310' 23:00 - 00:00 1.00 FISH P OECOMP Stand back DC's - BHA 8/5/2006 00:00 - 00:30 0.50 FISH P DECOMP LD fish - Recovered 15.85' - Anchor - 10' pup joínt - SWS nipple - 3.60 cut off joint - Break and LD Baker fishing tools - 00:30 - 01 :00 0.50 FISH P DECOMP Moblize Howco RBP to ríg floor - Make up same 01 :00 - 06:00 5.00 FISH P DECOMP RIH with RBP to 9940' 06:00 - 06:30 0.50 FISH P DECOMP Set RBP at 9940' element depth (Top of F.N. at 9935') 06:30 - 08:00 1.50 FISH P DECOMP Círc surface to surface to get all air removed from well bore - 96 spm I 2400 Psi 08:00 - 08:30 0.50 FISH P DECOMP Test well to 3500 Psi f/15 min. - Recorded on chart - Test Good 08:30 - 11 :30 3.00 FISH P OECOMP POH f/9935' - LD HES RBP running tool 11 :30 - 12:00 0.50 WHSUR P DECOMP Pull wear ring 12:00 - 15:00 3.00 BOPSU P OECOMP PJSM - Install wI 9 5/8" test joint - Change out Varible top rams 27/8" x 5" to 9 5/8" casing rams 15:00 - 16:00 1.00 EVAL P OECOMP Test 9 5/8" casing rams - 250 psi low - 3500 psi high for 5 mínutes each - Recorded on chart - Test Good 16:00 - 18:30 2.50 EVAL P OECOMP PJSM - RU SLB 9518" lubricator - MU tools - Test lubricator to 1000 psi - Recorded on chart f/ 5 mínutes - Test Good 18:30 - 00:00 5.50 EVAL P DECOMP RIH w/ wireline US IT logs - Start logging up fl 9911' to 2800' in corrosion mode - Log up fl 2800' to surface in cement mode - Estimated top of cement at 2651 ' W LM - Observed DV collar at 2615' 8/6/2006 00:00 - 01 :00 1.00 EVAL DECOMP RD Schlumberger W.L. equip. 01 :00 - 01 :30 0.50 DHB P OECOMP Install wear ring 01 :30 - 02:00 0.50 OHB P DECOMP MU RBP 02:00 - 04:00 2.00 DHB P OECOMP RIH wI RBP to 3600' 04:00 - 04:30 0.50 OHB P DECOMP Obtain parameters - Set RBP at 3607' (element depth) - Test to 1000 psi for 15 mins record on chart 04:30 - 05:30 1.00 OHB P DECOMP POH to 3400' - Dump 1500# 20/40 sand down DP 05:30 - 07:00 1.50 DHB P DECOMP POH to 3300' - Dísplace well wI 9.8 ppg brine - 8 bpm 680 psi 07:00 - 08:30 1.50 OHB P DECOMP RIH to 3600' in attempt to tag sand - No sand - Stand back 1 stand - Hole out of balance - Circ. BU 08:30 - 09:30 1.00 OHB P DECOMP POH 2 stands - PU HES storm packer - Set 1 stand below well head - Release & set back stand - Test Storm packer to 1000 psi - 09:30 - 10:00 0.50 BOPSU P OECOMP Pull wear ring Printed: 8/28/2006 10:42:14 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-07 X-07 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/30/2006 Rig Release: 8/22/2006 Rig Number: 14 Spud Date: 4/14/1980 End: 8/22/2006 3.00 BOPSU P ND BOP's 1.00 WHSUR P Change out tubing spool 1.50 BOPSU P NU BOP's - Choke line - Riser 1.00 EVAL P RU testing equipment - Test against storm packer tubing spool breaks - 250 low - 3500 high - 5mins each test - test good - Record on chart - RD testing equipment 16:30 - 18:30 2.00 OECOMP Install test plug - Change out 9 5/8" casing rams to 2 7/8" x 5" variable rams - RU testing equipment 18:30 - 19:30 1.00 OECOMP Test rams to 250 low 3500 high 5 mins each test - Record on chart 19:30 - 23:30 4.00 OECOMP PJSM - NO stack - Remove tubing spool - NU Stack on casing head - Install choke line extention 23:30 - 00:00 0.50 OECOMP RU to test against storm packer - 250 low 3500 high - 5 mins each test - Record on chart 8/7/2006 00:00 - 01 :30 1.50 DECOMP PU 1 Std drill pipe - LO single joint - Screw into storm packer - Released storm packer - Pull to rig floor and LD 01 :30 - 03:00 1.50 OHB P OECOMP RIH w/ 4" drill pipe to 3200' - Dump 1500 Ibs 20/40 sand 03:00 - 04:00 1.00 DHB P OECOMP Wait on sand to fall f/ 15 minutes - Pump 10 bbls 9.8 ppg brine - WO sand to settle on top of plug 04:00 - 04:30 0.50 DHB P DECOMP RIH & tag top of sand at 3567' (40' above RBP) 04:30 - 06:30 2.00 BOPSU P OECOMP POH - LD Baker Model "L" RBP running tool 06:30 - 08:00 1.50 TA P SURE Wait on orders 08:00 - 10:00 2.00 BOPSU P SURE Nipple down BOP stack 10:00 - 11 :30 1.50 WHSUR P SURE NU Tubing spool - Test Seal to 2000 psi f/15 minutes 11 :30 - 14:00 2.50 BOPSU P SURE NU BOP stack / Choke line / Ríser I Flowline - Install test plug - RU test Equipment 14:00 - 18:00 4.00 BOPSU P SURE Test BOPE - Test annular, Test upper 27/8" x 5" VBR's, 3 1/2" x 6" lower VBR's using 4" drill pipe -Test Blind rams - HCR kill/choke, Manual killlchoke, Choke manifold, upper I lower IBOP, Surface valves to 250 psi low - 3500 psi hígh for 5 minutes each. Preformed accumulator test - Chuck Scheve with AOGCC waived witness of test - WSL witnessed all test- RD testing equipment - Install wear ring 18:00 - 19:00 1.00 TA P SURE PJSM - Blow down lines - RU to RIH 19:00 - 21 :30 2.50 TA P SURE MU mule shoe - RIH 63/4" drill collars - 4" drill pipe - Tagged sand at 3560' (47' above RBP) 21 :30 - 00:00 2.50 T A P SURE POH - LD drill pipe 1 x1 using secondary backup restraint 8/8/2006 00:00 - 09:30 9.50 TA P SURE Cont. LD 4" drill pipe I 6 3/4" drill collars I mule shoe 09:30 - 11 :00 1.50 TA P SURE Clear rig floor - Pull wear ring - RU to run 4.5" Kill string 11 :00 - 15:30 4.50 T A P SURE RIH w/4 1/2" 12.6# IBT L80 tubing kill string 15:30 - 16:30 1.00 TA P SURE MU hanger - Landed kill string at 2749' - RILDS - LD landing joint 16:30 - 17:30 1.00 TA P SURE Cut and slip drilling line 17:30 - 00:00 6.50 T A P SURE Wait on orders - Ríg maintenance 8/9/2006 00:00 - 12:00 12.00 TA P SURE Wait on orders - Cont. with rig maintenance I scrubbing rig floor and wind walls I paínting out side of rig - ( Circulate 10 bbls 9.8 ppg brine down tubing, observed returns at shakers I 4 bpm - 150 psi) 12:00 - 00:00 12.00 TA P SURE Wait on orders - Cont. with rig maintenance I scrubbing and painting wind walls and derrick legs { Circulate 10 bbls brine down tubíng, Observed returns at shakers 14 bpm 150 psi) Pumping I moving fluid down hole every 12 hrs. 8/10/2006 00:00 - 08:30 8.50 TA P SURE Wait on orders - Cont. with rig maintenance I painting derrick Printed: 8/28/2006 10:42:14 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-07 X-07 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/30/2006 Rig Release: 8/22/2006 Rig Number: 14 Spud Date: 4/14/1980 End: 8/22/2006 8/10/2006 00:00 - 08:30 8.50 TA P SURE legs and rig water tank ( pump 10 bbls 9.8 ppg brine to move fluid down hole every 12 hrs ) 08:30 - 12:00 3.50 TA P SURE PJSM - RD flowline I riser - Change out element in the annular 12:00 - 16:00 4.00 TA P SURE Cont. change element in the annular - MU riser / flowline 16:00 - 17:00 1.00 TA P SURE RU test Annular to 250 low I 3500 high for 5 min. on chart - RD test equipment 17:00 - 00:00 7.00 TA P SURE Wait on orders - Cont. with rig maintenance I scrub and painting I prep. rig tongs and lifting equipment for magna-flux inspection ( pump 10 bbls 9.8 ppg bríne to move fluid down hole every 12 hrs ) 8/11/2006 00:00 - 12:00 12.00 TA P SURE Wait on orders - Cont. with rig maintenance / cleaning I scrubbing and painting I prep. rig tongs and liftíng equipment for magna-flux inpection. ( Pump 10 bbls brine every 12 hrs. to move down hole fluid) 12:00 - 13:00 1.00 REST P SURE RO cleaníng and painting equipment - Prepare to resume workover operatíons 13:00 - 14:00 1.00 CLEAN P DECOMP RU floor equipment - Resume workover operations 14:00 - 15:30 1.50 CLEAN P DECOMP Circulate 9.8 ppg brine I Surface to surface I 265 gpm at 360 psi 15:30 - 16:00 0.50 PULL P DECOMP PU landing joínt - Screw into hanger 16:00 - 17:00 1.00 PULL P OECOMP BOLOS - Pull hanger to rig floor - LD same ( Cameron tested inner casing void between packoff and slips to 3500 psi f/10 minutes) 17:00 - 20:30 3.50 PULL P DECOMP PJSM - LO 41/2" 12.6# IBT L80 kill string 1x1 20:30 - 21 :30 1.00 FISH P DECOMP Clear rig floor - Install wear ring - Change out handing equipment 21 :30 - 00:00 2.50 FISH P DECOMP PJSM - MU mule shoe - RIH wI 4" drill pipe 1x1 to 2848' 8/12/2006 00:00 - 00:30 0.50 FISH P OECOMP Cont. RIH wI 4" drill pipe to 3513' 00:30 - 05:30 5.00 FISH P OECOMP Circ. 9.8 ppg surface volume in mud píts through Hot oil unit to heat fl 55 degrees to 120 degrees 05:30 - 06:30 1.00 FISH P OECOMP Oisplace hole at 3513' with brine heated to 120 degrees 1310 gpm at 700 psi 06:30 - 08:00 1.50 FISH P DECOMP POH f/3513' to surface - LO mule shoe 08:00 - 09:30 1.50 BOPSU P OECOMP Pull wear ring - PU install test plug - RU testing equipment 09:30 - 13:30 4.00 BOPSU P DECOMP Test BOPE - Test annular, Test upper 27/8" x 5" VBRs, 3.5" x 6" lower VBRs using 4" test joint, Test Blind rams - HCR killlchoke, Manual killlchoke, Choke manifold, upper I lower IBOP, surface valves to 250 psi low - 3500 psi high for 5 minutes each. Performed accumulator test - Lou Grimaldi wíth AOGCC waived witness of test - WSL witnessed all test - RD testíng equipment - Install wear ring 13:30 - 16:00 2.50 MOB P OECOMP MU - Baker multi-string casing cutter assembly - PU - 6 3/4" drill collars fl pipe shed 1 x1 16:00 - 17:00 1.00 MOB P OECOMP RIH wI 4" drill pipe to 2165' - Break círc to extend kníves 1134 gpm I 730 psi - Cont in hole Locate collar at 2183' - PU 97k - SOW 97k 17:00 - 18:00 1.00 FISH P OECOMP Pull up hole 20' to 2163' - Cut 9 5/8" casing - 250 GPM - 2200 PSI - RPM 50170 - TQ 31 5 K 18:00 - 18:30 0.50 FISH P DECOMP Shut down pump - Close pípe rams - Bring pump up slowly to 2 bpm - 2350 psi, pumping down 4" drill pipe taking returns through cut 9 5/8" casing at 2163' - Observed fluid returns from OA at tiger tank - Pumped 5 bbls total (pump pressure broke back at 2350 psi to 1950 psi after 4 bbls pumped) Printed: 8/28/2006 10:42: 14 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-07 X-07 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/30/2006 Rig Release: 8/22/2006 Rig Number: 14 Spud Date: 4/14/1980 End: 8/22/2006 8/12/2006 18:30 - 20:00 1.50 FISH P DECOMP LD single joint - RU hot oíl unít - PJSM - Pressure test line from Hot oíl unit to 3100 psi - Pump 33 bbls fresh water heated to 120 degrees from mud pits - 5.8 BPM 12250 PSI, taking returns up the IA - Shut down pump - Close pipe rams - Une up on Hot oil unit - Start pumping 132 bbls diesel at 125 degrees - 2 BPM I 2050 PSI - Monítored full returns at tiger tank - Final pressure 850 PSI at 2 BPM - Pump 23 bbls hot fresh water to displace diesel from drill pípe and spot in OA. 20:00 - 21 :30 1.50 FISH P OECOMP Wait on diesel to soak in OA for 1 1/2 hrs. 21 :30 - 23:30 2.00 FISH P OECOMP Pump 100 bbls hot water - 4.5 BPM 11630 PSI - Une up on Hot oíl unit - Pump 68 bbls diesel at 120 degrees - 2 BPM I 1000 PSI - Cont. to monitor full returns from OA at tiger tank 23:30 - 00:00 0.50 FISH P OECOMP Shut down pump - Let diesel migrate up hole 8/13/2006 00:00 - 01 :00 1.00 FISH P OECOMP Shut down pump - Let diesel migrate to surface 01 :00 - 02:00 1.00 FISH P OECOMP Resume pumping - Cont. circulate diesel out of 13 3/8" x 9 5/8" OA wI 120 degree hot water - 4 BPM 11500 PSI 02:00 - 03:00 1.00 FISH P OECOMP Pump 40 bbls High polymer sweep - Displaced dríll pipe and OA with 9.8 ppg brine water 5 BPM / 2400 PSI 03:00 - 03:30 0.50 FISH P DECOMP Shut down pump - Une up on IA and pump 50 bbls 9.8 ppg brine círculate 9 5/8" annulus to clear trapped I migrating diesel 03:30 - 06:00 2.50 OHB P DECOMP POH 3 stands - PU and set storm packer 1 stand below rotary table - LD running tool - Test to 3500 psi f/ 15 mínutes - Pull wear ring 06:00 - 09:00 3.00 DHB P DECOMP Install test plug - Change top 2 7/8" x 5" VBRs to 95/8" casing rams - Test casing rams to 250 psí low - 3500 psi high fl 5 minutes each, recorded on Chart 09:00 - 11 :00 2.00 BOPSU DECOMP NO BOP stack - Pull tubing spool and prepare slips for pullíng casing 11 :00 - 14:00 3.00 FISH DECOMP NU BOP - Install spacer spool - Installed choke hose extension to fit new stack configuration 14:00 - 15:00 1.00 BOPSU OECOMP RU test equipment - Test spool breaks and choke to 250 psi low - 3500 psi high for 5 mínutes, recorded on Chart 15:00 - 18:00 3.00 REST N OECOMP Blockage occured ín choke line as pressure was bled off - RD and located piece of lead babbit in choke line that had become dislodged - installed back into target blank and secured in choke líne 18:00 - 20:00 2.00 BOPSU P DECOMP MU all breaks on choke line - Test choke line breaks to 250 psi low - 3500 psi high for 5 minutes - Recorded on Chart 20:00 - 21 :00 1.00 OHB P DECOMP RIH wI storm packer retrieval tool - Screw into storm packer - Pull to rig floor and LO 21 :00 - 23:00 2,00 FISH P DECOMP POH w/ 4" drill and drill collars - POH wI Baker multi-stríng cutter assy. - LD cutter assy. 23:00 - 00:00 1.00 FISH P DECOMP PU Baker 9 5/8" spear assy. to rig floor - PJSM - MU BHA 8/14/2006 00:00 - 01 :00 1.00 FISH P DECOMP MU Baker spear assy 01 :00 - 02:00 1.00 FISH P DECOMP RIH wíth spear - Spear casg - Set grapple - PU 170 - SO - PU 240 Pipe jumped 3 to 4" pull to 250 No movement - SO - PU 310 pipe moved up 2" pull to 320 No movement - SO - PU 325 pipe moved 2" - Hand called from cellar - Stack moving 2 to 3" Up on pulls - Same distance down on slack off - Checked Well head in cellar - PU 325K Mandral on 133/8" casíng moving up 2" - SO Mandral moved down same dístance - Total movement on 9 5/8" casíng 7 to 8" up - 133/8" 2 to 3" up and settling Printed: 8128/2006 10:42:14 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-07 X-07 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/30/2006 Rig Release: 8/22/2006 Rig Number: 14 Spud Date: 4/14/1980 End: 8/22/2006 8/14/2006 01 :00 - 02:00 1.00 FISH P DECOMP down same dístance - (See remarks) 02:00 - 03:00 1.00 FISH P DECOMP Nipple down flow line - Back all LDS out - Inspect all LOS - All LOS ok none broke - Re-install LDS 03:00 - 04:00 1.00 FISH P DECOMP PU 350K 9 5/8" casing moved 6" - 13 3/8" casing moved up 1" - Stopped - Weight bled off to 265K - !3 3/8" casing settled 1" down - PU 325K 9 5/8" casing moved up l' - 13 3/8" casing moved up 1/2" - Stopped - Weight bled off to 240 - 133/8" casing settled 1" - PU 275K 9 5/8" casing moved up l' - 13 3/8" casing did not move - Weight bled off to 225 - PU 280 to 210K 9 518" casing moved up 35' - 13 3/8" casíng stable - No Movement - (Emergency slips at floor) 04:00 - 05:00 1.00 FISH P DECOMP Remove emergency slips - Re-install flow line - Center stack and riser 05:00 - 06:30 1.50 FISH P OECOMP Break circulation - 4 BPM - 650 psi - No Returns - Weíght on string dropped from 200 to 150K - Packed off - Shut down pump - Slack off taking weight - PU to 210K - Pressure dropping - Pump 2 BPM 180 psi - Increase pump to 5.5 BPM @ 400 psi - 1 st 48 bbls bbls pumped lots gas back with artic pack - Rolling I belching in drlg nipple - after 50 bbls pumped gas dissipated - Con't pumping bottoms up 5.5 BPM @ 400 psi - Pump 40 bbl Hi-vis sweep - 7 BPM @ 540 psi surface to surface 06:30 - 07:00 0.50 FISH P OECOMP LD cut joint I Baker spear - (Cut length laíd down 33.94') 07:00 - 08:30 1.50 FISH P OECOMP RU 9 5/8" casing tools 08:30 - 12:30 4.00 FISH P DECOMP Pulling and LD 9 5/8" casing - PU 175 to 250 - Not able to slack off taking weight - Hole swabbing - Filling hole thru casing - Fill = swab volume plus 3.5 blls displacement every 5 joínts pulled - Topping off every 10 joints pulled - Steaming every connection - 35 to 40K to break - Break with rig tongs - Back out with power tongs - (Problems with Doyon air valve for rig tongs) - Total joints laid down 14 12:30 - 13:00 0.50 FISH P DECOMP Ríg Service - Lubricate rig 13:00 - 15:00 2.00 FISH N RREP DECOMP Work on E-Z Torque units 15:00 - 16:00 1.00 FISH P DECOMP Con't LO 9 5/8" casíng - Break with rig tongs - Back out with power tongs - Total joints laid down 2 = 16 Cum 16:00 - 18:00 2.00 FISH N RREP OECOMP Work on E-Z Torque units - Shuttle valve bad - Replace seal on valve 18:00 - 00:00 6.00 FISH P DECOMP Con't LD 9 5/8" casing - Break with rig tongs - Back out with power tongs - Total joínts laid down 23 = 39 Cum 8/15/2006 00:00 - 02:00 2.00 FISH P DECOMP Con't LD 9 5/8" casíng - Pull joints 38 to 42 - Starting with joint # 40 pulling 150 to 300K - Flow line plugging off with cement slabs and Artic pack - Flushing flowline attempt to keep open (estimate depth of cement starting @ 1650') 02:00 - 03:30 1.50 FISH P DECOMP Shut down pulling casíng - Clean out possum belly on shaker box - Flowline - Cement dump on shaker box - All plugged up with cement / Artic pack 03:30 - 04:30 1,00 FISH P DECOMP Con't LD 9 518" casing from joints 43 to 44 - 100 to 300K pull - Flow line plugged - Riser full 04:30 - 08:30 4.00 FISH P OECOMP Clean out flow line - Take off flow sensors - clean out flow line - Pull mud bucket drain - Flush I clean flowline - Shorten to eliminate 90 degree elbow to possum belly - to help keep flow line clear 08:30 - 11 :30 3.00 FISH P OECOMP Con't LD 9 5/8" casing from joints 45 to 53 (UO 53 total full Printed: 8/28/2006 10:42:14 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-07 X-07 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/30/2006 Rig Release: 8/22/2006 Rig Number: 14 Spud Date: 4/14/1980 End: 8/22/2006 8/15/2006 08:30 - 11 :30 3.00 FISH P DECOMP joints, top cut jt 33.94', bottom cut joint 19,95') 11 :30 - 12:30 1.00 FISH P DECOMP RID casing equipment and clear floor 12:30 - 14:00 1.50 FISH P DECOMP PIU cut joint with spear - Oisengage spear - UD cut joint- Service break spear assembly - Clear ríg floor 14:00 - 15:30 1.50 FISH P OECOMP Wash and flush on stack - Flush and clean lines of cement and artic pack 15:30 - 19:00 3.50 BOPSU P DECOMP Install test plug - Change top rams to 2 718" X 5" - Open and clean all ram cavities 19:00 - 20:00 1.00 BOPSU P DECOMP Body test BOP stack and test top rams to 250 psi low, 3500 psi high for 5 minutes each 20:00 - 21 :30 1.50 CLEAN P DECOMP M/U 12 1/4" bit and cleanout BHA 21 :30 - 00:00 2.50 CLEAN P DECOMP Wash and ream from 300' to to 1827' (10 BPM @ 650 psi, 60 RPM) 8/16/2006 00:00 - 01 :30 1.50 CLEAN P OECOMP Continue wash and ream from 1827' to 2163' - 5 to 10k bit weight from 2130' to 2163' - (PU 95, SO 95, RW 95, 100 spm @ 730 psi, 60 RPM, 1 K TO) 01 :30 - 02:30 1.00 CLEAN P OECOMP Pump 30 bbl hi-vis sweep - Oisplace well with clean 9.8 brine (100 spm @ 730 psi, 60 RPM @ 1K TO, PU 95, SO 95, RW 95) 02:30 - 03:00 0.50 CLEAN P OECOMP Flow check - Started POH, pulling 30 to 40 Kover - Turned on pumps, pipe freed up (cement cuttings) 03:00 - 04:00 1.00 CLEAN P OECOMP Pump hi-vis sweep - Circulate hole clean - R & R (60 RPM @ 1 K TO, 100 SPM @ 730 psí) 04:00 - 05:00 1.00 CLEAN P OECOMP Flow check - POOH 05:00 - 06:00 1.00 CLEAN P OECOMP Stand back drill collars - C/O BHA to 8 1/2" cleanout assembly 06:00 - 07:30 1.50 CLEAN P DECOMP RIH to 2800' ( No problems) 07:30 - 08:30 1.00 CLEAN P OECOMP CBU - R & R (60 RPM @ 1K TO, 100 SPM @ 840 psi) 08:30 - 09:30 1.00 CLEAN P OECOMP POOH 09:30 - 11 :00 1.50 CLEAN P DECOMP UD BHA - Mobilíze washpipe assembly to floor 11 :00 - 14:00 3.00 CLEAN P OECOMP M/U washover BHA 14:00 - 15:00 1.00 CLEAN P OECOMP RIH with washpipe assembly 15:00 - 15:30 0.50 CLEAN P OECOMP Washover stub and collar from 2163' to 2191' - 3K weíght on bit to wash over cement ( PU 96, SO 96, RW 96, 85 SPM @ 520 psi) 15:30 - 16:30 1.00 CLEAN P OECOMP Pump hí-vis sweep and circulate hole clean (120 SPM @ 1070 psi) 16:30 - 17:00 0.50 CLEAN P DECOMP POOH wíth washover pipe 17:00 - 19:30 2.50 CLEAN P OECOMP Stand back collars - UD washover pípe BHA - Clear floor 19:30 - 21:00 1.50 EVAL P DECOMP PJSM - RlU SWS 21 :00 - 22:00 1.00 EVAL P DECOMP RIH with SWS three strand string shot and locate collar at 2180' - First run mísfired, Second run fíred 22:00 - 23:00 1.00 EVAL P DECOMP RlOSWS 23:00 - 00:00 1.00 FISH P DECOMP M/U 9 5/8" backoff BHA 8/17/2006 00:00 - 00:30 0.50 FISH P DECOMP Continue M/U 9 5/8" backoff assembly 00:30 - 02:30 2.00 FISH P OECOMP RIH (fill every 5 stands with fresh water) 02:30 - 04:30 2.00 FISH P DECOMP Set backoff tool per Baker Rep - Collar at 2183', pressure up to 3200 psi on backoff tool to break connection - 1200 psi to 600 psi on backoff tool to continue to break out connection for a total of 6 full turns 04:30 - 05:30 1.00 FISH P DECOMP POOH 05:30 - 07:30 2.00 FISH P OECOMP Stand back collars - UO BHA - Clear floor 07:30 - 08:00 0.50 FISH P DECOMP MlU spear assembly Printed: 8/2812006 10:42:14 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-O? X-O? WORKOVER DOYON DRILLING INC. DOYON 14 Start: ? /30/2006 Rig Release: 8/22/2006 Rig Number: 14 Spud Date: 4/14/1980 End: 8/22/2006 08:00 - 08:30 FISH DECOMP 08:30 - 09:00 FISH DECOMP 09:00 - 10:00 1.00 FISH DECOMP 10:00 - 10:30 0.50 FISH DECOMP 10:30 - 11 :00 0.50 BOPSU DECOMP 11 :00 - 12:00 1.00 BOPSU DECOMP 12:00 - 13:00 1.00 BOPSU OECOMP 13:00 - 13:30 0.50 BOPSU DECOMP 13:30 - 14:30 1.00 CASE DECOMP 14:30 - 20:00 5.50 CASE DECOMP 20:00 - 20:30 0.50 CASE P DECOMP 20:30 - 21 :00 0.50 CASE P OECOMP 21 :00 - 21 :30 0.50 CASE P DECOMP 21 :30 - 22:30 1.00 CASE P DECOMP 22:30 - 00:00 1.50 REMCM P DECOMP 8/18/2006 00:00 - 01 :00 1.00 REMCM DECOMP 01 :00 - 02:00 1.00 BOPSU DECOMP 02:00 - 03:00 1.00 BOPSU DECOMP 03:00 - 03:30 0.50 BOPSU DECOMP 03:30 - 06:00 2.50 BOPSU DECOMP 06:00 - 08:00 2.00 BOPSU DECOMP 08:00 - 09:30 1.50 BOPSU OECOMP 09:30 - 13:00 3.50 BOPSU OECOMP 13:00 - 14:00 1.00 BOPSU P OECOMP 14:00 - 15:30 1 .50 CLEAN P DECOMP 15:30 - 17:00 1.50 CLEAN P DECOMP 17:00 - 17:30 0.50 CLEAN P DECOMP 17:30 - 18:00 0.50 CLEAN P DECOMP 18:00 - 19:30 1.50 CLEAN P OECOMP 19:30 - 20:00 0.50 CLEAN P OECOMP 20:00 - 21 :00 1.00 CLEAN P OECOMP 21 :00 - 22:00 1.00 CLEAN P OECOMP 22:00 - 22:30 0.50 CLEAN P DECOMP 22:30 - 23:00 0.50 CLEAN P DECOMP RIH to 2163' Engage fish and back out cut joint POOH wI cut off joint UD BHA & Fish ( cut jt = 19.26') Pull wear ring and install test plug Change top rams to 9 5/8" solid body RlU and test rams to 250 psi low, 3500 psi high for 5 mínutes each Pull test plug RlU to run 9 5/8" 40# TC-II L-80 casing PJSM - Run 9 518" 40# casíng filling every 5 stands ( 54 jts ran, PU 125, SO 120, RW 118) RID casing equipment Engage screw-in sub @ 2181' with tieback assembly ( 11 rounds = 10K torque) Change to long bails and M/U cement head Test 9 5/8" casing to 2000 psi for 15 minutes - Shear out ES cementer @ 2500 psi - Establish circulation at 100 psi @ 40 SPM Cement 9 5/8" casing per plan - ( 5 bbls H20, test lines to 4500 psí, pump 140 bbls 15.8 ppg class G cmt, drop closing plug, displace with rig pumps 9.8 brine total 1620 strokes, bumped plug, closed ES cementer with 1600 psi, pressured up to 2000 psi, bled off, checked ES cementer (closed), 19 bbls cement back to surface, cement in place @ 2352 hours) RIO cement head and void fluíd from landing joint N/D and raise BOP stack Install emergency slips with primary seal with 125K weight on slips - RILO's to energize seals Cut 9 5/8" casing with Wachs cutter (cut jt = 28.16) Install tubing spool - Pump in plastic seal material - Test Packoff to 3000 psi for 30 minutes Nipple up BOP Change out top rams to 2 7/8" X 5" VBR's Test BOPE - Test annular, Test upper VBR's, Test lower VBR's, Test blind rams, Test HCR kill/choke, Manual kill/choke, Choke manífold, Upperllower IBOP, Surface valves to 250 psi low, 3500 psi high for 5 minutes each, Performed accumulator test, Tested alarms on PVT, flow, trip tank, and gas alarms - Witnessed by AOGCC rep Jeff Jones and WSL UO test plug and install wear ring M/U 8 1/2" drillout Assembly Wait on cement RIH to 2100' Waít on cement - Verified UCA 1000 psi with Schlumberger lab Tag cement @ 2166' - Drill cement and ES cementer to 2176' (PU 95, SO 98, RW 98, 570 psi @ 85 SPM) Círculate hole clean (910 psi @ 110 SPM) RlU and test 9 5/8" casing to 3500 psi for 30 minutes Drill Baffle Plate RIH to 3450' Tag old cement cuttings and artic pak @ 3520 - Wash and ream to 3570' Printed: 8/28/2006 10:42:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-O? X-O? WORKOVER DOYON DRILLING INC. DOYON 14 Start: ? /30/2006 Rig Release: 8/22/2006 Rig Number: 14 Spud Date: 4/14/1980 End: 8/22/2006 8/18/2006 23:00 - 00:00 1.00 CLEAN P DECOMP CBU and verify sand in returns - Pump hi-vís sweep - Oisplace with clean seawater 8/19/2006 00:00 - 00:30 0.50 CLEAN P OECOMP Cont displace with clean seawater @ 450 gpm = 1080 psi, 80 RPM 00:30 - 01 :00 0.50 CLEAN P OECOMP Flow check - POOH from 3570' to 2000' 01 :00 - 03:00 2.00 CLEAN P DECOMP RlU - Test 9 5/8" casing to 3500 psi for 30 mínutes on chart - RIO test equipment 03:00 - 03:30 0.50 CLEAN P DECOMP POOH to BHA 03:30 - 04:00 0.50 CLEAN P DECOMP Stand back collars - UO drilling assembly 04:00 - 05:00 1.00 CLEAN P DECOMP M/U Reverse junk basket assembly 05:00 - 06:00 1.00 CLEAN P DECOMP RIH to 3540' 06:00 - 08:00 2.00 CLEAN P OECOMP Wash wíth reverse junk basket from 3540' to 3601' (PU 115, SO 117, RW 115, TO 5K @ 60 RPM, 244 gpm @ 2940 psi) 08:00 - 09:30 1.50 CLEAN P DECOMP POOH to BHA 09:30 - 10:30 1.00 CLEAN P DECOMP Stand back collars - UO reverse junk basket assembly 10:30 - 11 :00 0.50 CLEAN P DECOMP M/U Baker RBP retrieving tool 11 :00 - 12:30 1 .50 CLEAN P DECOMP RIH to 3601 - Attempt to latch RBP - No success 12:30 - 13:30 1.00 CLEAN P DECOMP Reverse círculate with hydríl (240 psi @ 40 SPM) - Wash down to 3604' with posítíve latch on RBP 13:30 - 14:00 0.50 CLEAN P OECOMP Clear slush and ice from derrick 14:00 - 16:00 2.00 CLEAN P DECOMP POOH with RBP 16:00 - 16:30 0.50 CLEAN P DECOMP UD Baker retrieving tool and RBP 16:30 - 17:00 0.50 CLEAN P DECOMP M/U HES retrieval tool - RIH with drill pipe from derrick 17:00 - 18:30 1 .50 CLEAN P DECOMP PJSM - P/U drill pipe singles from pipeshed and RIH to 4282' 18:30 - 19:00 0.50 CLEAN P OECOMP Servíce and lubricate rig 19:00 - 19:30 0.50 CLEAN N RREP OECOMP Díagnose and fix skate malfunction 19:30 - 23:30 4.00 CLEAN P OECOMP Continue RIH with dríll pipe singles from pipeshed to 9862' 23:30 - 00:00 0.50 CLEAN P DECOMP PJSM - Cut and slip drill line 8/20/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP PJSM - Contínue cut drill line 01 :00 - 02:30 1.50 DHB P DECOMP Break cir @ 9862' 168 gpm @ 360 psi - Engage RBP - Worked RPS loose (30K overpull), - Well went on vacuum, pumping 10 bbls seawater every 15 minutes and twice the pipe displacement every 5 stands 02:30 - 07:00 4.50 CLEAN P DECOMP POOH with RBP (5 to 10K overpull first 5 stands) pumping 10 bbls seawater every 15 minutes and twíce the drill pipe displacement every 5 stands 07:00 - 07:30 0.50 CLEAN P DECOMP Service break running tools - UD RSP (Rubbers off RSP were left downhole) 07:30 - 08:30 1.00 CLEAN P OECOMP Wait on orders (Discussing with town problems wíth RBP rubbers left downhole and solutíons) 08:30 - 09:30 1.00 CLEAN P DECOMP M/U 8 1/2" cleanout assembly 09:30 - 12:00 2.50 CLEAN P DECOMP RIH to 9975' - Wash down tag packer at 10002' (200 gpm @ 180 psi) 12:00 - 12:30 0.50 CLEAN P DECOMP Rotate and break up rubber seals from RSP @ 10002' (top of packer) 12:30 - 16:00 3.50 CLEAN P OECOMP POOH to SHA 16:00 - 17:00 1.00 CLEAN P OECOMP Stand back collars - UD cleanout assembly 17:00 - 18:00 1.00 CLEAN P DECOMP Clear floor - RlU for 2.875 PAC drill pipe 18:00 - 20:00 2.00 CLEAN P DECOMP PJSM - M/U 3.7" 5-bladed mill assembly 20:00 - 23:00 3.00 CLEAN P DECOMP RIH to 9934' 23:00 - 00:00 1.00 CLEAN P DECOMP Sting into 4.5" tubing @ 10002' - Wash down to plug @ 10026' - Mill on plug @ 10026' (PU 220, SO 155, RW 182,65 RPM @ 5K TO, 40 SPM @ 760 psi) Printed: 8/28/2006 10:42: 14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-07 X-07 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/30/2006 Rig Release: 8/22/2006 Rig Number: 14 Spud Date: 4/14/1980 End: 8/22/2006 8/21/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP Continue milling from 10026' to 10027' - Well went on vacuum - Work tight pipe back out of 4.5" tubíng ( 30K overpull) - Sting back ínto 4.5" tubing and push plug to 10126' - Bottom of tail pípe @ 10107' - (PU 210, SO 160, RW 180,65 RPM @ 7K TO, 98 gpm @ 100 psi) 01 :30 - 09:30 8.00 CLEAN P DECOMP PJSM - POOH UD 4" drill pipe 09:30 - 11 :30 2.00 CLEAN P OECOMP UO collars, jars, 27/8" PAC drill pípe, and mill 11 :30 - 12:00 0.50 CLEAN P DECOMP Clear rig floor 12:00 - 12:30 0.50 BOPSU P OECOMP Pull wear ríng 12:30 - 14:00 1.50 BOPSU P DECOMP Install test plug - RlU and test top rams with 4.5" test joint, 250 psi low, 3500 psi high for 5 minutes each - RID test equipment and pull test plug 14:00 - 15:30 1.50 EVAL P DECOMP Change out saver sub 15:30 - 17:00 1.50 CASE P OECOMP RlU to run 4.5" 12.6# Vam Top 13CR80 tubing using torque turn services 17:00 - 00:00 7.00 CASE P DECOMP Run 4.5" 12.6# Vam Top 13cr80 tubing per plan (5713' @ 0000 hrs) 8/22/2006 00:00 - 04:30 4.50 CASE P DECOMP Contínue run 4.5" 12.6# Vam Top 13cr80 tubing per plan (from 5713' to 9862') 04:30 - 05:30 1.00 CASE P DECOMP M/U tubing hanger - Land tubing - RILO's ( bottom @ 9908') ( PU 155, SO 130) 05:30 - 08:30 3.00 CASE P DECOMP RlU - Pump 423 bbls 140 degree seawater with 2 drums corrosion inhibitor and 45 bbls seawater at 3 BPM = 200 psi down IA (well stíll on vacuum, no returns) 08:30 - 10:30 2.00 CASE P DECOMP Set packer - Test tubíng to 3500 psi for 30 mínutes on chart - Bleed tubing down to 1500 psi - Test IA to 3500 psi for 30 minutes on chart - Bleed off tubing and shear OCK valve at 600 psi 10:30 - 11 :30 1.00 CASE P DECOMP RIO landing joint - Install TWC - Test TWC to 1000 psi from below 11 :30 - 13:00 1.50 BOPSU P OECOMP NID BOPE 13:00 - 17:00 4.00 WHSUR P DECOMP N/U adapter flange and tree - Test flange to 5000 psi for 30 minutes - Test tree to 5000 psi for 10 minutes 17:00 - 18:00 1.00 WHSUR P DECOMP RlU lubricator with DSM and pull TWC 18:00 - 20:00 2.00 WHSUR P DECOMP RlU Hot Oíl - PJSM - Pump 145 bbls diesel freeze protect to IA ( 350 psi @ 2.5 BPM) 20:00 - 21 :30 1.50 WHSUR P DECOMP Allow diesel to equalize between IA and tubing 21 :30 - 22:30 1.00 WHSUR P DECOMP Set BPV with OSM 22:30 - 23:00 0.50 WHSUR P DECOMP Test BPV with Hot Oil to 1000 psi for 10 minutes 23:00 - 00:00 1.00 WHSUR P DECOMP Secure well - Release rig 8/23/2006 00:00 - 0.00 WHSUR DECOMP Printed: 8/28/2006 10:42:14 AM ~~~......".. ) r·;1--' > . ", L .~Li- 1::; 'w0o Scblumberger NO. 3941 ~Ðif & Gas GeM. Ccmrniam Ar.cr.crage State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth J~O -0(3 Company: SCANNED SEP 1 4 2005 x - o-::¡- (M~o",-L~) Field: Prudhoe Bay BL C C Well Job# Loa Descrintion Date olor D C 1A 11225983 LDL 07/02/06 1 B 5 11217247 LDL 05/11/06 1 F- 6A 11258688 PROD PROFILE W/DEFT 03/20/06 1 G- 8A 11209612 MEM INJECTION PROFILE 07/19/06 1 P- 4 11216206 MEM INJECTION PROFILE 07/06/06 1 B- 8 11221590 LDL 07/04/06 1 B 1 11211508 PROD LOG W/DEFT 06/23/06 1 W- 9A 11216197 MEM PROD PROFILE OS/29/06 1 ZoO A 11212856 INJECTION PROFILE 05/02/06 1 G-D A 11211493 LDL OS/24/06 1 C-2 A 11225979 LDL 06/07/06 1 F-2 B N/A MEM PROD & INJECTION 06/06/06 1 F-2 B N/A MEM BORAX LOG 06/06/06 1 W-3 A 11216197 MEM BORAX LOG OS/29/06 1 F-O A 11221602 SCMT 08/18/06 1 Y-O ~ 11221604 SCMT 08/20/06 1 CoO B 11212883 US IT 08/15/06 1 X-2 11217274 US IT 08/26/06 1 K-D7 10942217 MEMORY SCMT 06/15/05 1 Y-10 11209611 MEM INJECTION PROFILE 07/18/06 1 F-1 11225984 LDL 07/02/06 1 K-07 D 11058256 SBHP SURVEY 11/28/05 1 X-O 10919925 PROD PROFILE W/DEFT 12/15/04 1 A-3 A 11054295 CH EDIT OF PDC LOG W/GR 04/06/05 1 17,,( B 40010183 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 03/09/04 1 1 Z-3 A 40010092 OH EDIT OF MWD/LWD (REDO OF TVD DATA) 01/27/04 1 1 17-04 PB1 40010183 OH EDIT OF MWD/LWD 03/08/04 2 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 08/28/06 . . ~p~ lA', e>~j U lr~ lJ ?'~' ~,~. f,'~ [, ['" Î,' ,'' CJ,/11 \\ J U I r' ~~,' L" t !Ó~ .J L 1"1,7," ~, f\\ J L~ . FRANK H. MURKOWSKI, GOVERNOR ALASHA OIL AND GAS CONSERVATION COMMISSION 333 W 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU X-07 Sundry Number: 306-273 \~D' 0 ~"?:> 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this/bday of August, 2006 Enc!. p a II t,/Je f(Í5Þb AIIAO~ t1 oft _ ~ / Jc;STATE OF ALASKA a , y'r. \b~ ALASKAOILANDGASCONSERVATIONCOM~ON AUG 1 4 2006 APPLICATION FOR SUNDRY APPROV ALAI k 0'1.' G C C ,. 20 MC 25.280 as a I 01 as ons. OfT1ß1ISSlon RE~1v~l)J2-00(" 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate . _~!!c"oraue o Time Extension o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver 181 Other / Restart Ocerations after Shutdown 2. Operator Name: 4. Current Well Class: // 5. Permit T~rill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 180-013 305-366 I ? 3. Address: D Stratigraphic D Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20441-00-00 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: PBU X-07 / Spacing Exception Required? DYes 181 No g, Property Designation: /10. KB Elevation (ft): 11. Field I Pool(s): ADL 028313 73.6' Prudhoe Bay Field I Prudhoe Bay Pool 12. '. PRESENt WELL CONDITION$UMMARY' ,.,/.. ,.". . , Total Depth MD (ft): Total Depth TVD (ft):Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11691 9617 11638 9572 3607 (Upper) None Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 110' 30" x 20" 110' 110' Surface 2695' 13-3/8" 2695' 2695' 4930 2670 Intermediate 10568' 9-5/8" 10568' 8671' 8150 5080 Production Liner 1631' 7" 1 0059' - 11690' 8267' - 9616' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 10734' - 10876 8802' - 8918' 4-1/2", 12.6# L-80 & 13Cr -3200 & 1001' - '10111' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW 'HBBP-R' packer I Packers and SSSV MD (ft): 10001' 13. Attachments: 14, Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch // D Exploratory 181 Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: CommencinQ Operations: August 11 , 2006 181 Oil DGas D Plugged D Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Doug Cismoski, 564-4303 Printed Name Doug Cismoski Title Drilling Engineer Prepared By Name/Number: Signature Ä /zb,,¿ Z , Phone 564-4303 Date Terrie Hubble, 564-4628 p/ Commission Use Onlv Conditions of approval: Notify Commission so that a representative may witness I Sundry Number:6fxo - :J.71.:S D Plug Integrity ~OP Test ~echanicallntegrity Test D Location Clearance Other: T~t- ßOPE t-o ~ÇOO ý> r...:. n) RBDMS BFL AUG 1 7 2006 Subsequent Form Required: \0 - ~0Y/): ~ ~ /6/r;J; ,-)," ~MISSIONER APPROVED BY Approved By: THE COMMISSION Date Form 10-403 Revised 06/2006 VÀV s/bmit (n Duplicate ORIGtN " . STATE OF ALASKA . ALA~ OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Ops Shutdown due to Field Shutdown 1. Type of Request: o Abandon o Suspend 181 Operation Shutdown o Perforate o Time Extension o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5, Permit To Drill Number BP Exploration (Alaska) Inc, 181 Development D Exploratory 180-013 I 305-366 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20441-00-00 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: PBU X-07 Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028313 73.6' Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11691 9617 11638 9572 3607 (Upper) None C~!;ina Lenoth Size MD TVD Burst Collapse Structural Conductor 110' ~O" x 20" 110' 11n' Surface 2695' 13-3/8" 2695' 2695' 4930 2670 I ntArmediate 1 0568' 9-5/8" 10568' 8671' 8150 5080 Production Liner 1631' 7" 1 0059' - 11690' 8267' - 9616' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 10734' - 10876 8802' - 8918' 4-112", 12,6# L-80 & 13Cr -3200 & 1.óIe'T' - '10111' ðCIO\ Packers and SSSV Type: 9-5/8" x 4-1/2" TIW 'HBBP-R' packer packers and SSSV MD (ft): 10001' 13. Attachments: 14. Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service o Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: CommencinQ Operations: August9,2006 181 Oil DGas D Plugged D Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed NamÇj{d Room Title Dr;n;ng Eng;noor Prepared By Name/Number: Signature ~f¿ PAA;-t Phone 564-5743 Date t -tD-tt Terrie Hubble, 564-4628 Commission Use Onlv I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance Other: Subsequent Form Required: APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Revised 0612006 Submit In Duplicate " . . X-07 Well Status: Well is secured with two RBPs, The lowest at 9940 MD, pressure tested to 3500 psi and the second set at 3607 MD , pressure tested to 1000 psi. Well has a kill string run to 3200 MD. Scope: Retrieve existing 4.5", 12,6#, L-80 completion, Replace 2000' of 9 5/8" casing and cement to surface, Re-complete with 4,5", 12.6#/ft, 13Cr80 Vam Top tubing with 9 5/8" x 4-1/2" packer. RWO OPERATIONS: Over the course of the past week, the scope of the RWO has been completed up to the replacement of 2000' of 9 5/8" casing and cement to surface. We are currently halting operations due to a field wide shutdown. An RBP was set at 9940' MD with a 3500 psi pressure test. Another RBP was set at 3607 MD and 40 ft of sand was set on top of it. This RBP was tested to 1000 psi. A kill string was run to -3200' MD. TREE = . 'Wa.LHEAO = A C'TUA TOR = KB. a.EV = BF. a.EV = KOP= Max Angle = Datum MD = Datum TVO = . 7-1/16" 5M CrN 13-5/8" 5M MCEVOY OTIS 73.60' 39.80' 3200' 52 @ 5700' 10810' 8800' SS 113-3/8" CSG. 72#, L-80. ID = 12,347" H 2693' I 4-1/2" TBG, 12.6#, 13CR-95, V AM- TOP H Minimum 10 = 3.725" @ 10063' 4-1/2" PARKER SWN NIPPLE TOPOF 7" LNR I 14-1/2" TBG. 12,6#. 13CR, 0,0152 bpf, 10= 3.958" I X-07 S~OTES: *** POSSIBLE IA X OA COMM. OP~NG PRESSURE OF THE 13·3/8" ANNULUS MUST NOT EXCEED 2000 PSI (10/12/02 W AlVER)***4-112" CHROME TBG 2615' H 9-5/8" OV A<R I -3200 H 4-1/2" HES X NIP. 10 = 3.813" 3283' H 4 -1/2" WLEG I 3607' H 9 5/8" RBP I 9940' H 9 5/8" RBP ...J 9-5/8" x 4-1/2" TrN HBBP-R A<R, 10 = 4.0" H 4 1/2" Fas-Dril plug I ...J 4-1/2" PARKER SWS NIP, 10 = 3,813" I 1...J4-1/2" PARKER SWN, NIP, 10 = 3.725" I 10107' ...J 4-1/2" WLEG. 10 = 3.958" I H a.MO TT LOGGED 04/23/91 I 19-5/8" CSG, 47#, L-80, 10 = 8,681" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 05/05/80 ANGLEATTOPÆRF: 32@ 10734' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 10734 - 10761 0 05/16/94 3-3/8" 6 10846 - 10876 0 01/03/91 3-3/8" 6 10886 - 10906 C 01/03/91 2-7/8" 4 10916 - 10928 S 12/29/90 3-3/8" 4 10938 - 10943 S 12/29/90 I 7" LNR, 29#, L-80, 0.0371 bpf, 10 = 6.184" DATE 05/09/80 04/13/91 10/12/02 12/11/03 04/13/06 04/13/06 REV BY COMMENTS ORIGINAL COMPLETION RWO JAUKK WAr.JER SAFElY NOTE JDWfTLP ClOSE ÆRFS Ba.OW 10906' JCMlPJC MIN D CORRECTION (SWN NIp) JCMlPJC PXNlTP@ 10063' 10882' -I 3" IBP- 04/24/91 I 11638' 11690' DA TE REV BY COMMENTS 06/23/06 BSElPJC PULL PXN PLUG PRUDHOE BA Y UNIT Wa.L: X-07 ÆRMIT No: '1800130 API No: 50-029-20441-00 SEC7, T10N, R14E, 156' Wa. & 409' SNL BP Exploration (Alaska) . . FRANK H. MURKOWSKJ, GOVERNOR A1tASHA OIL AND GAS CONSERVATION COMMISSION 333 W 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)27~7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 \-no-O\:3 , Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU X-07 Sundry Number: 306-268 Dear Mr, Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager), As provided in AS 31.05,080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested, DATED this/~ay of August, 2006 Encl. I u~\"LoI V LoU 12ç;;., err ß-I+~Dk ~/0 f!I¿ \lJú#\-- 9/1f{2-0D(P AUG 1 1 2006 .~Ú" STATE OF ALASKA Ï, ó6 ~~ ' ALASKA OIL AND GAS CONSERVATION COM ON r Alaska Oil & Gas Cons, ConJItPPLICA TION FOR SUNDRY APPROVAL Anchorage 20 MC 25.280 Ops Shutdown due to Field Shutdown 1. Type of Request: 0 Abandon o Suspend 181 Operation Shutdown o Perforate o Time Extension o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: / 5. Per~o Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 180-013/ 305-366 3. Address: D Stratigraphic D Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20441-00-00 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: PBU X-07 .-/ Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028313 73.6' Prudhoe Bay Field / Prudhoe Bay Pool 12. '. PRESENTWELL·.cor·./DITIONSUMMARY .,'. ,/ ··,,',·.,i ...', /( ,( ..', '.. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11691 9617 11638 9572 3607 (Upper) None Casinn Lenoth Size MD / TVD Burst Collanse Structural Condur.tor 110' 30" x 20" 110' 110' Surface 2695' 13-3/8" 2695' 2695' 4930 2670 Intermediate 1 0568' 9-5/8" 10568' 8671' 8150 5080 Production Liner 1631' 7" 1 0059' - 11690' 8267' - 9616' 8160 7020 Perforation Depth MD (ft):~ I Perforation Depth TVD (ft): I Tubing Size: /' Tubing Grade: Tubing MD (ft): 10734' - 10876 / 8802' - 8918' 4-112", 12.6# L-80 & 13Cr -3200 & 1.Qe'T' _ '10111' ,; V 16110\ Packers and SSSV Type: 9-5/8" x 4-112" TIW 'HBBP-R' packer I Packers and SSSV MD (ft): 10001' 13. Attachments: 14. Well Class after proposed work: /' 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program ~ 15. Estimated Date for Augusl~J.006 16. Well Status after proposed work: CommencinQ Operations: 181 Oil DGas D Plugged D Abandoned 17. Verbal Approval: Dat¥- DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed NamWd Reem Totle Drimng Eng;nee, Prepared By Name/Number: \ ì f!o Signature /¡ 'O/lAA/I Phone 564-5743 Date !-/ð-Ób Terrie Hubble, 564-4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ?r{ 0 -;:¿ ÚJ íï D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance , Other: ~)PhP(!j;i1JJ - 40 3 .,..eJ /AAJ W d fo yV'S~t- ~t;;~ Subsequent Foon Reou;,ed: . ~~. 'I. DateSk ðb -L, I ø ~ MMISSIONER APPROVED BY Approved Bv: THE COMMISSION Form 10-403 Revised 06/2006 Vl ~ "'- --- _fubniln Duplicate !~IGI~ RBDMS 8Ft AUG 1 62D06 . . X-07 Well Status: Well is secured with two RBPs, The lowest at 9940 MD, pressure tested to 3500 psi and the second set at 3607 MD , pressure tested to 1000 psi. Well has a kill string run to 3200 MD, Scope: Retrieve existing 4,5", 12,6#, L-80 completion, Replace 2000' of 95/8" casing and cement to surface, Re-complete with 4,5", 12,6#/ft, 13Cr80 Vam Top tubing with 95/8" x 4-1/2" packer. RWO OPERATIONS: Over the course of the past week, the scope of the RWO has been completed up to the replacement of 2000' of 9 5/8" casing and cement to surface, We are currently halting operations due to a field wide shutdown, / An RBP was set at 9940' MD with a 3500 psi pressure test. Another RBP was set at 3607 MD and 40 ft of sand was set on top of it. This RBP was tested to 1000 psi. A kill string was run to -3200' MD, TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = 7-1/16" 5M CrN 13-5/8" 5M MCEVOY OTIS 73.60' 39.80' 3200' 52 @ 5700' 10810' 8800' SS . 113-3/8" CSG, 72#, L-80, ID = 12.347" H 2693' 14-1/2" 1BG, 12.6#,13CR-95, VAM- TOP H Minimum ID = 3.725" @ 10063' 4-1/2" PARKER SWN NIPPLE TOPOF 7" LNR I 14-1/2" 1BG, 12.6#, 13CR, 0.0152 bpf, ID = 3.958" I 1 9-5/8" CSG, 47#, L-80, ID = 8.681" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 05/05/80 ANGLEATTOPÆRF: 32 @ 10734' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 6 10734 - 10761 0 05/16/94 3-3/8" 6 10846 - 10876 0 01/03/91 3-3/8" 6 10886 - 10906 C 01/03/91 2-7/8" 4 10916 - 10928 S 12/29/90 3-3/8" 4 10938 - 10943 S 12/29/90 I PBTD I 17" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" DATE 05/09/80 04/13/91 10/12/02 12111/03 04/13/06 04/13/06 REV BY COMMENTS ORIGINAL COMPLETION RWO JALlKK WAIVER SAFETY NOTE JDWfTLP CLOSE ÆRFS BELOW 10906' JcrvvPJC MIN ID CORRECTION (SWN NIP) JCMlPJC PXN TIP @ 10063' X-07 10058' 10107' 11638' 11690' DA TE REV BY COMMENTS 06/23/06 BSElPJC PULL PXN PLUG TES: *** POSSIBLE IA X OA COMM, OP NG PRESSURE OF THE 13-3/S" ANNULUS MUST NOT EXCEED 2000 PSI (10/12/02 WAlVER)***4-1/2" CHROME TBG 2615' H 9-5/8" DV PKR I -3200 H 4-1/2" HES X NIP, ID = 3.813" 3283' H 4 -1/2" WLEG I 3607' H 9 5/8" RBP I 9940' H 9 5/8" RBP ~ 9-5/8" x 4-1/2" TrN HBBP-R PKR, ID = 4.0" H 4 1/2" Fas-Dril plug I ~4-1/2" PARKER SWS NIP, ID = 3.813" 1 10063' 1-14-1/2" PARKER SWN, NIP, ID = 3.725" I ~ 4-1/2" WLEG, ID = 3.958" I H ELMD TI LOGGED 04/23/91 I 10882' -1 3" IBP - 04/24/91 I PRUDHOE BA Y UNrr WELL: X-07 ÆRMrr No: "1800130 API No: 50-029-20441-00 SEC7, nON, R14E,156' WEL &409' SNL BP Exploration (Alaska) i:i7 8:j?~ II !Ii IJ L¡f"l U 16 e rn·U' I.~.... fi:I.!l\ n.. lW U Lru Lb e AI,ASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR David Reem Drilling Engineer BP Exploration (Alaska), Inc P.O. Box 196612 Anchorage, AK 99519-6612 333 w. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: PBU X-07 Sundry Number: 305-366 ~t;ANNfD DEG 1 t:t 2005 Dear Mr. Reem: 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. Please provide at least twent,y-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. 30 K. ChaJ. DATED this~ day of November, 2005 Encl. Ñ fJilll" ~ -ð5' IJ.J~ i " e STATE OF ALASKA · RECEIVEC' ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL NOV 2 3 '2005 20 AAC 25.280 Maska OU & Gas Cons. CommiSSítHI u "'~ lIP ~ 1. Type of Request: [] Abandon [J Suspend [J Operation Shutdown [] Perforate [J Other [J Alter Casing III Repair Well [J Plug Perforations [J Stimulate [J Re-Enter Suspended Well [] Change Approved Program III Pull Tubing [] Perforate New Pool [J Waiver [J Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number / 180-013/ BP Exploration (Alaska) Inc. 181 Development 0 Exploratory 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20441-00-00 // 7. KB Elevation (ft): 73.6' 9. Well Name and Number: PBU X-07 / 8. Property Designation: 10. Field / Pool(s): ADL 028313 Prudhoe Bay Field / Prudhoe Bay Pool 11. I /.>.>i ... .' Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11691 9617 11638 9572 10882 None Casino Lenath Size MD " TVD Burst CollaDse Structural 110' 30" x 20" 110' 110' Surface 2695' 13-318" 2695' 2695' 4930 2670 10568' 9-5/8" 10568' 8671' 8150 5080 Liner 1631' 7" 10059' - 11690' 8267' - 9616' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 10734' - 10876 8802' - 8918' 4-1/2", 12.6# 13Cr 10111' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW 'HBBP-R' packer Packers and SSSV MD (ft): 10001' ,/ 12. Attachments: 13. Well Class after proposed work: / 181 Description Summary of Proposal o BOP Sketch o Exploratory 181 Development o Service o Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 15, 2006 181 Oil I o Gas o Plugged o Abandoned 16. Verbal Approval: Date: o WAG DGINJ DWINJ o WDSPL Commission ReDresentative: 17. I hereby certify ~ at the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Name ~vi)J.. Ree~ Title Drilling Engineer b,-( ~ir!jl ¡J A__ ~lz3Jo 5 Prepared By Name/Number: Sionature Phone 564-5743 Date Terrie Hubble, 564-4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness T Sundry Number:L)Y)5 - ~ of (J o Plug Integrity ~OP Test ærMechanicallntegrity Test o Location Clearance Other: T e-s. t- ß e P e- ~ So 0 f~' RBDMS 8FL NOV 2 9 2005 Approved I:¥ ..... C/t 'A APPROVED BY II'¡! ~,;: COMMISSIONER THE COMMISSION Date Form 10-403 ~ 0772~ "- Submit In Duplicate ORIGTN L \. e e Well Status: Shut-in Ivishak gas-lifted producer. Well has confirmed inner x outer ~. annulus communication when on gas-lift. The leak path is not believed to be through the wellhead. Well is secured with a composite bridge-plug in the tubing tail. Proiect: Retrieve existing 4.5", 12.6#, 13Cr-80 TDS completion, locate top of cement in 9-5/8" x 13-3/8" annulus, cut and pull the 9-5/8" casing above the TOC, tie-back premium threaded 9-5/8" to surface and fully cement same, re-complete well with 4.5", 12.6#, 13Cr-80 VamTop tubing. Provide AOGCC field inspectors 24-hr notices as .---- required to witness BOP tests and MITIA post packer setting. 1. MIRU 4ES. Pull BPVs, set and test TWC in tubing hanger. ND tree and adapter flange. NU BOPE. Test annular to 250 psi (low)/3500 psi (high), remaining BOPE / to 250 psi (low)/3500 psi (high) per BP and AOGCC regulations. 2. Fully circulate through the pre-RWO tubing cut with heated seawater. 3. Pull 4.5", 12.6#/ft, 13Cr-80 TDS down to the tubing cut just above the packer. 4. Run 8-1/8" dress-off BRA and 9-5/8" casing scraper to top of 4-1/2" tubing stub at /' 9981 'md. 5. Set 9-5/8" RBP at -4000' and stack 30' of sand on same. 6. RU e-line and log with USIT cement evaluation log from -200' below the 13-3/8" / shoe to -200' above the top of cement. 7. Mechanically cut the 9-5/8" above the TOe. Circulate out Arctic Pack. LD9-5/8" to the cut. 8. Run wash shoe and 13-3/8" scraper to the 9-5/8" stub and circ out all Arctic Pack. ,/ 9. Back-off remaining 9-5/8" cut joint and spear same leaving 9-5/8" connection looking up. 10. Run 9-5/8" screw-in sub on 9-5/8", 40#, L-80, TC-II casing. Screw back into stub. / Pull test to 250K. 11. Land casing on emergency slips in existing tubing spool. / 12. Fully cement the 9-5/8" to surface with Permafrost grade cement. 13. PT casing to 3500 psi for 30-minutes (charted). ,- 14. Mill up shoe track and wash down to the RBP. 15. Pull RBP. 16. Mill up composite bridge-plug in 4.5" tubing tail. LDDP. 17. Run new 4.5", 12.6#/ft, 13Cr-80 Yam Top completion with "stacker-packer". Set ........-- and test packer to 3500 psi (tubing and inner annulus) for 30-minutes each (charted). 18. RDMO 4ES. 19. Tie well in and place on gas-lift production. . - TREE = 7-1/16" 5MOW WB...LHEAD - 13-518" 5M MCEVOY X-07 SAFETY NOTES: *** POSSIBLE IA X OA COMM. ACTUATOR - OTlS OPERATING PRESSURE OF THE 13·3/8" ANNULUS KB. ELEV = 73.60' MUST NOT EXCEED 2000 PSI (10/12/02 BF. ELEV = 39.80' WAlVER)*** KOP- 3200' Max Angle = 52 @ 5700' . 1996' 4-1/2" OTIS SSSV NIP, ID - 3.813" I Datum MD = 10810' Datum TVD - 8800' SS = = ~ 2615' H9-5/8" DV PKR GAS LIFT MANDRELS I 13-318" CSG, 72#, L-80, ID = 12.34 7" 2693' -µ ~ ST MD TVD ŒV TYPE VLV LATCH FORI" DATE 5 3004 2930 6 OTlS 1-1/2" RA 4 5684 5065 51 OTlS 1-1/2" RA L 3 7928 6532 45 OTlS 1-1/2" RA 2 9248 7512 35 OTlS 1-1/2" RA 1 9960 8111 33 OTlS 1-1/2" RA Minimum ID = 3.725" @ 10063' 4-1/2" PARKER SWN NIPPLE I I 9989' L 4-1/2"PARKERSWSNIP,ID-3.813" I I 10000' L TlW LA TCH A SSY I :8: ........ 10001' 1~9-5/8" x 4-1/2" TlW HBBP-R A<R, ID 4.0" I ¡.:::::::> I . 10052' L 4-1/2" PARKERSWS NIP, ID 3.813" I I TOP OF 7" LNR 10058' ~ I . I 10063' L 4-1/2" PARKERSWN, NIP, ID 3.813" I 4-1/2" TBG, 12.6#, 13CR, 0.0152 bpf, ID = 3.958" 10107' I 10107' L 4-1/2" WLEG, ID= 3.958"1 I 10094' H B...M) TT LOGGED 04/23/91 I 9-5/8" CSG, 47#, L-80, ID - 8.681" 1 0568' "]---..4 ... [] PERFORATION Sllv1f1N1. RY [] REF LOG: BHCS ON 05105180 [] ANGLEA TTOP PffiF: 32 @ 10734' Note: Refer to A"oductbn œ for historical perf data SIZE SFF INTffiV A L Opn/Sqz DATE 3-318" 6 10734 - 10761 0 05/16/94 ~ 10882' 3" IBP - 04/24/91 I 3-318" 6 10846 - 10876 0 01/03/91 3-318" 6 10886 - 10906 C 01/03/91 2-718" 4 10916 - 10928 S 1 2/29/90 I 3-318" 4 10938 - 10943 S 12/29/90 I PBTD I I 11638' I 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" I 11690' DATE REV BY CO rvtv1 ENTS DATE REV BY COrvtv1ENTS FRUDHOE BA Y UNIT 05/09/80 ORIGINAL COMPLETION WB...L: X-07 04/13/91 RWO PE~rrNo: 1800130 06/22/01 RNlTP CORRECTIONS API No: 50-029-20441-00 07/13/02 JC/KA K CORRECTIONS SEC 7, T1 ON, R14E, 156' WEL & 409' SNL 10/12/02 JA UKK WA IVER SAFElY NOTE 12/11/03 JDW/TLP QOSE FERFS BELOW 10906' BP Exploration (Alas ka) TREE = 7-1/16" SM crvv e e . WEU.H~D = 13-5/8" 5M MCEVOY X-OJ Proposed ACTUA TOR = OTIS KB. ELEV = 73.60' BF. ELEV = 39.80' KOP= 3200' 9-5/8", 40#, L-80 TC-II Max Angle = S2 @ 5700' Fully cemented to I -2100' 4-1/2" HES "X" NIP, ID = 3.813" I Datum MD = 10810' surface. Datum TVD = 8800'SS H9-S/8" DV PKR ,/ GAS LIFT MANDRELS I 13-3/8" CSG, 72#, L-80, ID = 12.347" 2693' ST MD ìYPE VLV S 3001 4.5" x 1.5" OCR U 4 4883 4.5" x 1.5" OUMMY 3 6620 4.5" x 1.S" DUMMY 2 8459 4.5" x 1.5" DUMMY 1 9802 4.5" x 1.5" DUMMY Minimum ID = 3.725" @ 10063' 4-1/2" PARKER SWN NIPPLE 1:81 . -9870' 4-1/2" HES "X" NIP. ID - 3.813" I ¡¿:::" .", -9891' .-19-S18" x 4-1/2" BKR S-3 PKR, 10 - 3.875" I I I I -2100' 1-14-1/2" HES "X" NIP, 10 - 3.813" I 4-1/2" TBG, 12.6#. 13Cr-80, VamTop -9980' . 1--11 n I UNIQUE MACHINE OVERSHOT H -9981' 1""""'- lioc::> 9989' 4-1/2" PARKER SWS NIP, 10 - 3.813" I ~I ¡o:= 10001' 9-S/8" x 4-1/2" Trvv HBBP-R PKR, 10 = 4.0" I I 10052' 4-1/2" PARKER SWS NIP, 10 3.813" I I TOP OF 7" LNR I 10058' l- . I I I f-----i J4-1/2" PARKER SWN, NIP. 10 - 3.813" 10063' I 4-1/2" TBG, 12.6#, 13CR. 0.0152 bpf, 10 = 3.958" 10107' 10107' J4-1/2" WLEG. 10 = 3.958"1 I 10094' H ELMO TT LOGGED 04/23/91 I I 9-5/8" CSG. 47#, L-80, 10 = 8.681" 10568' µ ~ ~ PERFORA TION SUMMARY I] REF LOG: BHCS ON 05/05/80 . ANGLEATTOPPERF: 32@ 10734' T Note: Refer to Production OB for historical perf data SIZE SPF INTERV AL Opn/Sqz OATE 3-3/8" 6 10734 - 10761 0 05/16/94 ~ 10882' H 3" IBP- 04/24/91 3-3/8" 6 10846 - 10876 0 01/03/91 3-3/8" 6 10886 - 10906 C 01/03/91 2-7/8" 4 10916 - 10928 S 12/29/90 I 3-3/8" 4 10938 - 10943 S 12/29/90 I PBTD 11638' I I 7" LNR, 29#. L-80, 0.0371 bpf. ID = 6.184" 11690' OATE REV BY COMMENTS OATE REV BY COMMENTS PRUOHOE BAY UNrr 05/09/80 ORIGINAL COMPLETION WELL: X-07 04/13/91 RWO PERMrr No: 1800130 06/22/01 RNlTP CORRECTIONS API No: 50-029-20441-00 07/13/02 JClKAK CORRECTIONS SEC 7, T10N. R14E.156' WEL & 409' SNL 10/12/02 JA LIKK WAIVER SAFETY NOTE 12/11/03 JOW/TLP CLOSE PERFS BELOW 10906' BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, a' DATE: Commissioner December 9, 2000 THRU: Tom Maunder, P. I. Supervisor FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Field BPX / X-Pad SatUrday~ December 9~ 2000: I traveled to BPX's .X Pad in the Prudhoe Bay Field to witness' Safety Valve System tests. Merv Liddelow, BPX representatiVe in charge of the testing, performed the tests in a safe and proficient manner. Of the 26 wells tested, 3 fa[lures were witnessed. Well X-14A's SSV failed to Close and well X,19B's pilot was frozen and the SSV failed to close. Mr. Liddelow indicated to me on 12/10/00 that these items have beep corrected and successfully re-tested. The AOGCC test reports are attached for reference. I conducted 26 well house inspections concurrent with the SVS tests. A slight crude oil leak was noted on a wellhead flange of well X-19B. Mr. Liddelow indicated he would have this item addressed. No other exceptions were noted. SUMMARY: I witnessed SVS tests and conducted well house inspections on BPX's X Pad. 26 .wells, 53 components tested, 3 failures. 26 well houses inspected. Attachments.: SVS PBU X Pad 12-9-00 JJ NON-CONFIDENTIAL SVS PBU X Pad 12-9-00 JJ.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit~ad: PBFfPBU/X Pad Separator psi: LPS 174 Date: 12/9/00 HPS 723 Well Permit Separ Set L/P Test Test Test 'Date Oil, WAG, GIN J, Number· Number PSI PSI 'TAp Code Code Code Passed GAS or CYCLE X-01 1790540 174 125 125 'P P OIL X-02 1790690 174 125 125 P P OIL X-03A 1980860! 723 550 400 " P P OIL X-04 1790890': 174! ·125 125 P P OIL X-05 1791040 .. 174 '" '125 115 P P ..... OIL , , X-06 .1800090 X-07 180013.0' 174 125 110 .'P P OIL X'08 18003'60 174 125 115 ''P P OIL X-09 1800280 · X"10 . 1800430 174 ' 125~' ~ 120 'P · P OIL X-11A 1990780 ' 2000 1950 P P P . ."'"' ~AG X-12'~ '1800440. 174 125 110' .P P , ~, OIL , ,, X-13A 1930650 1.74 125 100 P P . . OIL X-14A 1921430 174 125 ' 120 ':'P' 5' OIL , ,, X-15 1800740 174 ' 125 . 125 P P '. OIL X-16~ 1811720 174 ' 125 ,125 P P. .OIL X-17' 1811690 723 55.0 520 ' .P P .OIL X-18 1811620 174 ~ 125 120 P P. ~'OIL. X'lgB 1961300. 174 125 0 ~ 2 5 ' OIL ,, x-26 '1940670 [ · X-2!A 1991080 174 · i25 110 P P." ' "OIL X,22 1931300 174 125 1.10 · P P . OIL X-23 1840610 . . X-24A . 1991250. · X'25 1840340 ., 174 · 125 ~ ~20 P' P ~ , . OIL · X-26 1840300 ' X-27 ., 1840.690 1'74 125 120 P' P ., OIL. X-28 1'931140 , '~ · X-2~ 1931390. . , x-3o' ~ 1950410 174' ' 125 ' 115 P P' OIL X-31 · 1931980 174 125 120 P ', P OIL ........ X-32 1931620 1'74 125 : 125 'P P OIL X-34 19317.20 174 '125 115 P P '. OIL , X-35 ' 1931990 174 125 90 ' P P OIL , 12/13/00 Page 1 of 2 SVS PBU X Pad 12-9-00 JJ.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, Gl]NJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE X-36 19616701 Wells: 26 Components: 53 Failures: 3 Failure Rate: 5.6% Uloo Day Remarks: 12/13/00 Page 2 of 2 SVS PBU X Pad I2-9-00 JJ.xls STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMMI . ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing ..... Repair well Perforate Other ........ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigmphic 4. Location of well at surface 408' SNL, 156' WEL, SEC. 07, TION, R14E, UPM At top of productive interval ~ 2582'NSL, 1100'WEL, SEC. O8, T10N, R14E, UPM (Sag R) O R I G I N A L At effective depth 2245' NSL, 945' WEL, SEC. 08, TION, R14E, UPM At total depth 2140' NSL, 905' WEL, SEC. 08, TION, R14E, UPM 6. Datum elevation (DF or KB) KBE = 73.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-07 (43-08-10-14) PBU 9. Permit number/approval number 80-13 / 10. APl number 12. Present well condition summary Total depth: measured true vertical 11691 feet BKB 9616 feet Plugs (measured) 50- 029-20441 11. Field/Pool Prudhoe 0il Pool Effective depth: measured true vertical 11481 feet BKB 9438 feet Junk (measured) fill at 10881' MD (07/91) Casing : Structural Conductor Surfade Intermediate Production Liner Perforation depth: Length .. 110 2661 10534 .. 1631 measured Size Cemented Measured depth True vertical depth BKB 20x30 8. 5 c.y. 144 144 13 3/8 3720 c.f. 2695 2695 9 5/8 1682 c.f. 10568 8656 7 540 c.f. : 10 734 '- 10 761 ', 10846'- 108 76', 10886'- 10906', 10058-11690 8253-9615 Sqzd: 10916'-10928', 10938'-10943' (lvishak) true vertical eubsea 8728'-8870' (Sag R) · Tubing (size, grade, and measured depth) 4 1/2' NT 12.6#, NT 13CR-80 tubing to 10107'MD Packers and SSSV (type and measured depth) 9 5/8; Baker TIW HB-BP packer at 10001 '; 4 1/2" Otis SSSV at 1996'MD 13. Stimulation or cement squeeze summary see attachment Sag is sqzd:8878'-8901 (two Ivishak intervals) Intervals treated (measured) AUG ;50 1995 14. Treatment description including volumes used and final pressure ~as_ka,. Oil & Gas Cons. Commission ~; ~choraae Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 855 1008 2663 3500 280 Subsequent to operation 1083 818 2334 3580 294 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby c rtify that th !oreg ' ' tr a d correct to the best of my knowledge. Form 1-~---~d4 Rev o8/15/88 ~ Date SUBMIT IN DI~:~LI~;dAT'E WELL X-07 (43-08-10-14) Re_oerf O_oerati0ns 5/6/94 The following SAG interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 10734- 10761MD LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 24 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL x-07 143-08-10-14 # DESCRIPTION 1PLS/STATIC FNL BL+RF 1CN/GR FINAL BL+RF 1 CN/GR FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS/STATIC FNL BL+RF ECC No. Run # 1 4046.05 Run # 1 5694.04 Run # 1 5751.05 Run # 1 5758.02 R~n # 1 6035.03 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by~_~~~ Date: Please sign and ~.eturn ~: PetrotechnXcel Data Cente~' BP Exploration (Alaska) Ina 900 East Benson Boulevard Anchorage, Alaska 99508 Receive~ b~ :E D Alaska Oil & 6as Cons. Commis$!lln Anchorage . l~a~:,e sign end rei;uz,n to: ?e~;ro'l;eel-mieal Data ~ i;ez. BP Exploration (Alaskk., Inc 900 East Season Boulevard Anchorage, Alaska 99~08 Received by Dste ALAS ' COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date:' RE: 7 July 1994 Transmittal of Data Sent by: ATLAS WIRELINE Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. ,,~PDK/GR FINAL BL 1 PDK/GR FINAL RF Run # 1 4269.O1 Run # 1 X-07 (43-08-10-14) 1/~.LS FINAL BL Run # 1 4046.04 f ~LS FINAL RF Run # 1 /~ PLS/GLS FINAL BL Run # 1 PLS/GLS FINAL RF Run # 1 -, /~1 PDK/GR FINAL BL PDK/GR FIN~ RF Run # 1 4146.O1 Run # ! /--1 SBT/GR FINAL BL 1 SBT/GR FINAL RF Run # 1 6229.00 Run # 1 /fCN/GR FINAL BL 1 CN/GR FINAL RF Run # 1 1157.02 Run # ! JCN/GR FINAL BL CN/GR FINAL RF Run # 1 6012.01 Run # 1 J~-COLLAR LOG FINAL BL 1 COLLAR'LOG FINAL RF Run # 1 1991.02 Run # 1 Please sign and return to: Atlas Wire!ine Services 5600 B Street Received by: Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date: ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-,3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 6, 1994 Steve Farris/Jerry Bixby Wireline/Completion Supervisors BP Exploration (Alaska), Inc P O Box 196612 Anchorage, AK 99519-6612 Re: No-Flow Verification BPX PB..U-J~lls & X-8 PTD ~_~_~& 80-036 Dear Mr. Farris: As requested, on June' 30, 1994, our Inspector Bobby Foster witnessed no-flow tests on BPX's PBU wells X-7 (PTD 80-013) and X-8 (PTD 80-0360). The wells had been shut-in since 5:00 p.m. the previous evening. Both wells were being bled down to the bleed tanks on-site. A gas meter showed that well X-7 was producing apProximately 30 SCF per hour and well X-8 approximately 51 SCF per hour. Since these rates are well below the limits for "no-flows", the Inspector concluded that wells X-7 and X-8 were not capable of unassisted flow of hydrocarbons. The Commission hereby authorizes removal of the subsurface safety valves from BPX's PBU wells X-7'(PTD 80-013) and X-8 (PTD 80-036) on the condition that the low-pressure sensors and surface safety valves must be maintained in good cOndition and, if for any reason, the wells again become capable of unassisted flow of hydrocarbons, the'subsurface safety valve(s) must be reinstalled and maintained in good working condition. Sincerely, Blair E. Won~ll PI Supervisor c: Bobby Foster beW/nlpbu2x MEMORANDU State o "'Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: · David Johnston, Chairman~ DATE: June 30, 1994 Blair Wondzell, ~ FILE NO: P. I. Supervisor '//z/~ Bobby Fos_{~~C ~'~+SUBJECT: Petroleum Inspector 1J91F4BD.doc No Flow Test BPX- PBU - X Pad Prudhoe Bay Field Thursday, June 30, 1994: I traveledkBPX's X pad at the request of Ken Smith, BPX rep., and witnessed the No Flow Test on wells 7 and 8. I arrived at X pad at 8:00 AM and met with Ken. He informed me that the wells had been shut in since 5:00 PM the previous evening. He said that he had come to the pad at 6:00 AM and began bleeding the tubing down to the bleed tanks on site. Both wells were being bled down through one half inch hoses tied into the swab cap. Ken had gone the previous day to Nergasco ( the public natural gas supplier On the North Slope) and purchased a gas meter. The meter, an American AL 425 - ANIS class 400 ( a regular home gas meter) which is acceptable up to 25 psi of pressure, was tied into the vent line on well # 7. During the next 3 hours readings were taken on well 7 and 8. Well ~7 averaged producing 30+- scl of gas per hour. Well 8 averaged 51 +- scl= of gas per hour. I called Blair Wondzell, my supervisor, and told him about our findings. Based on APl RP 14B a well may be classified as unable to flow unassisted if it produces no more than 900scf of gas per hour or no more than 6.3 gals. per hour of fluid. I recommend to the commission that both of these wells, X-7 and X-8 be classified as NO-FLOW. Summary: I witnessed the NO-FLOW test on BPX's PBU wells X-7 and X-8. Attachment ALASKA OIL & 'GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 8 June 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. ~_[I H-07 (22-11-13) /~ CN/GR FINAL BL 1CN/GR FINAL RF SEPIA Run # 1 4096.01 Run ~ 1 ~ PL PROFILE FINAL BL 1PL PROFILE RF SEPIA Run # 1 2188.01 Run # 1 ~--~0A B-28 (32-29-11-14) /1PLS FINAL BL 1PLS FINAL RF SEPIA Run # 1 3771.04 Run # 1 B-27 ~ B-27/ jl PLS FINAL BL 1 PLS FINAL RF SEPIA j~PLS PRESURE FINAL BL 1PL$ PRESURE RF SEPIA /2 CN/GR FINAL BL 1 CN/GR FINAL RF SEPIA Run # 1 Run # ! 5603.03 Run # 1 5808.02 Run # 1 Run # 1 5603.04 Run # 1 ~Y~ ~ ~ X-07 (43-08-10-14) /1 PL PROFILE FINAL BL 1 PL PROFILE RF SEPIA Run ~ 1 4046.03 Run # 1 P-06 (24-30-11-13) /1 PL PROFILE FINAL BL 1 PL PROFILE RF SEPIA Run ~ 1 5802.03 Run # ~ PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 5617.07 Run # 1 ~9-~b J-10 (lO-ZZ-13) /! PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 4887.04 Run # 1 Cont/ RECEIVED & ¢o s. Gommfssfo Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA · . Date: 26 May 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL $ DESCRIPTION R-04 (22-05-11-13) 1 CN/GR FINAL BL CN/GR FINAL RF SEPIA A-11 E-06 (33-6-11-14) F-l! /1 CCL/PACKER FINAL BL i CCL/PACKER RF SEPIA / 1 SPNR/TEMP FINAL BL 1 SPNR/TEMP RF SEPIA /' 1 DTEMP FINAL BL 1 DTEMP FINAL RF SEPIA F-14 (33-35-12-13) / 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA R-13 / 1 CN/GR FINAL BL 1 CN/GR FINAL RF SEPIA B-02 (32-11-14) /1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA R-35 (23-33-12-13) X-07 (43-08-10-14) I PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA /1 PFC/PERF FINAL BL i PFC/PERF RF SEPIA S-32 (33-26-12-12) 1 PFC/PERF FINAL BL /1 PFC/PERF RF SEPIA cont/ ECC No. Run # 1 5627.05 Run # 1 Run # 1 3560.02 Run °# 1 ' Run # 1 3573.01 Run # i Run # ! 1022.02 Run # 1 Run # 1 959.07 Run # 1 Run # 1 4515.04 Run # i Run # i 5803.04 Run # 1 Run # I 6136.04 Run # 1 Run # 1 4046.02 Run # 1 Run # 1 6202.00 Run # 1 R IVED Alaska Oil & Gas Cons. Cor~rnission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSIbN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing X Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 408' SNL, 156' WEL, SEC. 07, TION, R14E, UPM At top of productive interval 2582' NSL, 1100 ' WEL, SEC. 08, TION, R14E, UPM (Sag R) At effective depth 2169' NSL, 916' WEI_, SEC. 08, TION, R14E, UPM At total depth 2140' NSL, 945' WEL, SEC. 08, TION, R14E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 11691 feet BKB 9616 feet 11631 feet BKB 9565 feet Size true vertical 5. Type of Well: Development Exploratory Strafigraphic Service 6. Datum elevation (DF or KB) KBE = 73.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-07 (43-08-10-14) 9. Permit number/approval number 80-13~Conservation order 258 10. APl number 50- 029-20441 11. Field/Pool Prudhoe Bay Field~Oil Pool Plugs (measured) Junk (measured) Fill@ 11631'MD (4/11/91) Cemented Measured depth True vertical depth RECEIVED MAY 1 2 1992 Alaska 0ii & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 4-1/2", 12.6#, NT 13CR-80 tubing to 10107'MD Packers and SSSV (type and measured depth) 9-5/8" TIW 'HB-BP' Permanent Packer @ IO001'MD, 4-1/2" Otis SSSV @ 1996'MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Workover En~linner Supervisor Form 10-404 Rev 06/15/88 Date SUBMIT IN DOI::~.IOATE BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Tuesday, March 26. 1991 WELL: X-07 (43-08-10-14~ PRUDHOE BAY UNIT Rig: .Nabors Rig #3-S Day: 1 Expense AFE Number: Expense AFE Amount = 145057 Current Field Costs = Estimated Final Cost = Current O0erati0n' NU and test BOP. Summary of Last 24 Hours MIRU. Accept rig at 0600 hours on 3/25/91. Displace diesel from well. Install 2-way check. ND tree. NU and test BOP. Reviewed By:~-~~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: pRUDHOE BAY UNIT As of 0600 Hrs. Wednesday, March 27. 1991 WELL: X-07 (43-08-10-14) Rig: Nabors Rig #3-$ Day: 2 Expense AFE Number: Expense AFE Amount = 145057 Current Field Costs = Estimated Final Cost = Current Ooeration:. Nipple up BOP's. Summary. of Last 24 Hours Nipple up BOP's, check equipment. RECEIVED MAY 1 2 1992 Alaska Oil & Gas Cons. CommisSiO~ Anchorage Reviewed By: '~..~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Thursday, March 2~, 1991 WELL: X-07 (43-08-10-14) Rig: Nab0rs Rig #3-S Day: 3 Expense AFE Number: 145057 Expense AFE Amount = Estimated Final Cost = Current O0eration: Repair leaks in manifold. Summarv of Last 24 Hour~ Continue to rig up BOP's and test. Current Field Costs = Reviewed By: '~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Monday, April 1. 1991 WELL: X-07 (43-08-10-14) PRUDHOE BAY UNIT Rig' Nabor$ Rig #3-S Day' 7_ Expense AFE Number: Expense AFE Amount = 145057 Current Field Costs = Estimated Final Cost = Current'Ooeration: Set storm packer. ,~ummary of Last 96 Hours Test BOP's. Pull 4-1/2" tubing. RIH with overshot. Fish cutoff and PBR. RIH with overshot. Set storm packer to change 9-5/8" packoff. Reviewed By: '" "" '" BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Tuesday. A.oril 2. 1991 WELL: X-07 (43-08-10-14) PRUDHOE BAY UNIT Rig: Nabors Rig #3-S Day: 8 Expense AFE Number: Expense AFE Amount = 145057 Current Field Costs = Estimated Final Cost = Current Ooeration: Run test plug. Summary of Last 24 Hours Set storm packer and exchange tubing spool and 9-5/8" packoff. Run test plug. Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday, April 3, 1991 WELL: X-O7 (43-08-10-14) Rig: Nabors Rig #3-S Day: .9. Expense AFE Number: Expense AFE Amount = 145057 Current Field Costs = Estimated Final Cost = Current Operation: POH. Sumrnarv of Last 24 Hours Test BOP to 5000 psi. RIH. Test casing to 2500 psi, OK. Attempt to fish slick stick. POH. Reviewed By' ¢,.~_- BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Thursday, April 4. 1991 - WELL: X-07 (4;5-05-10-14) · Day: 10 Expense AFE Number: 145057 Expense AFE Amount -- PRUDHOE BAY UNIT Rig: Nabor8 Rig #3-S Current Field Costs = Estimated Final Cost = Current Operation: POH with slick stick. Summary of Last 24 Hours RIH. Service rig. RIH recover slick stick. POH. REEEIYED MAY 1 2 1992 Alaska Oil & Gas Cons. Commission Anchorage Reviewed By :(,/~)~~--- . -. ., _. BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Fdday, April 51 1991 WELL: X-07 (43-08-10-14) PRUDHOE BAY UNIT Rig: Nabor~; Rig #3~$ Day: 1,1, Expense AFE Number: Expense AFE Amount = 145057 Current Field Costs = Estimated Final Cost = Current Operation: RIH with packer mill. Summary of Last 24 Hours POH recover slick stick. RIH mill packer. POH for new mill. RIH with packer mill. Reviewed By: ~,~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: ~ As of 0600 Hrs. ~ ' Rig: Nabors Rig #3-S Day: 1_.j.4 Current Field Costs = Expense AFE Number: ~ Estimated Final Cost = ~urrenl; Operation~ POH with packer. Summary_ of Last Z2, ~ POH with mill. RIH with shoe. Mill packer and push to liner top. Circulate and monitor well. RIH with spear. POH fish dragging. RECEIVED MAY 1 2 1992 Alaska,0il & 6as Cons. Commissio~ ;Anchorage Reviewed BY' ~,~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOI~ BAY UNIT As of 0600 Hrs. Wednesday. Aoril 10. 1991 WELL:. X-07 (43-08-10-14) Rig: Nabors Rig #3-$ Day: 16 Expense AFE Number: Expense AFE Amount = 14,5057 Current Field Costs = Estimated Final Cost = Current Operation: Cleaning out 7" liner. Summary of Last 24 Hours Recover packer. Made 9-5/8" casing scraper run. Cleaning out 7" liner. Reviewed By~,~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Thursday. April 11. 1991 WELL: X-07 (43-08-10-14) PRUDHOE BAY UNIT Rig: Nabors Rig #3-$ Day: 17 Expense AFE Number: Expense AFE Amount = 145O57 Current Field Costs = Estimated Final Cost = Current Operation' POH with D.P. Summary_ of Last 24 Hour~ Clean out to 11,631'. Reverse and change over to inhibited brine. POH laying down D.P. Reviewed By: BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Fddav. Aoril 12, 1991 WELL: X-07 (43-08-10-14) PRUDHOE BAY UNIT Rig: Nabors Rig #3-$ Day: 1 8 Expense AFE Number: Expense AFE Amount = 145057 Current Field Costs = Estimated Final Cost = Current Operation: Run 4-1/2" chrome tubing. Summary of Last 24 Hours Lay down drill pipe. RU WL and run 8.35" gauge dng to 10,089'. RU and run 4-1/2" chrome tubing. MAY 1 2 1992 Naska 0il & Gas Cons. Commissio~ ;Anchorage Reviewed By: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 03/13/92 T# 83324 BP CASED HOLE FINALS Enclosed is your copy of the materials listed questions, please contact BP Well Records at X-07 PRODUCTION LOG 03/09/92 #2 below. If you have any (907) 564-4004. 7875.00-10880.00 SCH 2/5" Information Control Well Records Adrian J. Martin RECEIVED MAR 2 ~ 199;L Alaska Oil & Gas Cons, Commission Anchorage STATE OF ALASKA ~[ AL(~..,A OIL AND GAS CONSERVATION COMMIS~,,.,N 0 j~ · ' PORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate ,x Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Explorat~ (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 408' SNL, 156' WEI., SEC. 07, TION, R14E, UPM At top of productive interval 2582'NSL, 1100'WEL, SEC. 08, TION, R14E, UPM (Sag R) At effective depth 2245' NSL, 945' WEL, SEC. 08, TION, RI4E, UPM At total depth 2140' NSL, 905' WEL, SEC. 08, TION, R14E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11691feet BKB 9616feet 11481feet BKB 9438feet Str~graphic Service KBE = 73.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-07 (43-08-10.14) PBU 9. Permit number/approval number 80-13/ 10. APl number 50- 029-20441 11. Field/Pool Prudhoe Oil Pool Plugs (measured) .; Junk (measured) fill at 10881'MD (07/91) Casing Length Structural .. Conductor 110 Surface 2661 Intermediate 10534 Production -- Liner 1631 Perforation depth: measured Size Cemented Measured depth True vertical depth BKB 8.5 c.y. 144 144 3720 c.f. . 2695 2695 1682 c.f. 10568 8656 20x30 133/8 9 5/8 7 540 c.f. 10846'-10876', 10886'-10906', truevertical subsea 8728'-8750' (Sag R) 8820'-8870' (two Ivishak intervals) 10058-11690 8253-9615 Sqzd: 10734'-10761' (Sag R) 10916'-10928', 10938'-10943' (Iv~shak) Sag is sqzd:8728' 8750' Tubing (size, grade, and measured depth) 4 1/2" NT 13CR-80 to 10001' with 4 1/2" WLEG to 10107' Packers and SSSV (type and measured depth) 95/8"Baker TIWHBBPpackerat 10001~ 4 1/2" SSSV at 2110' 13. Stimulation or cement squeeze summary see attachment K ~ ~ ~. I V ~ [~ 14. Intervals treated (measured) FEB 2 1 1992 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. C0mmissio~ Representative Daily Average Production or Injection Data ~"~"'""~" OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1060 1318 2169 1628 234 Subsequent to operation 880 949 422 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~ - Sienna Form 10-404 Rev 06/15/88 / 911 237 Service Title Supervisor Waterflood/Miscible Flood Date SUBMIT IN DUPLICATE WELL X-07 (43-08-10-14~ PBU CTU/WSO SQUEEZE OPERATIONS A CTU/WSO squeeze was performed December 29, 1990 on the following intervals: 10734' - 10761' MD BKB 10846' - 10876' MD BKB 10886' - 10906' MD BKB 10916'- 10926' MD BKB 10938' - 10943' MD BKB Including the channel that extends to 10990' The following intervals were reperfed on January 3, 1991 following the squeeze: 10846'- 10876' MD BKB 10886' - 10906' MD BKB Injectivity of 1.5 BPM @960 psi. Pumped 15 BBIs cement. Pressure was lost, and squeeze broke down. Well was cleaned up and batch #3 pumped. Injectivity improved. Pressure improved, and squeeze held. On 4/29/91 Hydraulic Fracturing RECEIVED FEB 21 1992 Alasl~a 0ii & 6as Cons. Commissio~ Anchorage BP EXPLORATION BP Exploration (Alaska) Inc.. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-511'1 TO: DISTRIBUTION Date :07/30/91 T#:82671 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-.!.445. -43 ~1 - ~-4;~P-11 R-08 R-19 X-07 X-08 X-10 CET ' 07/24/91 #1 13450-14466 Sch 5" CBTE" 07/24/91 #1 13450-14442 Sch 5" CNL" 07/24/91 #1 9850-14416 Sch 5" Peal' 07/27/91 #1 9130-9775 Sch 5" Perf,- 07/26/91 #1 10860-11170 Sch 5" Perf ,- 07/26/91 #1 9500-9753 Sch 5" Prod- F" 07/22/91 #1 10500-10870 Sch 5" Production Log' 07/23/91 #1 9400-9906 Sch 5" Production Log- 07/24/91 #1 10550-10755 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES -MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :05/14/91 T#:82386 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. D-23 E-19 M-21 ut0.. t 5~ .,,P-17 U-11 W-25 _~ X-07 Z-20 Gas Entry Survey 04/24/91 #1 10100-10480 Gas .Entry/Prod~F 04/19/91 #1 11450-11690 Gamma -Ray 04/16/91 # 1 8300-9005.5 Prod- F 04/17/91 #1 12100-12445 GR/CCL/Pre Fmc 04/19/91 # 1 8700-9178 Gamma-Ray 04/24/91 # 1 9300-9954 PITS 04/23/91 #1 10400-11190 Leak Det.' 04/26/91 # 1 9500-9750 Prod-F 04/18/91 ~#1 10100-10553 Jewelry 04/23/91 #1 9900-11000 Temp 04/27/91 #1 3000-13132 Gas Entry SurveY 04/17/91 ' #1 11100-11521 Camco 5" Camco 5" Camco 5" Camco ,.~ Camco 5" Camco 5" Camco 5" Camco 5" Camco 5" Camco. 5" Camco 5" Camco 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED MAY 2. 0 1991 Alaska Oil & Gas Cons. CommlsBion Anchorage STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATI( IGINAL 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska gg51g-6612 Stimulate Plugging Alter casing Repair well 5. Type of Well: Development X Explorato~/ S~graphic Service 4. Location of well at surface 408' SNL, 156' WEL, SEC. 07, TION, R14E, UPM At top of productive interval 2582'NSL, 1100'WEL, SEC. 08, TION, R14E, UPM (Sag R) At effective depth 2245' NSL, 945' WEL, SEC. 08, TION, R14E, UPM At total depth 2140' NSL, 905' WEL, SEC. 08, TION, R14E, UPM "i2. Present well conditi~m summary Total depth: measured 11691feet Plugs (measured) true vertical BKB 9616feet Effective depth: measured 11481feet Junk (measured) true vertical BKB 9438feet Perforate Other 6. Datum elevation (DF or KB) KBE = 73.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-07 (43-08-10-14) PBU ,! 9. Permit number/approval number 80-13/9-615 ,, 10. APl number 50- 029-20441 11. Field/Pool Prudhoe Oil Pool fill at 11481'MD (01/90) Casing Length Size Cemented Structural -- Conductor 110 20x30 8.5 c.y. Surface' 2661 13 3/8 3720 c.f. Intermediate 10534' 9 5/8 1682 c.f. Production -- Liner 1631 7 540 c. fo Perforation depth: measured 10846'-10876', 10886'-10906', Measured depth True vertical depth BKB 144 144 2695 2695 10568 8656 10059-11690 8253-9615 Sqzd: 10734'-10761' ,(Sag ~), , 10916'-10928, 10938-10943 (ivishak) true vertical subsea 8728'8750' (Sag R) Sag is sqzd:8728'8750' 8820'-8870' (two Ivishak intervals) Tubing (size, grade, and measured depth) 4 1/2"L-80 to 10005' with 4 1/2" tailpipe to 10110' Packers and SSSV (type and measured depth) 9 5/8" Baker SAR packer at 10005'; 4 1/2" SSSV at 2110' , ..... ;1'3. Stimulation or ceme~{squeeze summary see attachment Intervals treated (measured) Treatment description including vOlumes used and final pressure 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure APR 1 2 t991 Alasl~ 0il & Sas Cons. C0~ Anchorage Tubing Pressure Prior to well operation Subsequent to operation , 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1060 1318 2169 1628 880 949 422 911 16. St~us of weliclassific~ion as: Oil X. Gas Suspended 234 237 Service "'~7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~, 1~)-- {~. UUtZ,~/ ~ C'--{. /~~~ Title Supervisor Waterflood/Miscible Flood FOrm 10-404 Rev 06~I 5/~8~ ' d Date SUBMIT IN DUPLICATE WELL X-07 ( 43-08-10-14) PBU REPERFORATING OPERATIONS The following Ivishak intervals were reperforated January 3, 1991, using Schlumberger 3 3/8" carrier guns at 6 spf: 10846'- 10876' MD BKB 10886'- 10906' MD BKB The well was returned to production immediately following perforating operations, then tested. RECEIVED APR 1 ~ t99t Alaska 0ii & Gas Cons. uomm'~ss'~on Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (9o7) 561-5m TO: DISTRI B UTION Date :03/15/91 T#:82226 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. ~-D-10 '"-M-21 ---Y-29 "Y-29 '--Y-29 ""-Y-29 Production Log 03/10/91 #1 10800-11100 Sch 5" Production Log 03/09/91 #1 8850-9200 $ch 5" CBT 03/09/91 #1 12480-13422 Sch 5" CET 03/09/91 #1 12480-13445 Sch 5" CNL 03/10/91 #1 12900-13447 $ch 5" Completion 03/10/91 #1 12470-13426 Sch 5" Leak Det. 03/03/91 #1 7550-10150 Camco 5" Inj 03/04/91 #1 9550:9865 Carn(~ 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES BP EXPLORATION BP Exploration (AI.aska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :01 / 11/91 T#:81981 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. ~ D-24 Perf 01/04/91 #1 10600-10941 Sch 5" ,, P-18 Peal 01/06/91 #1 10400-11368 Sch 5" \ S-28 Peal 01/02/91 #3 9700-9850 Sch 5" · '-. S-30 Peal 01/01/91 #2 11700-12220 Sch 5" ,. S,31 CBT 01/06/91 #1 10380-11342 Sch 5" ~, S-31 CET 01/0'6/91 #1 10380-11365 Sch 5" ,. X-07 Peal 01/03/91 #1 10700-11140 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED JAN 1 5 1991 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORA'ilON BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anclqorage, Alaska 99519-6612 (907} 561-5111 To: Distribution Date: 01/23/90 Transmittal: 80809 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is' your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. C-04 CNL 2.5" Tool 01/14/90 #1 9750-10659 Sch 5" M-23 PERF 01/16/90 #1 9500-10033 Sch 5" X-07 PERF 01/18/90 #1 10700-10990 Sch 5" W-24 TUBING CUTTER 01/15/90 #1 8746-8930 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR -- ARCHIVES RE Alaska 0il 8~ Gas Cons. Anchorage BP Exploration (AtaSka) Inc. 900 East Benson Boutevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska oil & Gas ConservatiOn commissiOn ?orcuPine Drive 300l Alaska 99501 AnchOrage' Attention: Mr. C. V. chatterton en: Gentlem 4~ Form 10-404, _ . in duplic-ate'-b~e-named well. Enclused, ~or t~e ~ _~..n~ the well. ~ratiOnSr ~ _~. ,.,f per~ora~ = ~2~ent repO~u" BJ?: jAM Enclosures (4) cc: ~. Burke (MB12(-l~)2.1) w/10 Well ~ecordS Well File ~eport o[ sundry Well This contains our RECEIVED JAN ! 197 ?,iaska 0il & Gas Cons. C0mmissiot~ Anchora~ · ( STATE OF ALASKA SKA OIL AND GA8 CONSERVATION COM ,, ION {} REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown .__ Stimulate.__ Plugging Repair well $. Type of Well: Exploratory StralJgraphic Plugs (measured) Pull tubing Alter casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, ,4nc~rage, Alaska 99519.6612 4. Location of well at surface 408' SNL, 156' WEL, SEC. 07, TION, R14E, UPM At top of productive interval 2582'NSL, 1100'WEL, SEC. 08, TION, R14E, UPM (Sag R) At effective depth 2245' NSL, 945' WEI., SEC. 08, TION, RI4E, UPId At total depth 2140' NSL, 905' WEL, SEC. 08, TION, R14E, UPM 2. Present well condition summary Total depth: measured 11691 feet true vertical BKB 9616feet Perforate x Other, 6. Datum elevation (DF or KB) KBE = 73.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-07 (43-08-10-14) PBU 9. Permit number/approval number 80-13 / 9-615 10. APl number 50- 029-20441 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 11481 feet true vertical BKB 9438feet Junk (measured) fillet 11481'MD (01,490) Casing Length Structural -- Conductor 110 Surface 2661 Intermediate 10534 Production -- Liner 1631 Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented Measured depth 144 2695 10568 20x30 8.5 c.y. 13 3/8 3720 c.f. 9 5/8 1682 c.f. 7 540 c.f. 10059-11690 10734'.10761' 10846'-10876', subsea 8728'-8750' (Sag R) 8820'-8901' (four Ivishak intervals) 4 1/2" L-80 to 10000' with 4 1/2" tailpipe to 10110' True vertical depth BKB 144 2695 8656 8253-9615 Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. 9 5/8" Baker SAB packer at 10000'; 4 I/2" S$SV at 2110' RECEIVED JAN 3 1 :~,iaSka 0ii & Gas Cons, Rearesentative. Daily Average Production or In!ection Dat~ ~nch0ra~. OiI-Bbl Gas-Mol Water-Bbl Casing Pressure Tubing Pressure 909 1021 1500 259 1065 1814 1623 273 16. Status ofwellclassEication as: Service Prior to well operation 930 Subsequent to operation 900 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby ~.' that ~reg~/, tru~.~d correct to the best of my knowledge. Signed ,~:~_~/-,~-~ / ~'/-~///~ Form 10-404 Rev 06/4"5/88 .~' Title Supervisor Watedlood/Miscible Flood SUBMIT IN DUPLICATE WELL X.7 (43-08.10-14~ PBU ADD'L. PERFORATION OPERATIONS The following additional intervals were perforated as follows: 10846'- 10860' MD BKB 1/18/90 Schlumberger 3 3/8" gun @ 4 spf 10938' - 10943' MD BKB 1 1/4/89 Atlas Wireline 3 3/8" gun @ 4 spf All depths are referenced to BHCS, 5[$/80. A lubricator was installed and tested to 3500 psi for all well work. The well was returned to production immediately following perforating operations, then tested. jm 1/23/90 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard HO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5rll To: Distribution Date: 11/07/89 Transmittal: 80569 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of .-the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. ~ B-15 F-17 ~ ~-o6 ~ X-07 CNL - GR. 11/02/89 ~1 9644-9646 Atlas ., CNL - GR-' 11/01/89 ~1 9500-10315 Atlas PFC 11/01/89 ~1 11008-11296 Atlas CCL 11/03/89 #i 9750-10050 Atlas CCL 11/04/89 ~t 10730-11056 Atlas 5" DistribUtion: ARCO cHEVRON EXXON. GEOSCIENCES HOUSTON MOBIL PHILLIPS RESERV~ ARCHIVES i ECEIVED NOV 1989. Naslm Oil & ~s Cons. C. ommissi~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 995196612 (907) 561-5111 TO: HOUSTON ARCO CHEVRON EXXON TEXACO 'MOBIL P~~ ~ATE OF ALASKA~ ARCHIVES DATE: 01/08/90 TS: 80771 BP FINAL DATA - PRESSURE SURVEY DATA Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. C-20 Static Gradient 12/25/89 Camco C-31 Static Gradient 12/29/89 Camco F-30 Static Gradient' 12/27/89 Camco H-!2 Static Gradient 12/30/89 Camco J-02 Flowing Gradient 12/31/89 Camco X-07 Flowing Gradient 12/25/89 Camco Information Control Well Records LR 2-1 J. Dietz/S. McCurry BP EXPLORATION BP Exploration (Alaslm) Inc. 900 East Benson Boulevarcl RO. Box 196612 Anchorage, Alaslm 99519-6612 (907) 561-5111 To: Distribution Date: 01/08/90 Transmittal: 80772 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. C-03 Prod-F 12/19/89 G-10 Spinner 11/01/89 J-24 Perf 01/02/90 G-13 Prod-F 12/22/89 R-!0 Prod-F 12/19/89 X-01 Spinner 12/23/89 X-07 Prod-F 12/25/89 X-10 Temp 12/23/89 9900-10110 Camco 5". 9800-10050 HRS 5", 10560-11557 Sch 5", 9050-9380 Camco 5"~ 10300-10468 Camco 5", 82-9284 ~RS 2"~5"' 100-11200 Camco 2"/5"' 10500-10930 Camco 5", Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR ~'-._STATE OF ALASKA_~ ARCHIVES RECE iVED JAN Alas~ Oil '8; Gas Cons, Anchorage BP EXPLORATION July 6, 1989 900 East Benson Boulevard P,O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well X-7 (43-08-10-14) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. YoursB~very~i Supervisor Waterflood & ~4iscible Flood BJP: JAM Enclosures (9) cc: L. Burke (MB12-1) Well File APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend Alter casing Repair well Change approved program ~ 2, Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 408' SNL, 156' WEL, SEC,. 07, TION, R14E, UPM At top of productive interval 2582' NSI., 1100' WEL, SEC. 08, TION, R14E, UPM (Sag R) At effective depth 2487' NSL, 1052' WEL, SEC. 08, TION, R14E, UPM At total depth 2140' NSL, 905' WEL, SEC. 08, TION, R14E, UPM 12. Present well condition summary Total depth: measured 11691 feet true vertical BKB 9616 feet OperalJon Shutdown PI. ugging Pull tubing ~ Variance ~ 5. Type of Well: Development x Exploratory Straligraphic Service Re-enter suspended well Time extension Stimulate Perforate X Other 6. Datum elevation (DF or KB) KBE = 73.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-07 (43-08-10-14) PBU 9. Permit number 80-13 10. APl number 50- 029-20441 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 10945 feet true vertical BKB 8972 feet Junk (measured) fill at 10945' (02/89) Casing Length Size Structural .- Co nd uctor 110 20x30 Surface 2661 13 3/8 Intermediate 10534 9 5/8 Production -- Liner 1631 7 Perforation depth: Cemented Measured depth True vertical depth BKB 8.5 c.y. 144 144 3720 c.f. 2695 2695 1682 c.f. 10568 8656 540 c.f. 10059-11690 8253.9615 measured 10734'-10761' (Sag R) 10860'- 10876', 10886'-10906', 10916'-10928' (Ivishak) true vertical subsea 8728'-8750' (Sag R) 8847,-8958' (three Ivishak intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 10000' with 4 1/2" tailp~e to 10110' RECEIVED LI L 1 Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 10000';4 1/2" SSSV at 2110' ~i[~;)~".~ 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: June/July 1989 1'6. If proposal was verbally approved Oil X Gas~ Suspended Name of approver Date approved Service 17. I hereby certify th. at the foregoing is~ an(~rrect to the best of my knowledge. Signed ~ J~'"'/~~~ TitleSupervisorWaterflood/MiscibleFIood / ~ FOR COMMISSION USE ONLY Conditions of apprOval: Notify Commis~on so representative may witness Plug integrity__ BOP Test__ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- /.~' ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH IApproval No. Approv/ed' Copy Returned -- Commissioner Date 7"- (' 7~ ~' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL X-7 (43-08-10~14~ PBU ADDtL. PERFORATION PROPOSAL _ We propose to perforate the following additional intervals during June/July 1989: 10846'- 10860'MDBKB 10906'- 10916'MDBKB I0938'- 10953'MDBKB All depths are referenced to BHCS, 5/5/80. A lubricator will be installed and tested to 3500 psi for all well work. The well will be returned to production immediately following perforating operations, then tested. jm 5/15/89 RECEIVED BOWEN P~~'KOFF FLOW TUBES & PACKOFF GREASE SEAL FLOWTUBE PUMP FLOWLINE FLOWLINE VALVE GREASE LINE GREASE )//~ ~ MANIFOLD · GREASE PUMP RISER '~'- GREASE RESERVOIR BOP BP EXPLORATION TO: HOUSTON ARCO CHEVRON EXXON BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Ancttorage, Alaska 99519-6612 (907} 56~-51~ TEXACO Date: 0 3 -2 2 -8 9 MOBIL TI: 7 9 9 01 PSILLIPS STATE OF AIJ~KA GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES · BP'CASED HOLE FINAL LOGS The following ma*erlal Is being subml~ed herewith. Please acknowledge receipt by signing a copy of *his leu~ter and returning it to this office: M-3L CCL/pERF 03-05-89 -#1 10700-11150 HLS 5" X-07 CCL/PERF 02-22-89 #1 10600-10900 HLS 5" X-12 CCL/PERF 03-09-89 #1 8850-9150 HLS 5" Race i ved Date Oil & Gas Con~.. Commis$io;~ Anchorage ; Shirley McCurry INFORMATION CONTROL Well Records LR2-t BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 21, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well X-7 (43-08-10-14) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well OPerations, for the above-named well. This contains our subsequent report of perforating the well. Yours very truly, B. J. Policky Supervisor Waterflood & Miscible Flood BJP:JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File RECEIVED MAR 2 t' 1~,9 Oil & Sas Cons. STATE OF ALASKA SKA OIL AND GAS CONSERVATION COMMI ~ ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 408' SNL, 156' WEI., SEC. 07, TION, R 14E, UPM At top of productive interval 2582'NSL, 1100'WEL, SEC,. 08, TION, R14E, UPM (Sag R) At effective depth 2221' NSL, 936' WEL, SEC. 08, TION, R14E, UPM At total depth 2140' NSL, 905' WEL, SEC. 08, TION, R14E, UPM 12. Present well condition summary Total depth: measured 11691 feet true vertical BKB 9616feet Stimulate Plugging Alter casing Repair well 5. Type of Well: Development × Exploratory S~'alJgraphic Plugs (measured) Perforate X Other 6. Datum elevation (DF or KB) KBE. 73.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8, Well number X-07 (43-08-10-14) PBU 9, Permit number/approval number 80-13 / 9-O72 10, APl number 50- 029-20441 11, Field/Pool Prudhoe Oil Pool Effective depth: measured 11528feet true vertical BKB 9478feet Junk (measured) fill at 11528'(01/88) Casing Length Structural -- Conductor 110 Surface 2661 Intermediate 10534 Production -- Liner 1631 Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented Measured depth 144 2695 10568 20x30 8.5 c.y. 13 3/8 3720 C. fo 9 5/8 1682 cof. 7 540 c.f. 10059-11690 10734'-10761' (Sag R) 10860'-10876', 10886'.10906', 10916'-10928' (Ivishak) subsea 8728'-8750' (Sag R) 8847'-8958' (three Ivishak intervals) 4 1/2" L-80 to 10000' with 4 1/2" tailpipe to 10110' True vertical depth BKB 144 2695 8656 8253-9615 Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 10000'; 4 1/2" SSSV at 2110' 13. Stimulation or cement squeeze summary see attachment lb 12 ~ ~. ~, . r 14. Intervals treated (measured) MAR 2 Treatment description including volumes used and final pressure ~.~tjJ ~[ Gas.C01~ Reoresentative Daily Averaae Production or Iniection Dat~ - '- ...... OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1160 749 1044 1218 245 Subsequent to operation 1030 1305 1156 1256 250 15.Attachments 16. Status of well classification as: Copies of .Logs and Surveys' run Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify, that the foregoi~ is,true and correct to the best of my knowledge. Signed Title Form 10--404 Rev 06/1~8~1 - Service Supervisor Watefflood/Miscible Flood Date SUBMIT IN DUPEICATE WELL X.'7 ¢43.0g.10-14~ PBU ADD~L. PERFORATION OPERATIONS The following Sag River interval was perforated February 22, 1989 using Halliburton 3 lf2" Dcnsijet carrier guns at 4 spf: 10734' - 10761' MD BKB (8728' - 8750' TVDss) (Ref. BHCS, 5/5/80) A lubricator was installed and tested to 3500 psi for all well work. The well was returned to production immediately following perforating operations, then tested. jm 3/15/89 RECEIVED ,~aska Oil & gas Cons. ~rrn~r0~ Rnchorage Standard Alaska Production Company 900 East Benson Boulevc~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 C9\c· ~ January 23, 1989 ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well X-7 (43-08-10-14) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. BJP:JAM Enclosures (g) cc: L. Burke (MB12-1) Well File Yours very truly, Waterflood & Miscible Flood A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. SKA OIL AND GAS CONSERVATION COMMI ,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon~ Suspend Alter casing ~ Repair well Change approved program 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 408' SNI., 156' WEL, SEC. 07, TION, R14E, UPM At top of productive interval 2531' NSI., 1074' WEL, SEC. 08, TION, R14E, UPM At effective depth 2221' NSL, 936' WEL, SEC. 08, TION, R14E, UPM At total depth 2140' NSL, 905' WEL, SEC. 08, TION, R14E, UPM 2. Present well condition summary Total depth: measured 11691 feet true vertical BKB 9616 feet Operation Shutdown ~ Plugging ~ Pull tubing ~ Veriance ~ 5, Type of Well: Development x Exploratory ~ Sa'atigraphic ~ Service Re-enter suspended weli~ Time extension Stimulate Perforate x Other 6. Datum elevation (DF or KB) KBE = 73.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-07 (43-08-10-14) PBU 9. Permit number 80-13 i10. APl number 50- 029-20441 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 11528 feet true vertical BKB 9478 feet Junk (measured) fill at 11528' (01/88) Casing Length Structural .. Conductor 110 Surface 2661 Intermediate 10534 Production .- Liner 1631 Perforation depth: measured Size Cemented Measured depth True vertical depth BKB 8.5 c.y. 144 144 3720 c.f. 2695 2695 1682 c.f. 10568 8656 20x30 13 3/8 95/8 7 540 c.f. 10860'-10876', 10886'-10906', 10916'-10928' 10059-11690 true vertical subsea 8847'8958' (three intervals) Tubing (size, grade, and measured depth) 4 1/2"L-80 to lO000'with 4 1/2"tailpipe to 10110' Packers and SSSV (type and measured depth) 9 5/8" B~zker SAB packer at 10000'; 4 1/2" SSSV at 2110' 8253-9615 ' ch0mge , 13. Attachments Description summary of proposal x' Detailed operations program BOP sketch X 14. Estimated date for commencing operation I 15. Status of well classification as: February 1989 16. If proposal was verbally approved Oil X Gas Name of approver Date approved Service 17. I hereby certify that the foregoij3g i~ true~nd correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test ~S~~ent f, ,~ entfor r uiredl0- Approved by order of the Commission Corn missioner Form 10-403 Rev 06/15/88 Approve~ Copy Returned / Suspended __ IApp °va N°' Date ~ 7/~:~ SUBMIT IN TRIPLICATE WELL X-7 (43-0~1.10-14~ PBU ADD'L. PERFORATION PROPOSAL We propose to perforate the following Sag River interval during February 1989: 10734' - 10761' MD BKB (ReL ,BHCS, 5/5/80) A lubricator will be installed and tested to 3500 psi for all well work. The well will be returned to production immediately following perforating operations, then tested. jm 1/18/89 FLOW TUBES & PACKOFF BOWEN PACKOFF HAND PUMP GREASE SEAL FLOWTUBE FLOWLINE GREASE LINE FLOWLINE VALVE RISER GREASE MANIFOLD GREASE PUMP BOP .--.~ GREASE RESERVOIR Standard Alaska Production Company 900 East Benson Bouleva~. P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA P~ODUCTION October 20, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well X-7 (43-08-10-14) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, // A. B rag~ ~ &/Manager Production Engineering JAB:JAM~ Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 X-7 Well File RECEIVED OCT 2 6 ] 88 Oil a C~as Con:. C" ....... A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA COMMISS(~,,,i ALA~'KA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 408' SNL, 156' WEL, SEC. 07, TION, R14E, UPM At top of productive interval 2531' NSL, 1074' WEL, SEC. 08, TION, R14E, UPM At effective depth 2221' NSL, 936' WEL, SEC. 08, TION, R14E, UPM At total depth 2140'NSL, 905'WEL, SEC. 08, TION, R14E, UPM 12. Present well condition summary Total depth: measured true vertical BKB Effective depth: measured true vertical BKB Stimulate X Alter casing Plugging Repair well 5. Type of Well: Development X Exploratory Straligraphic Service 11691 feet 9616feet 11528feet 9478feet Plugs (measured) Junk (measured) Perforate Other 6. Datum elevation (DF or KB) KBE= 73.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-07 (43-08-10-14) PBU 9. Permit number/approval number 80-13 / 8-641 10. APl number 50- 029-20441 11. Field/Pool Prudhoe Oil Pool fill at 11528' (01/88) Casing Length Structural -- Conductor 110 Surface 2661 Intermediate 10534 Production -- Liner 1631 Perforation depth: measured Size Cemented Measured depth 8.5 c.y. 144 3720 c.f. 2695 1682 c.f. 10568 20x30 13 3/8 9 5/8 7 540 c.f. 10860'-10876', 10886'-10906', 10916'-10928' 10059-1169 True vertical depth BKB 144 2695 8656 8253-9615 true vertical subsea 8847'8958' (three intervals) Tubing (size, grade, and measured depth) 4 1/2"L-80 to 10000' with 4 1/2" tailpipe to 10110' Packers and SSSV (type and measured depth) 95/8" Baker SAB packerat lO000'; 13. Stimulation or cement squeeze summary see attachment OCT Intervals treated (measured) Treatment description including volumes used and final pressure A~ch~rage 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae Production or In!ectigp Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1200 1336 784 1167 1530 2246 1058 1125 Tubing Pressure 259 241 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas SusPended Service 17. I hereby certify that the foregoing' is true and correct to the best of my knowledge. Form 10~(J4 Rev 06/15/88 Date SUBMIT IN DUPLICATE WELL X-7 (43-08-10-14~ PBU ~TIMULATION OPERATIONS A bullhcadcd mud acid wash and scalc inhibition trcauncnts wcrc performcd on the following perforated intervals in Wcll X-7. 10860' - 10876' MD BKB 10886' - 10906' MD BKB 10916' -10928' MD BKB The mud acid treatment was pumped August 24, 1988, as follows: 1000 gal. dispersed 15% HCI/10% xylene 2000 .gal. 15% HCI 4000 gal. 6% HCI - 1.5% I-IF 2000 gal. 3% NH4CI brine '500 gal. xylene Displaced to peffs with 200 bbls. seawater The following scale inhibition treatment was performed October 8, 1988: 10 bbls. diesel preflush w/mutual solvent 25 bbls. EDTA solution wtdive~ter 42 bbls. scale inhibitor solution w/diverter 191 bbls. seawater oveflush 13 bbts. xylene Displaced to perfs with 176 bbls. seawater After a 24-hour shut-in period, the well was returned to production and tested. jm 10/12/88 RECEIVED OCT 2 6 1988 :~, Oil & G~s Cons. Com~?:,,s~ Standard Alaska (~ Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ALASKA PRODUCTION August 17, 1988 Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well X-7 (43-08-10-14) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB:JAM Enclosures (9) cc: J. L. Haas (MB12-1) X-7 Well File %. A. Br g/ // Manager Production Engineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown I'1 Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing El Amend order El Perforate [] Other [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 408' SNL, 156' WEL, SEC. 07, TION, R14E, UPM At top of productive interval 2531' NSI., 1074' WEL, SEC. 08, TION, R14E, UPM At effective depth 2221' NSL, 936' WEI., SEC. 08, TION, R14E, UPM At total depth 2140' NSL, 905' WEL, SEC. 08, TION, R14E, UPM 5. Datum elevation (DF or KB) KBE= 73.60 AMSL feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number X-07 (43-08-10-14) PBU 8. Permit number 80-13 9. APl number 5 0 - 029-20441 10. Pool Prudhoe Oil Pool 1. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2661 I nte rm ed i ate 10534 Production -- Liner 1631 Perforation depth: measured 11691 feet BKB 9616 feet 11528 feet BKB 9478 feet Size Plugs (measured) Junk (measured) fill at 11528'(01/88) Cemented 20x30 8.5 c.y. 13 3/8 3720 c.f. 9 5/8 1682 c.f. Measured depth 144 2695 10568 7 ~ 540 c.f. 10059-11690 10860'-10876', 10886'-10906', 10916'-10928' true vertical subsea 8847'-8958' (three intervals) Tubing (size, grade and measured depth) 4 1/2"L-80 to lO000'with 4 1/2"tailpipe to 10110' True Vertical depth BKB 144 2695 8656 8253-9615 Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 10000'; 4 1/2" SSSV at 2110' 2. Attachments Description summary of proposal I~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation August/September 1988 4. If proposal was verbally approved ' ~/~ ~ ..)/.~ 5. I hereby ce. rt~fy t~at t,l:)e/foregoing is true and correct to the best of my knowledge Signod' _ ~~..~ ~ Titlo Mana~lerProdu,t~on~r~lineer, n~ -.~ / Commission Use Only Date approved Conditions of approval [] Plug integrity [] BOP Test Approved by{~.~,/~ Form 10-403 Rev 12-1-85 Notify commission so representative may witness IApproval No. [] Location clearance I Approved Copy Returned .. ,~ ~)--~,,~c>~ '~'~'by order of Commissioner the commission WELL X-7 ¢43.05-10-14~ PBU STIMULATION PROPOSAL A bullheaded mud acid wash and contingent scale inhibition treatment is proposed for thc following perforated intervals in Well X-7. 10860'- 10876' MD BKB 10886'- 10906' MD BKB 10916' - 10928' MD BKB Thc trcatmcnt will bc pumped as follows: 1000 gal. dispersed 15% HCI/10% xylcnc 2000 gal. 15% HCI 4000 gal. 6% HCI- 1.5% HF 2000 gal. 3% NH4CI brine 500 gal. xylenc Displace to perfs with seawater If thc mud acid wash is succcssful, the following scalc inhibition treatment will bc pcrformed: 10 bbls. diesel preflush w/mutual solvent 25 bbls. EDTA solution w/divcner 53-63 bbls. scale inhibitor solution w/diverter 200 bbls. seawilI/:r oveflush 500 gal, xylene Displace to perfs with seawater After a 24-hour shut-in period, the well returned to production and tested. jm 8/11/88 I NOEXED .. _ DALI-kS ARCO STANDARD CHEVRON ALASKA PRODUCiION E~XON Date: 02/12/88 TEXACO 78547 TO: Tt: MOBIL PHILLIPS C~_~TE OF ALASKt~ ~ REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: A-26 01/27/88 Static Survey GO A-29 01/30/88 " " Camco A-32 01/28/88 " " GO B-20 01/28/88 " " Camco B-29 01/27/88 " " GO C-12 01/31/88 " " Camco C-35 01/31/88 " " Camco G-19 02/01/88 , " " GO G-26 01/30/88 " " Camco H-22 01/25/88 " " Camco J-21 01/29/88 " " GO N-22 01/24/88 " " Camco S-18 01/30/88 " " GO U-8 01/23/88 " " Camco X-2 01/24/88 " " Camco ~X~' 01 /27/88 " " Camco X-27 01/26/88 " " Camco Y-2 0i/09/88 " " Camco J~ounded ,~, [le.elond C~,o ,,'~ 1870 Victoria Aldridge !NFORMATION CONTROl_ :~e~i Records LR2-1 Standard Alaska Pwoduclion Company~ 900 East 8enson 8oulev0rd P.O. 8ox 196612 Ancho,oge. Alaska 99519-6612 (907! 564-.51 ! I INDEXED DALLAS ,~co STANDARD c~wo. ALASKA PRODUCTION EXXON Date: 08/18/87 TEXACO 78131 TO: Tt: ~0~IL PHILLIPS STATE OF ALASKA REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The tailoring material Is being submitted herevith. Please acknovledge receipt by signing a copy of this letter and returning If fo this office: ""°B-30 08/10/87 '"C-32 08/07/87 "~C-32 08/09/87 / / '"-'JX-2 07/30/87 / '""-~N-21 08/10/87 / ~X-5 07/29/87 ! "'"~X-7 07/29/87 I --~x-9 08/07/87 { '~X-1408/07/87 ~ '"~.Y-1 ,08/07/87 Static Gradient Camco !1 II II 11 II !I 11 II I1 II II 11 II II 11 II II II II 11 II II II II II II II I1 11 II II II II II II II ti I! · Commission -,, Anchorage Race I ved Date A u,,, nf the o*,g,,,,,I Fou-dec! ,n Clevelo,,d Oh,o, ,n 1870 Victoria Aldridge I NFORHAT I ON CONTROL Wel I Records LR2-1 Standard Alaska P~oduction Company ~: 900 Eo$! Ben~on Boulevard P.O. Box 196612 Anchorage. Alosl~o 99519-6612 (907! .564.5111 INDEXED TO: DALLAS ARCO STANDARD CHEVRON ALASKA PRODUCTION EXXON Date: 08/18/87 TEXACO 78131 TI: MOBIL PHILLIPS / STATE OF ALASKA ~ REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following mate~ial is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returnlng it to thls office: B-30 C-32 08/10/87 Static Gradient Camco 08/07/87 " " " II II C-35 08 " " C-38 08 " " J-19 07/28/87 " " J-24 07/30/87 " " JX-2 07/30/87 " " N-21 08/10/87 " " X-5 07/29/87 " " X-7 07/29/87 " " X-9 08/07/87 " " X-14 08/07/87 " " Y-1 08/07/87 " " Y-22 08/03/87 " " Alaska Oil & Gas Cons. Victoria Aldridge INFORMAT I ON CONTROL Wel I Records LR2-1 Slandmd Alaska/ Pweduction C. empany% 900 Eo$1 8ansan Boulevo,d P.O. Bo~ 196612 Ancho,oge. Al¢,d~o 99519-66 f9O?! 564-511 I INDEXED TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA STANDARD ALASKA PRODUCTION Date: 01/,22/87 TI: 77678 REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and returning it to this office: B-19 Static Gradient 01/09/87 Camco B-27 Static Gradient 01/09/87 Camco H-6 Static Gradient 01/08/87 Camco H-24 STATIC Gradient 01/08/87 Camco J-2 Static Gradient 01/i3/87 Camco N-22 Sta~'~/~radient 01/05/87 Go. U-2 Static .Gradient 01/06/87 Camco U-6 Static Gradient 01/06/87 Camco U-8 Static Survey 01/05/87 Go. X-7 Static Gradient 01/17/87 Camco X-9 Static Gradient 01/17/87 Camco X-14 S~atic Gradient 01/12/87 Camco Rece I ved Date I NFORMAT I ON CONTROL Wel I Records LR2-1 A u",! OI the O.(J,no| Founded ,n Clevelo,,d Oh,o ,n SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 April 17, 1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well X-7 (43-'08-.10-14) 'PBU Gentlemen: Enclosed, in duplicate,'isFoTM 10-404, Report of Sundry Well Operations, for'the'above-named well. ThiS contains our sub- sequent repOrt of'stimulating this well. Yours very truly, JAB: JAM ~ L/SupervisOr Production Operations EnclosUres. (14) cc: Drilling Well Files (MB12-1) Well RecOrds.(LR2-1) X-7 Well File RECEIVED APR i ]986 Alaska Oil & Gas Cons. Comm/ssiolt Anchorage ALASK~ STATE OF ALASKA F IL AND GAS CONSERVATION COMM( ON REPORT O SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~_ Plugging m._ Perforate ~.~ Pull tubing Alter Casing ~ Other ~ 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 73.60' Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 408' SNL, 156' WEL, Sec. 07, T10N, R14E, UPM At top of productive interval (top Sag R. SST) 2698' SNL, 1100' WEL, Sec. 08, T10N, R14E, UPM (corrected) At effective depth 2793' SNL, 1051' WEL, Sec. 08, T10N, R14E, UPM At total depth 3140' SNL, 905' WEL, Sec. 08, T10N, R14E, UPM 7. Well number X-7 (43-08-10-14) PBU 8. Approval number N/A 9. APl number 50--029-20441 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 11691 feet Plugs (measured) 9616 feet BKB Effective depth: measured true vertical 10945 feet Junk (measured) 8973 feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented __ 70' 20"x30" 8.5 cu.yd. 2655' 13 3/8" 3720 cu. ft. 10528' 9 5/8" 1682 cu.ft. __ 1631' 7" 540 CU. ft. measured 10860' -10928' (three intervals) true vertical (subsea) 8847'-8958' Measured depth True Vertical depth BKB 110' 110' 2695' 2695' 10568' 8.656' 10059'-11690' 8253'-9615' RECEIVED Tubing (size, grade and measured depth) 4 1/2" L-80 to 10000' with 4 1/2" tailpipe to 10110' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 10000"; 4 1/2" Otis SSSV at 2110' 12. Stimulation or cement squeeze summary Combination EDTA/scale inhibitor matr±x treatment via coiled tubing. Intervals treated (measured) 10860' - 10928' Treatment description including volumes used and final pressure 13. APR 2 1 1986 Ala0ka U~t ~ G~',s Cons. C0mm[ssi0n' Anchcrage 35 bbls. EDTA followed by 56 bbls. scale inhibitor. Final pressure = 1400 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure · , .. Prior to well operation 1460 1170' 79 1122 219 Subsequent to operation 2890 2358 224 1210 231 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15., hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~141~2~./~ Title SuperVisor Production Operations Date Fo'rm 10-404URev. 12-1-85 Submit in Duplicate Well X-7 (43-08-10-14) PBU STIMULATION OPERATIONS 3126/86 4/03/86 pulled SSSV from ball valve nipple at 2110'. Rigged up coiled tubing unit and pressure tested BOP'S to 4000 psi. Pumped 35 bbls. EDTA followed by 56 bbls. scale inhibitor- The following perfor- ated intervals were treated. 10860' - 10876' MD BKB 10886' - 10906' MD BKB 10916' - 10928' MD BKB Left well shut in for 24 hours following the treat- ment. 4/04/86 4108/86 Put' well back on production- Reset and tested otis SSSV in ball valve nipple at 211g'. RECEIVED APR 2 1 1988 Oil & Gas Cons. Commission Anchorage. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed Operation shutdown ' Stimulate ×. Plugging "' Perforate - Pull tubing Alter Casing Other ;~_-. 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 73.60' Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 7. 408' SNL, 156' WEL, Sec. 07, T10N, R14E, UPM At top of productive interval (top Sag R. SST) 8. 2698' SNL, 1100' WEL, Sec. 08, T10N, R14E, UPM (corrected) At effective depth 2793' SNL, 1051' WEL, Sec. 08, T10N, R14E, UPM At total depth 3140' SNL, 905' WEL, Sec. 08, T10N, R14E, UPM Well number X-7 (43-08-10-14) PBU Approval number N/A 9. APl number 50--029-20441 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 11691 feet Plugs (measured) 9616 feet BKB Effective depth: measured 10945 feet Junk (measured) true vertical 8973 feet BKB Casing Length Size Cemented Structural -- Conductor 70' 20"x30" 8.5 cu. yd. Surface 2655' 13 3/8" 3720 cu. ft. Intermediate 10528' 9 5/8" 1682 cu. ft. Measured depth True Vertical depth BKB 110 ' 110 ' 2695 ' 2695 ' 10568 ' 8656 ' Production -- Liner 1631' 7" 540 cu. ft. Perforation depth: measured 10860'-10928' (three intervals) true vertical (subsea) 10059 ' -11690' 8253 ' -9615 ' RECEIVED 8847'-8958' ~bing(size~grade and measured depth) 4 1/2" L-80 to 10000' with 4 1/2" tailpipe to 10110' Packers and SSSV (type and measured depthJ 9 5/8" Baker SAB packer at 10000'-; 4 1/2" Otis 12. Stimulation or cement squeeze summary sSSV at 2110' 13. Combination EDTA/scale inhibitor matrix treatment via coiled tubing. Intervals treated (measured) 10860' - 10928' Treatment description including volumes used and final pressure 35 bbls. EDTA followed by 56 bbls. scale inhibitor. Final pressure = 1400 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1460 1170 79 1122 219 Subsequent to operation 2890 2358 224 1210 231 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. ! hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-494 Rev. 12.1-85 Submit in Duplicate Well X-7 (43-08-10-14) PBU STIMULATION OPERATIONS 3/26/86 Pulled SSSV from ball valve nipple at 2110'. 4/03/86 Rigged up coiled tubing unit and pressure tested BOP's to 4000 psi. Pumped 35 bbls. EDTA followed by 56 bbls. scale inhibitor. The following perfor- ated intervals were treated. 10860' - 10876' MD BKB 10886' - 10906' MD BKB 10916' - 10928' MD BKB Left well shut in for 24 hours following the treat- ment. 4/04/86 Put' well back on production. 4/08/86 Reset and tested Otis SSSV in ball valve nipple at 2110'. 4/15/86 RECEIVED APR 2 1 Alaska Oil & Gas Cons. Commission SOHIO ALASKA PETROLEUM COMPANY · February 28, 1986 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well X-7 (43-08-10-14) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for theabove-named well. This contains our proposal to Stimulate the Well. Yours very truly, JAB: JAM ~ ~grgprodUction Operations EnclosUre s (3) cc: Drilling Well Files (MB12-1) Well RecOrds (LR2-1) X-7 Well File RECEIVED MAR 0 1986 0il & 8~s Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL 12] COMPLETED WELL;E] OTHER [] 2. Name of Operator 7. Permit No. STANDARD ALASKA PRODUCTION COMPANY 80-13 3. Address 8. APl Number P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 50-029-20441 4. Location of Well At surface: 408' SNL, 156' WEL, Sec. 07, T10N, R14E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 73.60' AMSL 6. Lease Designation and Serial No. ADL 28313 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number X-7 (43-08-10-14) PBU 11. FieldandPool Prudhoe Bay Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing I-'] 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). A combination 1500 gal. EDTA/57 bbl. scale inhibitor matrix treatment via coiled tubing is proposed for the following perforated~interVals in Well X-7. 10860' - 10876' BKB 10886' - 10906' BKB 10916' - 10928" BKB The well will be Shut in 24' hoUrs folloWing the treatment. The SSSV will be removed prior to the stimulation'and reset at 2110' after the job. This work is scheduled to commence in March, 1986. RECEIVED MAR 0 ]986 Alaska 0i~ & G~s C~s Cor~lmission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The s,~elow for Commission us~u Co~ns of Approval, if any: J. A. Bragg Title Supvr. Production Operations Date ~'" ~'7~"(~~ I Approved by COMMISSIONSR By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate INDEXED SOHIO ALASKA PETROLEUM COMPANY DALLAS ARCO CHEVRON EXXON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 To:DAL/UNIT/STATE: TE.YACO (-Marathon) MOBIL PHILLIPS ~STATET' Date: 2-i8-86 T#: 76883 BPAE (Transmittal Only) REFERENCE: SOHIO FINAL DATA - PRESSURE SURVEY DATA · . The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office-- -'~-3 ~-I7 -'C-2 "-C-12 "- D-6 ~H-8 -'~X-7 ~'-R-16 1-31-86 Step Rate Data Camco 2-02-86 Step Rate Data Camco · 2-06-86 Static Gradient Camco 2-06-86 Static Gradient Camco 2-04-86 Static Gradient Camco 2-07-86 Static Gradient Camco 2-06-86 Static Gradienc Camco 1-21-86 Flowing Gradient Camco RECEIVED OATE CATHY PERKINS LR 2-i' IMFOR~tATION CONTROL Well Records LR2-! TECHNICAL DOCUMENTATION SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 October 22. 1985 Alaska Oil & Gas Conservation Con~nission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Mr' C;V; Chatterton Wel 1 s C-27. U-8. and 'X.7 PBU Gentlemen: Enclosed in duplicate, is Form 10-403. Sundry Notice and Reports on Wells. for the above named'wells; These contain our subsequents to performing EDTA matrix treatments on these wells, Yours very truly, Michael D. Martin Senior Petroleum Engineer Enclosures cc: T. N. Tyler, (MBg-2) Well Records, (LR2-1) Drilling Well File #17 RECEIVED Alaska O# & Gas Cons. Commission Anchorage STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] X OTHER [] 2. Name of Operator 7. Permit No. SOHIO Alaska Petroleum Company 80-13 3. Address P. 0 Box 196612, Anchoragei Alaska 99519-6612 4. Location of Well At Surface 408' SNL 156' WEL; Sec; 07, TION; R14E; UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 73; 60' AMSL 12. I 6 . Lease Designation and Serial No. ADL 28313 8. APl Number 50- 029-20441 9. Unit or Lease Name Prudhoe Bav IJn~t 10. Well Number X-7 (43-08-10-14)PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] · Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10~407 for each completion,) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals in this well were treated with a 70 bbl EDTA solution on October 17' 1985; The treatment was conducted through coiled tubing as a single stage job and the well was shut-in for 24 hours after the treatment; The SSSV was removed prior to stimulation and reset after the job at 2110" 10860' - 10876' BKB (Ref; BHCS/GR' 05-05-80) 10886' - 10906' BKB (Ref, BHCS/GR' 05-05-80) 10916' - 10928' BKB (Ref' BHCS/GR. 05-05-80) RECEIVED OCT 2 Alaska 0ii & Gas Cons, C0m[~issJo~ Anchorage ~reby certify that the for_e~d correct to the best of my knowledge. Title Senior Petroleum Engineer Date Conditions of APproval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 October 2, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr; C;V; Chatterton Wells X-l,'X-7~'and X-17 PBU Gentlemen: Enclosed in triplicate' is Form 10-403, Sundry Notice and Reports on Wells, for the above named wells~ These contain our proposals to perform EDTA matrix treatments on these wells~ Yours very truly~ Michael D, Martin Senior Petroleum Engineer Enclosures CC' T. N. Tyler, (MB9-2) Well Records, (LR2-1) Drilling Well File #17 RECEIVED OCT 0 ? ]g85 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL)~] OTHER [] 2. Name of Operator SOHIO Alaska Petroleum Company 3. Address P. O, Box 1 9661 2, Anchorage, Alaska 9951 9-661 2 4. Location of Well At Surface: . 408' SNL, 156' WEL, Sec' 7, TION; R14E~ UPM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. 80-13 12. 8. APl Number 5o-029-20441 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number X-7 (43-08-10-14)PBU 1 1. Fie)d and Pool Prudhoe [lay _ KBE = 73'60' AMS[ ADL 28313 : Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate ~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other Fl 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 p~oposed work, for Abandonment see 20 AAC 25.105-170). The following intervals in this well will be treated with a 70 bbl EDTA solutionJ The treatment will be conducted through coiled tubing as a single stage job and the well will be shut-in for 24 hours after the treatment~ The SSSV will be removed prior to stimulation and reset after the job at 2110', 10860' -- 10876' BKB (RefJ BHCS/GR 5-5-80) 10886' -- 10906' BKB (Ref~ BHCS/GR 5-5-80) 10916' -- 10928' BKB (RefJ BHCS/GR 5-5-80) o~ ~m t~o./ hereby certify that~ing ~ correct RECEIVED OCT07 1985 Alaska 0il & Gas Cons. commission Anchorage The space below for Commission use Conditions of APproval, if any: to the best of my knowledge. Title Senior Petroleum Engineer Approved by. COMMISSIONER ,~pproved Copy ~®turned By Order of the Commission Date /0- 7~'Y5 Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TO: SFO/UNIT/STATE: TEXAco (-Marathon) MOBIL PHILLIPS BPA~ 31 1 1 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907! 265-0000 MAIL: POUCH 6-61 2 ANCHORAGE. ALASKA 99502 Date: 8-09-85 76372 REFERENCE: S,~O CASED HOLE FINAL LOGS he ~ollo~in~ material i$ bein~ submitted hero~ith. Please acknowledge rocei~t by ~igning a ¢op¥ of this letter and retumin~ it to this office:-- SFO/UNIT/STATE: D-6 CF S 7 -07 -8 5 9050-9400 GO # 1 D-7 CFS 6-20-85 11900-12330 GO #1 X-7 CFS 7-02-85 10700-11000 GO #1 X-26 Temp 6-18-8 5 9200-9660 GO #1 ' ' 6-20-85 9200-9667 #2 1! 5" 5" 5" RECEIVED . [-)AT(' Alaska Oil & Gas Cons. C0mmissi~thy Perkins Anchorage 19 LR 2-1 Technical Documentation Records Management INDEXED SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON To:SFO/UNIT/STATE: TEXACO (-Marathon) MOBIL PHILLIPS ~ STAT~~ BPAE (Transmittal Only) 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE 1907! 265-O000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 7/19/85 T#: 76322 REFERENCE: ¢ ~~oO ,FINAL DATA - PRESSURE SURVEY DATA· - Ilowing material is being submitted herewith. Please acknowledge receipt by signing a V copy of this letter and returning it to this office:-- A-3~' Static Gradient B-9 ~- Static Gradient B-13-- Static Gradient D-6J 'PBU & BHPD D-7'~ PBU & BHPD H-8-'~ Static M-5i'~ Static Gradient N-E-~ BHPD & Falloff N-8// BHPD & Falloff X-7~'~ PBU & BHPD x-10 j Flowing Gradient X-267 PBU & BHPD 7/05/85 7/03/85 7~04~85 7/08/85 6/22/85 7/06/85 7/06/85 3/04/85 2/01/85 7/03/85 7/06/85 6/20/85 RECEIVED DATE RF F ~.I,~!.,~.._~,,. 2[! ~.~, ~_~,c'~'~ C:~-~. C::?.m:.ss'.~ctoria Aldridge LR2-1 Technical Documentation Records Management SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON ~o SFO/UNIT/STATE' TEXACO__ (-.~ara thon) MOBIL PHILLIPS STATE OF AK BPAE 3t 1 t "C" STREEI ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date ' T#: 02/06/85 75997 REFERENCE' SO~d~CASED HOLE FINAL LOGS / e following material is being submiited herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:' M-17 Spinner 1./17/85 #1 11050-11350 Camco 5" ,~i~X-7,~:, Spinner 1/3/85 #1 10600-11000 Camco 5" G-10 Cont. Flow 1/6/85 #1 9600-10000 GO 5" R-9 Cont. Flow 12/12/84 #1 9050-9500 GO 5" INDEXED SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TE~YACO TO~ SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) , 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 02/05/85 T#: 75990 REFERENCE: he following material is being submitted herewith. Please acknowledge receipt by signing a op¥ of this letter and returning it to this office:-- A-14j 'PBU & BHPD Sheet 11/12,13/84 GO B-2'~ PBU & BHPD Sheet 11/11/84 GO H-7 f Flowing Gradient & BHPD 11/27-29/84 Camco H-~8/ Static Survey 01/07/85 GO H-19"-- St-atic 01/03/85 Otis H-20--'~ Static 01/02/85 GO J-16/ PBU & BHPD 11/24,25/84 GO J-17~'~ PBU & BHPD 11/17,18/84 GO M-7t-~ PBU & BHPD 11/06,07/84 GO N-7j Static 12/07/84 Otis N-10~'~ Static 01/07/85 Camco R-9~ _- PBU &'BHPD 12/12,13/84 GO R-16~''~ PBU & BHPD 11/08,09/84 GO R-18-~ Static 11/26/84 GO ~~ Flowing Gradient & BHPD 01/03-05/85 Camco X-9/ Static Gradient 12/04/84 GO' X-14-" Flowing Gradient & BRPD 12/31/$4-1/02/85 Camco RECEIVEO D~TE ~ i~'O Z A ~ w~ Development Geology ~ ,. ~9 Well Records Alas~a 0~1-'~ ~s '~o~. ou,~.nission July 20, 1984 ADMINISTRATIVE APPROVAL NO. 192.5 Re: The application of Sohio Alaska Petroleum Company, to substitute static pressure surveys for transient pressure surveys for Prudhoe Bay Unit welYs A-15, A-18, E-7, and X-7, an exception to Rule 6(d) of Conservation Order No. 165. Mr. A. E. Leske Manager Reservoir Development Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502-0612 Dear Mr. Leske: The Alaska Oil and Gas Conservation Commission received your request, dated July 16, 1984, to substitute static surveys for transient pressure surveys on'Prudhoe Bay Unit Wells A-I~, A-18, E-7, and X-7. As operator of the western area of the Prudhoe Bay Unit SOhio Alaska Petroleum Company is required to take a transient pressure semi-annually on the PBU X-7'well (a key well) and an annual transient pressure survey in each of the governmental sections where the A-15, A-18, and E-7 wells are located. It is stated that all four Wells are shut-in, have been shut-in for a period of time exceeding ten days, that transient pressure surveys are impractical in this situation and static pressure surveys will provide adequate pressure data for reservoir monitoring. The Commission is in agreement with these facts. By this letter, the Alaska Oil and Gas Conservation Commission herebv waives the requirements of Rule 6(d) of Conservation Order No. 1~5 for the Prudhoe Bay Unit Wells A-!5, A-18, E-7, and X-7 for the calendar year 1984 and will accept static pressure Mr. A. E. Leske July 20, 1984 Page 2 surveys on the wells. This action is taken pursuant to Rule 2 of Conservation Order No. 192. Yours very truly, }larry W. Kugler Commissioner BY ORDER OF T~tE COMMISSION be SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON 311 ~ "C" STREE'[ ANCHORAGE, ALASKA TELEPHONE {9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 SFO/UNIT/STATE: GETTY (-Marathon) MOBIL Date: 3-15-84 PHILLIPS STATE:'OF'AK.::' BPAE (Transmittal Only) CENTRAL FILES(CC#'s-Transmittal ,Oqly) CC#: 75131 REFERENCE: CASED HOLE FINAL LOGS /./~he following material is being submitted herewith. P~ease acknowledge receipt by signing a copy of this letter and returning it to this office:-- C-17 X-7 Basket Fi~ Meter 3-4-84 #1 5300-6800 Camco Spinner 2-27-84 #1 10700-11050 Camco (4/82) RECEIVED DATE ,.. Carolyn Bishop Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY SFO ARCO - CHEVRON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-61:2 ANCHORAGE. ALASKA 99.502 EXXON To SFO/UNIT/STATE: (-Marathon) GETTY MOBIL PHILLIPS :'~:STATE 'BPAE (Transmittal Only) _ CENTRAL FILES (CCft's - Transmittal Only)_ 3-9-84 Date: Trans. f!: CCI~: 75110 /SOHIO FINAL DATA - P_RESSURE SURVEY DATA f/ ~he 7ol,owing material is beingsubmitted herewith' Please acknOwledge receipt bY signing a ¢op¥ of this letter and returning it to this office:-- C-14 ~ .... Flowing Gradient 2-9-84 Otis c-14-./' PBU Data Sheet 2-10-84 S-2~ PBU & PBU Data Sheet 2-21-84 Camco S-6 / PBU & PBU Data Sheet 2-07-84 GO S-8f''' Elowing. Gradient & PBU Data Sheet 2-15-84 Cam~o S-11 PBU '& PBU Data Sheet. ' 2-13-84 GO S-13 ,s- PBU & PBU Data Sheet 2-10-84 GO X-7z Flowing Gradient 2-27-84 Camco X-7,' Flowing Gradient (G/L X-7) 2-27-84 ~ X-7~ PBU Data Sheet 2-28-84 (4/82) RECE, IVED DATE Carolyn Bishojp = Development ueoi Well Records ogy SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON 31 1 1 "C" STREET ANCHORAGE. ALASKA TELEPHONE t907! 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 GETTY To SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS STATE"OF AK BPAE (Transmittal Only) CENTRAL FILES(CC#'s-Transmittal Only) Date: 9/~'~ cct/: 74730 REFERENCE: ~,HI0 CA___SED HO___LE FINAL LOGS /.,/~The following material is being submitted herewith. Please acknowledge receipt by.signing a / copy of this letter and returning it to this office:-- SFO/UNIT/STATE: E-4 Spinner 9/3/83 9500-9870 Otis 5" #1 X-7 Cont. Flow Survey 7/24/83 10700-11000 GO 5" #1 A=18 DFT 7/27/83 9900'10400, GO 5" #1 Y-13 DFT 7/26/83 10100-10900 GO 5" #1 (4/82) RECEIVED DATE ~-" " toria Aldridge TPi-5 Development Geology ........... ~9 Well Records .i SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO - CHEVRON 311 I "C" STREET ANCHORAGE. ALASKA TELEPHONE {go7! 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 EXXON ~o: SFO/UNIT/STATE: (-Marathon) GETTY MOBIL PHILLIPS STATE BPAE (Transmittal Only) _ CENTRAL FILES (CC#'s - Transmittal Only). 8/16/83 Date: Trans.#: - 74652 CC#: REFERENCE: f.cTS,,Ot~'O FINAL DATA- PRESSURE SURVEY DATA_ he following material is being submitted herewith. Please acknowledge receipt by signing a opy of this letter and returning it to this office:-- B-18j Pressure Survey & BHPD B_19~? ,, ,, ,, ,, B-20 j' " " " " B-21/ " " " " B-22~ " " " " B-23 j "' " " " D-16j Static Report D-21. " " D_22j' ', ,, D-23 ~/ " " ~ M-5j Pressure Survey X-7~ Pressure Survey & BHPD 7/18/83 Camco 7/26/83 Otis 7/28/83 Otis 7/30/83 Otis 7/17/83 Otis 7/16/83 Camco 7/27/83 Camco 8/01/83 Camco 8/08/83 Camco 8/04/83 Camco 8/03/83 Otis 7/24/83 GO '~/82) RECEIVED DATE ~/z~'~~~~~~L~ictor ia Aldridge ~ .Development Geology ., T' :[' T :~ '.~ . ' ~ ::~9: .......... Well Records TP1-5 , ~ , ~ . ,,- ,,.~,:~ SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON 311 1 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-61 ~ ANCHORAGE. ALASKA 9 9502 TO: SFO/UNIT/STATE: (-Marathon) GETTY MOBIL PHILLIPS STATE OF AK BPAE (Transmittal Only) CENTRAL FILES(CC#'s-Transmittal Only) Date: 7/22/83 CC#: 74588 REFERENCE: HIO .CASED HOLE FINAL LOGS - . The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- D-3~' CNL D-4 CNL E-9 CNL .. F-7 CNL F-8 ' CNL F- 11 CNL G-4- ' cNL G-13.-~ CNL J-3 B-12 · H-6' .F-7 - X-7 ~ 5/ 5/ CNL 5/ DDNLL 5/ DDNLL 5/ DDNLL 5/ Completion Record EPL 5/ EPL 5/ 5/16/83 #3 9900-10673 Sch 5" 5/16/83 #10 9900-10667 Sch 5" 5/17/83 #1 9595-10907 Sch 5" 5/14/83 #1 11160-11885 Sch 5" 5/13/83 #5 10500-11194 Sch 5" 5/13/83 #1 8900-9586 Sch 5" 18/83 #3 9400-10304 Sch 5" 18/83 #1 8650-9418 Sch 5" 19/83 #3 9500-10090 Sch 5" 11/83 #2 8750-9395 Sch 5" 14/83 #5 11160-11898 Sch 5" 12/83 #2 10630-11578 Sch 5" 4/23/83 #1 8600-9250 Sch 5" 15/83 #1 11380-11850 Sch 5" 12/83 #1 10740-11150 Sch 5" (4/82) RECEIVED OArE ,~ ~S ;~:~, , .~.:.,Well Records Victoria Aldridg e DeVelopment Geology TP1-5 SOltlO ALASKA PE Ii~OI_FUF~I COMt'ANY SFO ARCO 3111 'C o IeEE1 AIJCttORnG[, Al ASKA I[ILI'HONE {907} 255-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 10: EXXON PHiLLipS STATE OF AK Date: 7-19-8_3 074579 Trans.~: cc~: CENTRAL FILES(CCl/'s-Transmittal Onl~f REFERENCE: SOHIO MAGNETIC LIS TAPES & LISTINGS The (ollowing maleriai is being submitted herewith.-Please acknowledge receipt by signing a copy 'of 1his letter and returning it to this office:- ''' "-' .~'/-'~; '; ~..~7 /-.' /.:. ~,".? 01>'.'/-. ...... "' ' V-"^ ':'~ ': , ' .... '" i '"' / '" ' "'"' "':'" ,,,; O] ',/'~ ' : ' ' '' ./.' . .... ~.,~ :,.. : .. ......., ACC. # . (.... ' ,. ,,.~ -:*C-10 CH CNL 6-23-83 run ]. Sob 68405 .-*M-4 TI:Y2-M 5-23-83 run 3 Sch 68324 ..*B-12 TDT-M 5-11-83 run 2 Sch 683:1_9 --*F-3 CH ~ 5-30-83 run 1 Sch 68350 -'*X-7 TDT 5-12'83 run 2 Sob 68292 .-*F-'ll Q-I CN~ 5-13-83 run ]. Sch 68276 -'*N-6 Tl:Y2-M 5-].8-83 run 3 $ch 68305 ~ ~/')~...) .. ,*J-]. TUT-lq 5-19-83 nm 3 Sch 68308 ,., "' : ..*G--].3 CH C[~ 5-].8-83 run ]. Sch 68312 ........ , ..... Open Hole 6-2].-83 run - .GO 2286].0 Open Hole 6-9-83 run _ Go ].0229]. _... , ' ., ._~..: ...... I ~, . ~, ... ' .- ': ~ C 'v F ', '/ / ,":: .... ,' ' 1~:'' e ;~"y. ~, _ -- ..... -. / . ..~., . . :7..' . " ........ //~ , , ~.., ,," / .~ , , I , , . / /. .- ~.i () : . .-. . . "~ , t., . / -- . .... .~ / : ,,.'f / ... --7" / ,~'" ~ / 7: "" · >. .... . ;" ",.-.' .... O , -:_. '-.: ..., · ,,~.. '.. :~1 .... ~ --->~ ~ / .. :5 .... ' ~. ,,.:' ......... abouV.e--.ra eans s~ould have .s~0 ~ ~.xx0~-" ~^st'er'~'sk:(*) ~t to a l~sti~g you received the Tape(s) and Listing(s) directly from the respective service company- P1 eas'e c°nfirm this' ~~.~'I/fl'j'~C~,VE.. ' ' ~'~"~'~.-- Development Geology ~ ~ Well Records DATE SOt410 ALASKA PETF~OI-EUM COF'.~'IPANY lO: SFO ARCO EXXON PHILLIPS · . STATE OF AK' CENTRAL FILES(CC#'s-Transmittal Only, 3111 "C" S1 P,[ El ArJCt!ORAG[. ALASKA I[LLPHO.N[ (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99 502 . Date: 7-19-83 074579 Trans.(l: cc#: Pg. 2 of '2 REFERENCE: SOHIO MAGNETIC LIS TAPES & LISTINGS The following material is being submitled herewith.-Please acknowledge receipt by signing a copy of this letter and returning it to this office:- ACC # /*3115 RFT ~-15 open hole tape ~ · .*Y-2 TDT-M ~ ,r , ~*~f,.ll ' ~-M "". ....... " .... (' /~-14 o~n Hole ta~ ~J-3 ~ ~ 6-13-83 runl Sch 68374 6-13-83 run 1 SCH 68374 6-5-83 run 2 Sch 68354 5-20-83 run 2 Sch ·68322 5-17-83 run 1 Sch 68348 5-16-83 run - Dres 1719. 5-26-83 run 1 Sch 68347 5-19-83 run 3 Sch 68313 5-28-83 run 1 Sch 68349 5-18-83 run 3 Sch 68311 *SFO & EXXON' An Asterisk:(*) next to a listing abouve means you should have received the Tape(s) and Listing(s) directly from the respective service company. Please confirm this. ./~/~ ~.////~ '~ ~ ° ~..'"'- /DZ Anne Jones Development Geology DA~£ ~9 Well Records SOHIO ALASKA PEIF[OLEUM COMPANY SF0 ARCO - CHEVRON 3111 "C" SIREE1r ANCHORAGE. ALASKA TELEPHONE {907I 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99,502 EXXON GETTY ~o~ SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) _ CENTRAL FILES (CC#'s - Transmittal Only) Date: 9-24-82 Trans.#: 2670 CC#: 55670 REFERENCE: FINAL DATA - PRESSURE SURVEY DATA copy of this letter and returning it to this office:-- A-15" N-15-' A-19 A-18 G-19 E-15'" E-10 E_i~' E-20-' N-!4 R-7 ~' N-12 /(--7 ' M-16 E-11.~ E-11~, GO Pressure Survey and BHPD 8/27/82 Otis Pressure Survey and BHPD 8/28/82 Sch. Pressure Survey and BHPD 8/29/82 GO Pressure Survey and BHPD 8/29/82 Camco Pressure Survey 8/27/82 GO Pressure Survey and BHPD 9/3/82 GO Pressure Survey 9/14/82 GO Pressure SUrvey 9/14/82 GO Pressure Survey 9/7/82 GO Pressure Survey and BHPD .8/16/82 Otis Pressure Survey ,and BHPD 8/19/82 GO PreSsure.Survey and BHPD 8/18/82 Otis Pressure Survey and BHPD 8/9/82 Camco Pressure.Survey and BHPD 9/10-12/82 Otis Pressure Survey and BHPD 9/13/82 Otis Pressure Survey 9/1/82 Otis PressUre Survey and BHPD 9/11/,82 '82) RECEIVED DATE Al~k,~ Oit & Gas Cons. C0m.m~J0n Anchorage' Karen Mestas DeVelopment Geology Well Records SOHIO ALA,,SKA PETROLEUM C()MPANY ARCO -- C~tt7 , _ TO: SFO/UNIT/STATE (-Marathon) 31 1 1 "C" S-[REET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL' POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 4/9/81 # 718' REFERENCE: . SOHIO FINAL DATA. CASED HOLE he following material is being' bubmitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- ,~.. F-9 DDNLL 3/20/81 #1 5" ~ TDT-M 3 / 1 / 81 # 1 5" X- 10 TDT-M 3 / 8 / 81 # 1 5" Carol Krieter Development Geolgg~ Well Records ;FO/St/MPC/AE: ;F0/ST/AEP: .,RCO/STATE: SOHIO ALASKA PETROLEUM COMPANY ARCO EXXON MOBIL TO: PHILLIPS CHEVRON SFO REFERENCE: SOHIO & / MPC TRACT WELL MAGNETIC LIS TAPES & LISTINGS ,,//~he following material is being submitted herewith. Please acknowledge receipt by signing a /~/ copy of this letter ~rning it to this office:- ** MP Tract;W~ll' (4~)31-11-13 Magnetic LIS Tape & Listing #61417 **'-MP_Tract Well (13)15-11-12 Magnetic LIS Tape & Listing #61475 * GC 3B Magnetic LIS Tape & Listing #61407 9/25/7~ ~ ,, ,, ,, " #6125'1 1/14/81 B-2 _ r"7"--'X-7-~'" ,, ,, " " #61447 3/1/81. \ / t- i R~.~b ".:,'~'~ ' 31 11 "C" STREET ~9-3 ~ .... ~' ....~ TELEPHONE i907)26s-oooo j .... ~t- ~_~, I MA~L: POUCH 6-612 ~-L-~ .--~/~-tANCHORAGE, ALASKA 99502 ..... s VqTrxT T~C ~ 2/8/81 #3 3/18/81 #- Kuparuk St. 22-11-12~~netic.LIS Tape SP 8700-10100 3/18/81 F-9 ~ Magnetic LIS Tape DNLL 9550-10200 4/2/81 . . MM Tract Well ((32)30'11a13 Magnetic LIS Tape & Listine #61463(61345) 1/9/8i~ #1,2&3 APR '-"-" DATE ~laska ii & ~'"~ C.00.~-commissi°~9 ..,, Carol Krieter Development Geology Well Records SOHIO ALASKA Pk--rROLEUM COMPANY ARCO lC~t~: X' roi3 -to:. SFO/UNIT/ST: --[=7,:¥ar a thon'} ' 3] 1 '1 "C" SIRF_ET ANCHORAGE, ALASKA 'tELEPHONE {907i 265-O000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date:3~24~81 # 684' REFERENCE: ///"SOHIO FINAL DATA CaSed hole . The following material is being' ~ubrnitted herewith. Please acknowledge ~eceipt by s[gnin9 a copy of this letter and returning it to this office:-- !,'O/UN I T/STATE: B- 6 B-14 E-5 Spinne~Con'"'~:--'Flow 3/3/81 #1 5" Spinner Flowmeter 3/6/81 Spinner,.Con't Flow 2/.2'2/81 #1 5" Spinner,Gon't ~low 3/9/81 #1 5" DA T E _ - --;- 19 , , Carol Krieter Development Geol.ogy Well Records SOHIO ALASKA PETROLEUM COMP'ANY ARCO ~o: SFO/UNIT/ST: 3111 "C" STREET ANCHORAGE,'At ;,,$KA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 3/24/81 # 683' REFERENCE: SO.~IO FINAL DATA .., T~wing material is bein~l"~;ubmitted 'herewith. Please acknowledge receipt by signfng a /z,,copy returning ii to this office:- of this letter and SFO/UNIT/STATE:~ BottomHo.le Pressure Data Form & Survey (camco) (-Marathon) ~ ,, ,, ,, " " " (Go) · 311318 319181 RECEIVED 19 Carol Krieter Development Geol.ogy Well Records ALASKA ,L AND GAS CONSERVATION C ~,'MISSION WELL COMPLETION OR RECOMPLETION REPORT 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 C(mpany 80-13 . 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20441 4. Location of well at surface 9. Unit or Lease Name 408' SNL, 156' WEL, Sec. 7, T10N, R14E, UPM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2922' SNL, 1267' WEL, Sec. 8, T10N, R14E, UPM X-7 (43-08-10-14) At Total Depth 11. Field and Pool 3140' SNL, 905' WEL, Sec. 8, T10N, R14E, UPM Prudhoe Bay 5, Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 73.60' AMSLI ADL 28313 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 4/14/80 5/3/80 1/9/81 feet MSLI one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD~TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost l1691'MD 9616'TVD 11638'MD 95711TVE YES ~ NO [] 2110 feetMDI 19501 GL 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, BHCS/GR, FDC/CNL/GR/Cal 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT'PULLED · . . 30"x20" Insulat~ Conduct¢,rSurface 1i0 ' 36" 8.5 cu.yds, cOncrete . . 13 3/8" 72# L-80 Surface 269 5' 17 1/2" ~720 cu. ft. Permafro;~t "9 '5/8" 47# Soo-95 Surface i0568'. .12 1/4" 1552 cu. ft.. Class G;iL30cu. ft. Permafro: 7, 29# L-80 10059' 11690' 8 1/2" 540 cu.ft. Class G" , 24. Perforations open to Production (MD+T. VD of Top and Bottom and 25. TUB, lNG RECORD · interval, size and number) MD .TVD .. SIZE DEPTH SET (MD) PACKER SET (MD) Prudhoe Oil Pool: Top: 108~0' 8847' 4 1/2" 10111' 10001' Bottom: 10928' 8958' .... , ' . ,10860-10876'BKB 0 5"@4,s, pf (Ref.BHCS/GR, 5/5/80 i~6.' ACID, FRACTURE, CEMENT SQUEEZE, ETC. · "DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ~10916-10928'BKB" " ( " ) ~ · ~. . I ¢,'4. .. .. '....: .,-- .~ .. : · ' . . , . .. . , ", : , , , 27. PRODUCTION TEST ' '~ Method of Operation (Flowing, gas lift, etc.) ' 1-.9-8!._~Flowing ~~t Hours Tested PRODUCTION FOR OIL-BBL GAs-McF' WATER-BBL CHOKE SIZ'E IGAS-OIL:' RATIO '" . .. ;., :. TEST.PERIOD.e Flow Tubing: .. CasinglP, ressure. CALCULATED i~ OI'L'BBL GAS-MCF WATER-BBL oIL GRAVITY-APl (corr) ' '"Press.. . :, . . ',. '. 24_Hour RATE I~'j ' · "! : ~ :" " 28. CORE DATA . , -- -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · .. None'RECEIV[I) JAN2 8 I 8i ,' ,' Alaska Oil & Ga.3 .Cons. ComrnJSsior] Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. ~ ' ' - , GEOLOGIC MARKERS FORMATION TESTS . ., NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , BKB Subsea Sag River SST. 10735' 8717' · Shubl ik 10761 ' 8740 ' Ivishak 10847 ' 8814 ' · 31. LIST OF ATTACHMENTS None ~2. I her 'byc',_, . . rue and correct to the best of my knowledge e ~t /,/¢.., S 'g n~ _ ,~'~-.~. /,,.~_,~ O¢"d~ TitleDistrict Field Date _/ t G.J. \Plisq~'- (J Ena~_neP_r / / .... INSTRUCTIONS General: 'This 'form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt 'water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more'than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported .in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21 "Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 PERFORATING DATA - WELT. X-7 (43-08-10-14) December 20, 1980: Pressure tested tubing and inner annulus. January 9, 1981: Rigged up Schlumberger and perforated the following intervals using 2 7/8" hyperdome guns at 4 spf: 10860' - 10876' BKB (Ref. BHCS/GR, 5/5/80) 10886' - 10906' BKB ( " ) 10916' - 10928' BKB ( " ) Put well on production. January 21, 1981: Shut well in to prepare for static pressure survey. January 23, 1981: Ran static pressure/temperature survey at 8800' TVDss. January 24, 1981: Set and tested SSSV in ball valve nipple ca. 2000'. Well on production. SOHIO ALASKA PETROLEUM COMPANY January 26, 1981 3111 "C" ANCHORAGE MAIL: POUC R"~-~I~'~C~'I::.O~ ,,, ..... i CONFER: C~ID~ ~ ,, Alaska Oil & Gas Conservation Ccmmission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilt°n~ RE: Wells X-7, X-8, Y-3 Gentlemen: Enclosed, in duplicate, are the following forms for the above- referenced wells: 1. Form 10-407, Completion Report; ® e Form 10-403, Sundry Notices '& Reports on Wells; Form 10-404, Monthly Report of Drilling & Workover Operations. ~isl;i~7~eald Engineer GJP:JLH: ja Enclosures CC: Well File %17 S. R. Bundy A. E. Leske 2 8 lg81 Anchorage 1. DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Sohio Alaska Petroleum ~y 3. Address Pouch 6-612, Anchorage, Alaska 4. Location of Well At surface: 7. Permit No. 80-13 99502 8. APl Number 50-029-20441 9. Unit or Lease Name Prudhoe Bay Unit · 10. Well Number 408' SNL, 156' WEL, Sec. 7, T10N, R14E, UPM X-7 (43-08-10-14) 11. Field and Pool Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool _ KBE = 73.60' AMSL I ADL 28313 12. Check Appropriate Box To Indicate Nature of Notice, Report~ '°i~'~0ther Data '~" NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) , (Subm. i~.i,.n~) .upr~ate~_._~__..~-' Perforate [] Alter Casing [] - Perforatio~'~' .................J~ 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~ incl'uding estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals were perforated on January 9, 1981, using Schlumberger 2 7/8" hyperdome guns at 4 spf: 10860' - 10876' BKB (Ref. BHCS/GR, 5/5/80) 10886' - 10906' BKB ( " ) · 10916' - 10928' BKB ( - '" ) An SSSVwas set and tested in the ball valve nipple ca. 2000'. E£E VED JAN 8 1981 - Anchorage , 14. I rtif n~ is true and correct to the best of my knowledge. Signe~,~, ~j ~ (~~ District Field Engineer Date The ~p~e bel~ fo%~sion use ~ Title Con~ons of Appro~i~' any: · By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "1 ntentions" i~-~riplicate and "Subsequent Reports" in Duplicate · STATE OF ALASKA ~~ ALASKA(~' ',L AND GAS CONSERVATION C~"'IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well r-~ Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 80-13 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20441 4. Location of Well 9. Unit or Lease Name at surface Prudhoe Bay Unit · 408' SNL, 156' WEL, Sec. 7, T10N, R14E, UPM 10. WeHNo. X-7 (43-08-10-14) ..... 11. Field and Pool Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 1 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 73.60 ' AMSL[ ADL 28313 For the Month of January ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or 'liner run and quantities of cement, results of pressure tests ...... : · 14. Coring resume and brief description . " " 15. Logs run and depth where run ~16. DST data, perforating data, shows of H2S, miscellaneous data : See attachment. R~C~VE~ JAi", 2 8. ]gg] b~,,~~ha~s AlasKa 0il & Gas Cons. Co~missiorl 17. I here true and correct to the best of my knowledge. ~'~lqOJ~OJ'~.~jU .... NOTE--I port on thi~,fo~m is required for l :h calendar month, regardless of the status of operations, and must be file~in. dui Oil and Gas Conservation-'l~ommission by the 15th of the succeeding month, unless otherWise directed. Form 10-404 Rev. %1-80 the Alaska Submit in duplicate SOHIO ALASKA PETROLEUM COMPANY October 31, 1980 _.. j 3111 "C" SThEEIT 3 ENG ANCHORAGE, / 2 GE~ MAIL' POUCF~-glZ_ · ANCHORAGE, AL, SKA ~ STAT CONFER: FILF: CO~D~ 'i'i~~: Alaska Oil & Gas. Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Subject: Wells D-13, C-16, F-12 Gentlemen: Enclosed, in triplicate, are Forms 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our proposals to perforate the wells. "-~ DistriC~t~ield Engineer GJP: j a ~ Enclosures cc: Well File #17 S. R. Bundy A. E. Leske STATE OF ALASKA ALASKA-{/ o AND GAS CONSERVATION C(~~- MISSION SUNDRY NOTICES AND REPORTS' ON WELLS 1. DRILLING WELL I~ COMPLETED WELL [] OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of Well At surface: 408' SNL, 156' WEL, Sec. 7, T10N, R14E, UPM 5. Elevationinfeet(indicateKB, DF, etc.) 6. LeaseDesignationandSerialNo. KBE = 73.60' AMSL ADL 28313 7. Permit No. 80-13 8. APl Number 50-029-20441 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number X-7 (43-08-10-14) 11. FieidandPool Prudhoe Bay' Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 12. NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] - Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10407 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). The following intervals will be perforated during December 1980/January 1981, using Schlumberger 2 7/8" Hyperdome guns at 4 spf: 10860' - 10876' BKB (Ref. BHCS/GR, 5/5/80) 10886' - 10906' BKB ( " ) 10916' - 10928' BKB ( " ) An SSSV will be set and tested in the ball valve nipple ca. 2000'. Subsequent Work Beported o'~ Form No. ~ Dated I It-3/-~l "-" rrect to the best of my knowledge. Thespa~lowfo~o~missionuse G~ *. Pl~'8~a T'deDistrict Field Engineer Conditions of Approval, if any: Approved by Form 10403 Rev. 7-1-80 By Order of COMMISSIONER the Commission Approved Copy //- - Date ~ _ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA 9u',. AND GAS CONSERVATION C~MMISSION SUNDRY N.. TICES AND REPORT ,)N WELLS I--1 - DRILLING WELL ~ COMPLETED WELL ~ 2. Name of Operator Sohio Alaska Petroleum Company 3. Address POuch 6-612, Anchorage, Alaska 99502 4. Location of Well At surface: 408' SNL, 156' WEL, Sec. 7, T10N, R14E, UPM 5. Elevationinfeet(indicateKB, DF, etc.) KBE = 73.60' AMSL I 6. Lease Designation and Serial No. ADL 28313 12. j 3 ENG 7. Permit No. !4 ENG 80-13 --'T-~GEOL 'Il 8. APl Number i"'2 GE~! 50-029-20441 I 3 GEOL / II 9. unit or Lease Name ~ STAT TEc~l Prudhoe Bay Dnid~t STATTEC~ .. X-7 (43-08-10-14)CON.FER:__ 11. Field and Pool --l_ F~IL'F: ~ Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] . Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) ..... 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals will be perforated during December 1980/January 1981, using Schlumberger 2 7/8" Hyperdome guns at 4 spf: 10860' - 10876' BKB (Ref. BHcs/GR, 5/5/80) 10886' - 10906' BKB ( " ) 10916' - 10928' BKB ( " ) An SSSV will be set and tested in the ball valve nipple ca. 2000'. 14. I her y is true and correct to the best of my knowledge. Si,ned(/__ ~~ ~ ~ . TideDistrict Field Engineer G J Pllsga The spa~..below fo Co mission use · (_5 Conditions of Approval, if any: ' '- By Order of Approved by . COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Date Returned Date Submit "Intentions" in Triplicate and "Subsequent Reports" i n Duplicate SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company . SOHIO-BP ALASKA PRODUCTION DIVISION TO: SFO/UNIT/STATE -2' '-co_ .MLY l. 3111 "C" STr EET~-EN~V.%~ Phill;i~ , ,,. _ _ i ii i ., .~t"O .... - ...... '~ '_' _ . · ' ' -- iim REFERENCE: SOHIO CASED HOLE FINAL LOGS ,- //The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- D-ii Temp. Log 5/12/80 #1 B-16 Spinner Log 5/23/80 #1 D-12 Temp. Log 5/25/80 #1 E-8 Temp. Log 5/24/80 #1 N-7 Spinner Log 5/18/80 #5 Temp. Log 5/13/80 #1 511 5" Sit 5" 5" 5" Anne Barns Well Records RECEt'\/!'D 19 SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION ARCO TO: EXXON PHILLIPS 3111 "C" Sl~'REI~T ANCHORAGE. ANCHORAGE, SFO REFERENCE: SOHIO MAGNETIC TAPES /~The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- C-15 Magnetic Tape II I! !1 II NW~;1 RD~;1 " " ,z/60375 3/5/80 #60466 5~5/80 #60325 2/15/80 f/60407 3/21/80 ARCO/SFO/ST: W. Sak ~/14 Magnetic Tape #60434 4/9/80 Anne Barns Well Records SOHIO ALASKA PETROLEUM COMPANY June 4, 1980 MAIL: POUCH ANCHORAGE, ALA~ Alaska Oil & Gas Conservation Oom~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton We11 X-7 (42-08-:!_0 -14) Enclosed, in duplicate, is Form 10-404, Fbnthly Report of Drilling and Workover Operations, for the above-named well for the month of May, 1980. Yours very truly, SOHIO ALASKA PETROLEUM CCHPANY Enclosures cc: Well File #17 District Drilling Engineer Form No. 10~104 REV. 3-1-70 SUBMIT IN DUPLICATE STATE F ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL 2.NAME OF OPERATOR OTHER 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 4. LOCATION OF WELL 99502 at surface: 408' SNL, 156' ~EL, Sec. 7, T10N, R14E, UPM $. APl NUMERICAL CODE 50-029-20441 6. LEASE DESIGNATION AND SERIAL NO. ADL 283___13 7. IF INDIAN-ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Ba Unit 9. WELL NO. X-7 (4 3-08-10 -14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, P~hoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 8, T10N, R14E, UPM 12. PERMIT NO. 80-13 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANy OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. May, 1980 ' If 1 I . Directionally drilled 8% hole to 1~691 .? _Ra~...op~___hOle_logs,_:' Ran 41 jts. 7" 29 #L-80 Buttress casing to 11690'. uemen~d wzt~ 540 cu. ft. Class G cement. Cleaned out to 11638', tested casing to 3000 psi., ok. Displaced well to NaC1. Ran CBL. Ran 235 its. 4%" 12.6 #L-80 Buttress tubing with prOduction packer tailpipe assembly and 5 to 10,D lac · · pa at 2111'. Installed and tested tree. · bal ' e 10001', tested tubing to 3500 psi, ok. Released rig at 1500 hrs 5/9/80. 14. I hereby ~if~reg~ 'o~tr~ue and correct SIGNED~2' _~_ ~<~_~. -- TITLE District Drillin~~ATE___~__. ~2~__D NOTE--Report on this form is required for each calendar month, regardless of the status of operatio~ oil and gas conservation committ-,o hv th , 1Rth nf ti- , " , SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION I I I i i i __ TO: ~ _ . ,,, .... -- -- _ SFO/UNIT/STATE C'~t7 ,, ~ ........ 3111 "C" ANCHORAGE, TELEPHONE (907) MAI L: POUCH ANCHORAGE, ALASI ~ #168 M~il l~ilhl~ -- . ..... Ill! I I I SFO -- _ I II I i! REFERENCE: ~~_ l,_i ~... _ lJll- ~[~,~1~ [ ~j~~ '0 HOLE FINAL DATA OPEN lowing material is being submitted herewith. Please acknowledge receipt by signing a this letter and returning it to this office:- I/UNIT/STATE: ;TATE ONLY: X-7 ~DC 5/5/80 #1 X-7 FDC/C~TL 5/5/80 #1 X-7 BHCS 5/5/80 #1 X-7 DIL/SFL 5/5/80 #1 X-7 Gamma Ray 5/5/80 #1 2" & 5" 2" & 5" 2" & 5" 2" & 5" 5" X-7 '~arol Kridter Well Records Gyroscopic Survey Magnetic S.S. Survey s/14/8o 5/5/80 SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAG E, ALASKA 99502 June 6, 1980 CONFID~IAL Alaska Oil & Gas Conservation Con~nission /L~_! F_NG '~_ 3001 Porcupine Drive ,/ _.~cho~z~ge, Alas],~ 99501 Gentiamen: ~11 X-7 (43-08~10-14) ~~.'---'~ Enclosed, in duplicate, is Form P-7, Completion Report, for the above-named well together with the' Well History, Well Logs, and Directional Surveys. This well has been suspended pending perforating operations. RER: ja Enclosures cc: Well File #17 Geology Yours very truly, District Drilling Engineer Form P--7 STATE OF ALASKA (s~ :~m- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: OIL GAS 'r-'~ WELL r~l WELLU DRY r'-'~ Other b. TYPE OF COMPLETION: NEW ~ WORK DEEP-r'--I PLUG r--I DIFF. WELLI~__.J OVER ['-'] EN ! I BACK.I I RESER.I I Other 2. NAME OF OPERATOR Sohio Alaska Petroleum Company 3. ADDRESS OF OPERATOR Pouch 6-612, Anchoraqe, Alaska 995.02 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* Atsurface 408' SNL, 156' WEL, Sec. 7, T10N, R14E, UPM At top prod. inte~a~ reported below top Sag R. SST. 2698' SI~, 1100' WI~, Sec. 8, T10N, R14E, UPM At total depth 3140' SNL, 905' WEL, Sec. 8, T10N, R14E, UPM 5. APl NUMERICAL CODE 50-029-20441 6. LEASE DESIGNATION AND SERIAL NO. ADL 28313 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Pr~d~ Ray ]"[n'it- Prudhoe Bay, Prudhoe Oil Pc~ 1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 8, T10N, R14E, UPM 12. PERMIT NO. 80-13 13'DATE SPUDDED 114' DATE T'D' REACHED 115'DATE COMP' SUSP' OR ABAND'4/14/80 [ 5/3/80 5/9/80 1'6'ELEVATIONS (DF'RKB'RT'GR'~17' ELEV'CASINGHEADKBE = 73.60' AFL~L 39.80' ~L 18. TOTAL DEPTH, MD & TVD 119. PLUG BACK MD & TVDI20. IF MULTIPLE COMPL., I , I DEPTH I HOW MANY* 21. ROTARY TOOLS INI'~-RVALS DRILLED BY CABLE TOOLS 11691 MD 9616'TVD[ 11638'MD 9571'TVD[ I To~al . 22. PRODUCING INTERVAL(S), OF THIS COMPLETION - TOP, BOTTOM, NAME (MD & TVD)* 23. WAS DIRECTIONAL SURVEY MADE= None Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SFL/SP/GR, BHCS/GR, FDC/CNL/GR/Cal 25. CASING SIZE 30" x 20" 13 3/8" 9].r 5/8'! , ,, 26. SIZE 2~. PERFORATIONS OPEN TO PRODUCTION Noz3e , , CASING RECORD (Report all strings set In well) ulated', C(bnduct°ir ll0 ' 72,~, , I L-801 2695' 47# , I .qd 10568" - 29# ~ I ~80 110059-11690' LINER RECORD TOP (MD) I BOTTOM (MD) I SACKS CEMENT* I tr" DATE FIRST PRODUCTION 17k" 12~" 8~'" I 540 CU. ft..~ass G 27. .TUBING RECORD 4½" , , FLOW TUBING CASING PRESSURE HASTE PR ESS. 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc,) CEMENTING RECORD / AMOUNT PULLED 8.5 cu. yds. Permafrost c~ncrete 1552 eu. ft.C. lassC~..- ] 30 c3~Jf~-- p~.rmafrn.~t SCREEN (MD) SIZE DEPTH SET (MD) PACKER SET (MD) 10111 ' 10001 ' 29, ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ET~, DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED i Jl /IJi'll~gl'i],g~ PRODI JCTION JPRODUOTION METHOD (Flowing, g~s lift, I~umDIng--.~lze and type of pump) I PROD'N FOR OIL-BBL. TEST PERIOD IWELL STATUS (Producing or shut-in) ' GAS--MCF. J GAS-MCF. J WATER--BBL. J GAS-OI L RATIO WATER-BBL. J OIL GRAVITY-APl (CORR.) I JTEST WITNESSED BY 32. LIST OF ATTACHMENTS Well History, Well Logs, Directional Surveys' .,-.-..-:,SLGI~ED ' -- .-- '~ TITLE District Drilling Engineer ~'w:ja R.H.. Reilev ~ ' DATE INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where n°t otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item' 26: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, ~ WATER AND MUD 35. GEOLOGIC MARKERS ..... NAME "M'E~S'. DEPTH TRUE VERT. DEPT BKB SubSea Sag River SST. 10735 ' 8717 ' Shublik 10761' 8740 ' Ivishak 10847 ' 8814 ' 36.'CORE oA'I';Ai'ATTACH BRIEF DE$(~RIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. , , , , (~"m~.T. X-7 (43-08-10-14) WELL HISTORY _April, 1980 Spud well at 2100 hours, April 14, 1980. Drilled 17 1/2" hole to 2700'. Ran 68 jts. 13 3/8" 72# L-80 Buttress casing to 2695'. Cemented with 3720 cu. ft. Permafrost cement. Installed and tested BOPE. Cleaned out to 2653', tested casing to. 3000 psi, okay. Drilled out to 2726', ran ~ ~ · leak-off test to 0.66 psi/ft, gradient. Directionally drilled 12 1/4" hole to 10575'. Ran 269 jtg. 9 5/8" 47# S00-'95 Buttress casing-to -10568'. Cemented in two stages: First stage with 1552 cu. ft. Class G cement; second stage through D.V. packer at 2616' with 130 cu. ft. PermafroSt cement preceded by Arctic Pack. Cleaned out to 10525', tested casing to 3000 psi, okay. Drilled out to 10598', ran formation competency test to 0.69 psi/ft, gradient. Directionally drilled 8 1/2" hole to 10610'. May, 1980 Directionally drilled 8 1/2" hole to 11691'. Ran open hole logs. Ran 41 jts. 7" 29# L-80 Buttress casing to 11690t. Cemented with 540 cu. ft. Class G cement. Cleaned out to 11638t, tested casing to 3000 psi, okay. Displaced well to NaCl. Ran CBL. Ran 235 jts. 4 1/2" 12.6# L-80 Buttress tubing with production packer tailpipe assembly and 5 gas lift mandrels to 10111" landed tubing with ball valve nipple at 2111'. Installed and tested tree. Displaced tubing to diesel. Set packer at 10001'. Tested tubing to 3500 psi, okay. Released rig at 1500 hours', May 9, 1980. EFW: ja d. A. Fouch6 ~res/~ler~t 19, ~980 Sohio Alaska Petroleum 3111 C. Street ComPany Anchorage, A~ 99503 Re: Job Survey .... ~oss_16587 Well X-7 rt dhoe Bay Pield h S/ope, Alaska Dear Mr. Plisga: · Date of Survey: 5/14/80 Please find encl our Boss ~,_ Osed the ,,~ · . Well '~roscopic ~,~: .ur~g~nal ,, ~...~ . . ' ~ "~U~Snot Dir6~+.~'u s~xteen =~onal Survey (16) cOpies of . on the above Thank You .fOr giving us this Opportunity to be of service. YOUrs very trulyl SpERRY-.S~k~, INC. Doug Walker DW/kc Sen/or SUrvey Engineer R ~ C EhclosUres CONFIDENTIAl. STA OF ALASKA COP'v S (i- H ]' o ALASKA FRUPHOE BAY ~LASKA PETROLEUM CO. S F ED-,. R--y~-SUN "' 'WLFT_-E--Su R V E y I N G' ' C 0 p, p" A Ky ANCHORAGE, ALASKA CO Y P'U'I.a 1' 1~i,; N DATL MAY 15, 1980 MEASURED DEPTH TRUE SUB-SE A COURSE';:: 'i.:. CCUR SE VERTICAL ..... VERTICAL INCL'INA'TiON ..... DIPECTI DEPTH DEPTH DEG MIN DEGREE PAGE DATE OF SURVEY MAY 1A~ 19~:D DoSS (~¥RO&~jOPiC SURVE~ ,JOB NUMBER B05S-16587 KELLY BUSHING ELEV. = 73,60 oPEKA [uR-WALK£N FT, ON' DOG-LEG TO 'SEVE'RITY .... RECTANGULAR DEG/IO0 NORTH/SOUTH TAL ' ' cooRD"INAiES VLRilCAL EAST/WEST ,SECTION 0 100 200 ~+00 500 600 700 800 900 lO00 1100 1200 1.300 1AO0 O',O0 100.00 26,4'0 199,99 126,39 299'99 ..... 226,59 399,98 326,3~ 499,96 426,36 599,95 526;35 799,93 726,33 899';'9'1 826,51 999,89 926,2? 1099,86 1026,26 1199,83' :" .1126;'2" 1299,80 1226.20 1399.77 1,326,17 150'0 .... 14'~9,15 ' I~26'i5 1600 1599.7A 1526,14 1700 1699.72 1626.12 I~UI) ........... 1799,70" ' 1726,'10 1900 1899'69 1826,09 PO00 1999,68 192.6,08 2100 ...... 2 D .'9 ."9',' 67 ...... 2026.07 2200 2199.67 2126,67 2300 2299,66 2226,06 2AOD 2~¥V,-65"' . 2500 2Aq9,6~ 2426.04 2600 2599.63 2526.0,.3 2700 '26,q~j'62 ' ' 2800 2799.55 2 72 5.95 ~900 2899.~1 2825.71 O 2'9 ...: S 35.50 0'38 '" ':S 19.50 E 0 52 S 1~. 0 E 0 57 S 20,69 E ~' '"48!'... S ,6, O E 0 58 S ~3,10 E 1 0 S ~9.80 E 1 ~7 S ~ .8~ E 1 2~ S ~0.60 E 1 -"'26' - $ 3U,iO 1' 18 S..22, O E ] ~ ' S' zl .50 E 1 8 S 11.39 E 1 8 S 1~.~ E 0 5~ ' '$ ~9.60 E 0 ~8 -: .',.S 26, 0 E O 37 .S 26.50 E O' ~u S 0 36 S 2R,8~ E 0 45 S ~3.10 E ~'53 S ~ 58,"'< E ~, 09 6,00 '49" -22 1- 22 · 0'~ ..... 2,3i · 22 3.62 · 13 5.15 · 42 6.42 · 18' 7.52 .12 8,70 · 25 J · 20 11.75 · 12 13,74 · Ob i5,A7 · 28-: - 18.02 · 15 20,09 .1 ~ ...... 2i..97 .21 23.82 · 06 25.76 · 3¥ 27,~0 .-1.1 28,71 · 'lq 2.9,83 · 07 31,86 · 27 32.82 '. ' ;2~ :. ..- 53,72 O 55 2 50 4 51 s1 65,~59 E, :,::~'.o9 : 7~'.69'E'' ........ .22 ~8.19 E 1.94 68. 0 E 2,01 65,89~E: . i' 33 ' . ~ S ,25 E . 59 S ,68 E 1.22 $ ,99 'E 2'0~ S 1,30 E 2,9~. S 1.78 E S 2..SH E 5.52 S 3,66 E 7,02 S ~,90 E 8.69 .S 6.1M E i0.~ S 7,q3 E 12,~3 S 43.68 E 1A,52 $ 9,92 E 1~.69 S 10.98 E 1~.71 S 11.74 E 20.~3 S i2.4i E "' 2i.97 S 12.97+ 'E 23-~''''~ S 13,39 E 24.., S i/+-0~ E 26.17 ' S 14,74 E 27.45 S 15,29 E 28.50 5 15.76 E ' ' 29.43 S 16.22 E S 16,89 E 31,41 S ' ~ I8,00 C ' - 32,8.3 - 3A.4q S !q.19 E 34.22 35,03 S 20,31 E ~5.4~, 35,5i' ,<_: 21 .'6~"E 3g.gJ "' 36.6q S 2~.7G E AO.12 ~9,15 S $o,gg E 46,76 42,95- .% 39,85 E SOHIO ALASKA PETROLEUM ---'%--7'-TRl:lFT1 O pr~ UDHOE BAY ALASKA CO- SPERRY*S'UN R'ELL'.SURVEYING. C.O~PAKY - . AN £H. ORAGE, :A_LASKA . . ~Y 15~ 19fid -. MEASURED DEPTH TRUE :.:-.::': :.;:,.SUB-SEA COURSE:i:',: :::" :-'COURSE DOG-LEG '' VERT'i~'~'L ....' ...... VEMT'iCA'E .... IN"¢LINAIION ..... EIR'ECiION "SEVERIT'V RECTANGULAR DEPTH DEPTH DEG MIN DEGREES DEG/1 Or., NORTH/SOUTH 3100' ~.200 3300 3500 3600 ~700 3800 3900 alOO a2oo DATE OF SURVEY MAY 1~, ~0S$ GYROSCOPIC SURVEY dOB NUMBER BOSS-165f17 KELLY BUSHING ELEV, = oPERA~oK-WALKE~ TOTAL - COORDINATE~. EAST/WEST .1,Sq '- 2, flT'.'..-:~' 52,30 2,21.~: ..' 57,07 z',iS' ~2.9U 2.21 70,00 2.27 78.51 2,01.. ' 88.Z~q 'S · ~.. 17 ' 100.12 S 2',66 - 11.3.32 S 29 .... 5fi ....... S .... 73','1'9"E ............ 2'"i"0 ........ 121.2q, s 32 13 S 73.50 E 2.64 1~1,95 S ~fl 53 S 73.69 E 2,67 157.55 S 5500 5600 5700 5800 5900 GOO0 ~i'o o ~ ! 52" s.-. i.z.,'sO .'E q O I 0 S :: 72...'19-" E ~ ~ 5 s,.'7.'l:"~-;.:'e E ~6 .... ~b ..... 's .... ~9.5d' E ~7 18 S 69.39 E ~7 3il S 68.69 E :.q9 C S. 67'59 ~ ' ~ S B?.'~O- ~9 53 S ~7. 9 E 50 ~8 S 66,69 E .o-,'Oq,.:,:. -.: :. ,~I~.58 3"'65" .......':''238.~4 · 72 26~.09 · 55 290.~1 , '.-'i8 31-t.2 -E "-"75' 3~..'68 E::..' ..':.....:,~7 .- . _ .15 .97 ~62,05 50 ,.'gq E 65,R3 .E 85,0A E i08,35 135,58 E 1 66,29 E 200,22 237.96 E 280,02 E S'25. iO L 37~ ,90 E ~27.92 E q.~q · iz 5 q~+. 75 E 607.77 E ....... 6 7~",'i2 'E 7q2.5q E 811 .29 E 8g~6 ,,~b 950.13 E 1.019.88 E /U'~U eU~ L 50'71,97 ~998-.37 51 56 S 6~,59. E 5133,33 ":5059,73 52 20 S 66.50 E : ..... 519~.b2 5-i'2'0',92 .............. 52 '"i.2" S 66,' 0 E 5255.~9 5122.29 52 5 S 65.50 E 531~,98 52~3.3fl 52 35 S 65. 9 E .bm'7?;'~.. '. :b~O~',5~ b2 ' 1'6 - ~ ~.56 b -.'6U~' ..S93. i 6 ..85.. 52~,58 :,' ~-'7, 556 · 1 3 · Z~ :" '": ...... .ql 620o5A · 60 653.62 · 57 ' S 1160.53 S 12 31 · 35 S i302.55 S 137q.30 S lqA6.68 S .... i5i9,02 S 1591.01 s 1662.94 S 17 54', 66 PAGE 1980 73.60 FT. 'VERTICAL SECTION 68.2. 83.38 102,3~ i2.5,24 152,2.6 182,95 217.i5 255.~8 298,31 4~7,81 505,27 566,~.7 631,28 i 0 O ,~k 772. 8qq, 917. i.~' 991.6~ 1 066, O2 -i i41.15 1216.82 12q3.06 i37~a,ii 1 ~ 7.77 1526,Dq · 1604.5i 1682,90 17~1,5~ i~40.43 SPERRY-SUN W.:LL. SURVEYING "COMP ANY SCPIO ALASKA X-? i~l~+ilu PF UDHOE BAY ALASKA DETRCLEUF CO. AN CHORAGE,~ ALASKA COi.~PUT'AT i 0 ~ DATE MAY 15, 19ED DATE OF SURVEY M4Y 1N,~ EO$S 'GYRO$CO'PiC SURV-¥ dOB NUMHER B08S-16587 KELLY BUSHING ELEV, = IJl.-' E ~ A ~-tJ R - W A Lt~ E, R ....... NFASURED DFPTH TRUE SUB'SEA Vt, R iICAL ~"VER~ICAL DEPTH DEPTH C'OU'RSE )-COURSE :";.'-:.L::.DOG',LEiG .' TOTAL · INC'LINAilcN ' ~i~ECTION''~'' 'sEVL'Ri-'T¥ .... F. EL;TANGULAP .... COORDiNAT£S DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST 6200 '"543:9,67 ... -5566,'07:_--.:: 51' '28' 'S 64,!9 E.:::::~..:-.::.:~::.':::......:?...~.':~3 721,~2 S i805,b8 E ~300 (' ..55 0 2"* 07,' ...'.. .'...' :' 5 ~ 28"47 :- :' .'.' '51 1'7' :..:.S 63 ,.80 ': E::~".;::(:.:~;~:{~':::t~?~'36 _.. ' 755,G8 S 1875.81 ~ 6600 5693.71 5620.11 ~9 ~7 S 62.59 E .~3 ~58,~0 S 2082,47 E 6700 5752.73 56R5.13 49 26 S 62.39 E .15 893,~8 S 21A9,87 E 7200 73G0 7400 7500 7600 , 7700 7~00 7900 800'0 ~1.00 82[:0 ~3.'Do ....... 8400 ~500 ~60 O ' A70O ~8'00 68D0~':, ' 5823.95' !--"57~D'-~5 7000 '5954" 98". "--~'; 5":88I · 3~ ~100 6021.20 6087,99 601~.39 6154,77 60a1,17 628~-34 .'~": 6:215,7~ 6357-25 . .... g425";86 6352 6q95,13 ~705,35 ' ....66-31,75 6920.~ 68~7.33 6~9~.17 6929.57 ?0'68 · 2~.. '~ :"' · .-.7~3"08 ~'--- ......70~9' 7218,.A9 7144,8'9 8900 ....... 729~,7] ..... ~000 737~. ~7 7298.07 9100 7A~g,93 7376,33 ~2DO I530,62 '-' :~ ~ -:~ ~ .::?!:.i:::::"s:-'i'.:.:~:~:~::"; ~:O:"E:'iii?:.~-:::i!';' i':~:~;'i!::~.;o6 . e6s.1o 0'8 4'6 ';-:ii<i;:. :;?i::i'" ::,51 999 ' 71 ~ UJ~+, U~ 47 54 S 63. 9 E ,5fl 1067.98 48 18 S 63. 0 E .42 1101,71 - <' -m-- - ~ ""' - .... . .-.... -,.: -.. ' ;>2i6,6~ E 2283,30 .E 25/49,53 E 2e15,75 E. 26R1,50 E 2876,78 E 45 45 S 64. 0 E 43 8. S 63,80 E 42 40 S 64.89 E · 32 1297.75 S 2.941,22 ,29 i359W76 S 3069,22 · 99 :..".159~':.e~ S 3132,q0 · J5 1.420,¥6 ~ gl ~'~' 8~ · 80 1~5],20 S 3256,7] 39 21 5 64,6~ E ,69 1619,92 S 37 39 S 61,50 E 2,63 1648,05 S ~q q~' .$.-50-,5.9 E.:.' _....:. ~+,97 ' 1679.18 S 36 lq ,79 36 70.3! 37~0~5 E l~O 73.60 FT, .... VERTiCAL SECTION 1 9i a. 7 ' 199&,5~ .... .. ~DU,DD 2226.60' 2302.~3 ~37~.13 R~53,68 2528,96 z~um.72 ' 2677,97 2752,21 282~,2~ 2899,76 2972,96 3117, 3~b9 91 3330.50 3400,~ 3~6~"~ ..... 3538.2B 3606.05 3672,~9 3738,88 380~-17 393~.0~ 3994,11 SOHIO ALASKA PETROLEUM X-7 7 iTT~-Ti-i~ PRUDHOE BAY ALASKA CO. SFERRV-SUN ~ELL SURVEYING COMP~A.Y AN£HORAGE, ALASKA· CO MPuIA'1'IO r~ ' D'ATE 1980 DATE OF BOSS G'Y ,JOB NUM KELLY OP ER A sUB'SEA COURSE COURSE : !: DOG-LEG T VERT'i'CA'L' 'iNC"LINAIION'" UINEg:ilCN SE, VE'HIiY RECYANGULA DEPTH DEG MIN DEGREES DEG/1DO NORIH/SOUT · TRUE ED ..... D EPT H DE P Th .o4.00 '~500 9700 9POO 9900 10000 lOlO0 ,,~' i 0.~00 10300 1O400 9300 :' ' 7613,,32 7539'72 7r:, .qG.97 7623-37 7781 -28 77071'68 '7866 ,'1"6 ......77'92'56 7951.48 7877.8~ B036.79 7963.19 8205' 8~9.22 8575.62 8527.~3 ~500 ' "860~';65 :': 8.550-05 ~ 0600 S68'0'~5 10700 8761.52 · 8687..92 108uu 1 ~900 8933.31 8859.71 21000 9C20.05 89~6.45 11100 11200 9194.56 9120:,96 · ll~O0 9282'07 9208,~7 1 1500 9~5~,3~ 11600 953R.90 9465,30 ~' HORITONTAL · ~2 1647,55 · 53 1881.36 .1916;51 1.68 1953, 93 :!:':27 ' 1·993'66 leJ2 ;'"05b,Z I 1,96 2079,10 1.65 2125,.31 l* 92 ::: ::::E 17q eO 3 7,~2~;:.~ .2273,85 29 ~2..., 29 48 29' '1_~ 28 · 32 .. 2.9 1 9 , : .: 31 58 32 31 27.50 E S 26. 0 E 2q · 6T-J E 23.19 E 22.50 E ',2.1,69 E 21.60 E 20,69 E DISPLACEMENT = . 5290'7A: FEET AT:SOUTH, .z~6 2364.55 ,75 2408,98 '!,,0.6:: 2497,75 · :86. 25~2.34 1,13 ....... 2588'47 1,59 2636.59 ,73 2686.36 S :0., O0 '2732-i~ S : · . · . . P~GE' 4 SURVEY ~qaY 14, 1980 EER BOSS-165P_,7 BUSHING ELEV, : 73.60 FT. OR-WALKER OTAL R 'CuoROiNATE$ .... VERTICAL H EAST/WEST SECT/ON 3/6b.i8 r. qlOU,lb 3808,9~ E ~163,5.n, 3850.63 E A216.73 · '3~9i,25 E ~268,~ - 39~1,15 E ~320,51 $ 3970,88 E 4371,99 S ~050,91 E a~78,00 S ~g90,70 E 8532,59 S ~172.01 E a646.54 S 4213.98 E 4706.14 S 4256'3~ E ~767.61 S ~295,88 E ~N27,53 S ~326.99 E q879,62 S .......4351'36 E ~924~ S ~74.59 E ~967, S ~396.78 E 5009.17 S ~lt.vl E 50~C'.2~ S 4~37,55 E 5089.92 S 4~56,33 E 5129.03 '~ .... 4475.06 ~E 5i68'89 ' S 4~94.~6 E 5210.10 4513.~1 E 5252.2R 4530.71 E 5270,7~ .... AT ~D '= 11691 TM[ CALCULATIOK PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. SOHIO ALASKA PETRCLEUH'CC. PRUPHOE P,.~Y /~LASKA SPERRY'SUNi WELL..:SU. RV!E.¥ING COMPA~!Y CATE OF · ,AN£HOR. AGE';ALASKA' . C 0 '~P U 'FA T I U Fi 'D'A yL MAY 15, 1980 PAGE ":URVEY M~Y 1Ae 1980 dOB NUMBER PSSS'iGE.~7 KELLY BUSHING ELEV. , .: :- . OPEN ATOR-WALK E~( INTERPOLATED ··VALUES· FOP.::. V N' ' F' " ".-,¥.~E E ~lOO0 LET OF MEASURED DEPTH 73.6C FTo TRU MEASURED VERTI DFPTH DEPT 0 l'OOO 2000 3000 AO00 .'5.000 6000 7000 "' P, O00 1999.68 1926, 2998,8/+ 2925,2/+ 595~';'98 ........ 6634.85 6561,23 7~71.&7 7298.07 62 05.06 96 15. ~3 E SUB-SEA TOTAL CAL VERTICAL RECTANGULAR COORDINATES H DEPTH-··~ .:NGRIH/SOUIH-..·-_~· LAS~/W~S)- ..: . ,....-.L-L ..-.'..":i... ii <-',':-:' O0 '7 "~ ' ' ..... ~' '~"""""'9~'6;2v'' ~'" ~' "zz. ~ ~ ~.~ ~ ~000 ~coO0 11000 11691 THE CALCUL ATICN PRCCEDURES ARE 29.83 S 15.29 E 42o93 S 39° 83 E · -: 12~7-2~' 5....-i-'--~.-~.-.-..~25, 7 O. E z ~.~'.~, G~. ? s~.~. ' ~..;. e5 o' ~-z E ~9./z S ........ 255'O.'~q"'L ...... ZC~5;;U2 1328.96 S 3005.36 E 1365.17 1619.92 S ~61~.79 E 1628.5~ 2 7 ~ 2.1 4"~<':S~ "' '--:';:455 0.-:'.71 ? E..~ ~'.' 2 ~ 75," S 7 , ~. MD-TVD VERTICAL U I F !" L. iq I:..N C L 0'oo: · 3. i ,11 · 32 ,21 1,16 312-620 257°8 · 6'83w 82 3 70 m62'.O U 320.16 263.16 166°61 185.0 1 95,/+3 RADIUS OF CURVATURE ~4ETHOD. BASED ON THE USE OF THREE DIFENSI£,NAL SOHIO ALASKA PETRcLEuM ' X-7 7Riz~TiO PRUDHOE DAY ALASKA SPERrY'SUN~ WEEE-SugVE¥ING AN CHORAG'E~ ALASKA . CO~U¥'ATiON'DAT'E MAY · ' EvEN 1:00 iFEEI:'OF:~i~iSUB'SEA TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES ~D-TVD DE'PTH :- · .:DE'PT'H. NI3['V, TH/~gUFH:' EAS.?/W~,.s.J---:/DJ..FFE.~LNCE , '::i'o~. o-o o 'oo :: ~ o. ~ o 173 275 373 473 573 673 173.60 100.00 273,60 200,00 :37'3~60':~' ..'~ 300~'00 q-7..3'6:ro' : .....4:00,00 s 7 3-6 o 673,60 .01 .01 , Oq 773 773,60 700° D 873 873,60 80D.O 9'?$" · 9 7.3 "60 · · 1e73 ~o73.60.. '~'.,:.lono.o 1173 1173.60 ,:' 'I.I00-0 · : . ;... 1273 ........127~-6 o ........ i'2 o o · o 1373 1~73.60 1}O0.O 1~73 1473.60 1573 ' ~ 157:3,~0' ..... ~ ::iSP'U,U 1673 1673.60 1600.0 1773 I77~-60 .' 0 0 0 0 DATE OF SURVEY MAY lq9 ,JOB NUMBER BOSS-16587 KELLY PUSHING ELEV, gPLRAio~-WALKE~ DEFTH 1960 73.60 FT. VERTICAL .00 .01 .2Q °26 ,01 .01 .0~ .01 .0~ ,03 .02 °02 ,02 SOHTO ALASKA PETROLEU?, CO. x-~'r' 7Rt4TlO' PR LIDHCE BAY ALASKA SPERRY-SUN WELL sURvEYING 'COMPANY ANCHORAGE, ALASKA Co!,~P'UIA i iON DA MAY 15,~ 1980 DATE CF SURVEY MAY 14, PAGE dOB NUMBER POSS-165R7 KELLY E. USHING ELEV. oPE~. AiUN-BALKEF 7,3,60 FT, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA -DEPTH MEAS DEPT TRUE tIRED VERTICAL H DEPTH SUB-SEA TOTAL VERTICAL. RECTANGULAR COORDINATES YD-TVD DEPIH NCRTH/~.OU3~H ~AS~/wE~i b~FFEH:EN£E 1873 1873.60 1.~73 2073 2073,60 2173 2173,60 2273 2273.60 2,373 23,73.60 2473 2473..60 2573 2575,6'0 ' ' 2673 2673.6 2774 2773.6 2R74' ~ 2873,6 2~74 2973.6 3075 3073.6 ~17~ 31'73;6 3278 3381 ~590 3697 3273.60 3373.60 3473.60 3573o~0 3673,~0 '1800,00 2000,00 21DO.OD 2200,00 2300.00 2400.00 2500,00 0 2690.00 0 2700.00 0 ' 2800-00 G 2900.40 0 30~!D,00 3100.'OD 3200.00 3300.00 3500.00 3600.00 2u.'b? S' ' 30.57 S 31.61 $ .32.57 'S 33,-50 S"- 3~ .-28 :S 35.40 S 36.16 S 58~.3.5 -S "'4 1"~.2 S 46.38 S 14'5~ E 15.17 'E 15.64 E 16,10 E 16,65. E 17, 66 E 1R.92. E' 2 O' ~1' L 21.27 E 23.56 E 37.34 E ~7.'87 E ...... ' 32 .32 .33 . :5'6 ,37 ,~+1 .b~ 1,.01 1.67 55,96 S 80.45 E 61,68 S 103,57 E 77.61 S 163. 18 E 88.15 S 199.2q E 4.61 7.~2 I6,80 23,.6~ VERTICAL CORRECTiO .0 o0 ,01 ,01 ,01 .01 ,01 .01 ,66 1,10 1.84. 2.81 5,36 6,84 SOHIO ALASKA PETRCLEUP X;-'7 7RI 4Ti'O PRUPHOE BAY AL~SK~ CO. SPERRY-SUN ~ELL '$URVEyING'""'CDNP~EY ANCHOR'AGEv ALASKA COM'pU~rAI ION ' MAY 15, 198..0 INTERPOL.ATED VALUES FOR EVEN..iOO....FE£:T? OF 'SUB-SEA DATE OF SURVEY MAY 14,~ lgR2 MEAS , DE. PT TRUE SUB- URED VERTICAL VERTI H 3806 3773'60 3700° ,JOB NUMBER BOSS-16587 KELLY BUSHING ELEV. : UPERATuR-WA L~ER VERTICAL CORR~.ET iON PAGE H -' DEPTH SEA TOTAL CAL RECTANGULAR COORDINATES ~,D-TVD DO llb, lb ~ ....... 2'B7'"~r E 4~,'25 73.60 a032 3973.60 3900-°00 4150 4073,60 4OOO.O0 4272 ' ~'17'3,.'60" :-:'..AiO0.O0 A400 '~273.6D ~200,00 4535 4373*60 AS. OO.~ 0 4828 4573.60 4500,00 a978 4673.60 4600.00 131.91 S 3~1.21 E 58.7~ 1~9.68 S fiOl,lg E 76.67 22-2:,:8D.::'.S'~ - ::~- 631 · 2 q-. E . ... 162 · 35 2b ~'.'U6' 's ......... 72~.16' E- ........... 297.99 S 830,7A E 25A,72 338,65 S 935,12 E 51;'50 · ~773.:60 .. ;-.q. IL'ID.OD 5285 :: 4873°60 "' 4800.00 5442 ~97.3°60 qgOO. O0 5682 ' bO'7'3' 66 ...... b U O 8"° g'O 5765 5173-.60 5100,00 5928 5273,60 5200. O0 6D~2 .... ' 53~.~°60..:,~.',:, 6251 ..5473,"60 .. '/ 54~0.00 . 6~13 55:73,60- ..: "55~0,~0 ., . '-~.75:.o0'~? S ....... . .1 261° ~7' E--:'-:':'?~.'-'~'~:;'' ~'.68 · 72 ................. - ............ i L._ ....i: i.'..--.:'"-:~_"~ · ~ ~ 577.14 S 149~.3~ E 592.26 629.97 S 1611.71 E 655.23 ,. - ... ,- .-- ~: - '184~,91 E , .'/', 780-86 s.'' ................ .. ..,... _ .,..;, '~. . , ......... : ..... . ' -. i'i 14,49 17.93 22.50 28,15 35,03 47,77 50.16 52,02 5q.82 57,00 60'32 63,22 62,96 6~.08 61,55 FT, · ,' - .~'..:,;-'. 'SPERRY-SUN'.WEL'L~-"~-SURVE¥ING CO.~,PANY .... ·' "-.i -':ANcHOR'AiGE:.'~ &L.~SKA'-' /i.:i']'--'- X.7 iRlqT1U LU~HU lA I 1UN UA IL PRUDHPE BAY ... HAY 1Se 19.90 ALASKa INTERPOLATED VALSES FEET OF SURVEY HAY lq~ lqSb .JOB NUMBER BOSS-16587 KELLY BUSHIL'G ELEV. OPERATOR-WALKER SUP.-' sE'A:: DEPTH .. ., , = 73,60 FT. TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES FE-TVD VERTICAL DEPTH DEF.'~r Fi" ~:: ,?.:. OEP'Ft.H NgMi-'H/~UU~H r..~'i~i wE:gT :: bt FF.ERgNCE.". CORRgg7 ion 6569 5673'60 5609,00 8q'7"~'5'8-:~,.-S 2061,61 E ~9'5,~7.-.:. . 55,6~ 6722 b'%?3,6U' b/'{]O;'OO ~1e55 6 216be2/ t ~,ZI D2,BO 6R75 5873.60 5800.00 956.69 S 2267.1~ E 1002,32 53,04 7028 5973,60 5900.00 1009,38 S 2369.26 E 105q,65 52,33 7~76 6273.60 ~ 6200.00 11:6_0-:~.-::S'~ . 2~6.22 E 1205'.'1'3 q8.~2 76'23 ....... 6373'60 ..... 63D'O,O'D 12D9"66 S .... 2~6'2,'66 t ....... 125U,~ 47";26 7769 6q73.6'0 6q~D.OO 1.256.25 S 2856.80 E 1295.ql q5.02 7912 6573,60 6500.00 1301.73 S 29~9.~0 E 1339.10 ~3,68 8055; ' 6675,60. 6600'00. 8195' ' 6773,.60 6700.0~ ~q'/2'" 6'~/~,6U 69UU.UU ~607 7073.60 7000.00 8740 7173,60 7100,00 ~8't2..-., /275,.6U' t2DU,Oo 9002 73.73'~'0 7300,00 o129 7~'73'60' 7~00,00 1511,q9 S 33~3,09 E 1533,57 15~+9.06 S 3~63,19 E 1567,09 1620.'~.6.0-$ 361.6.21 E . 1~,28.8~ 1:6,56'91 s.,.......~685. 917:E'::-"'.;-~.-' ~ ......... , , , , , ,,,, ,, , , , ,,,, 39.03 35,15 33,52 3i.76 30.05 27,21 SOHIO ALASKA PETROLEU~ X-'F- 7RI4TlO PDUDHOE BAY cO. SPERRY-sU'N'UELL SURVEYING' COF, PANY :ANCHORAGE~ ALASKA INTERPOLATED CO?.F' u ~ A I Iuh! MAY 15, 1980 VALUE.S. iFOR:.-EVEN:.' 100 .FEE T.-OE bATE OF SURVEY M/~Y 14, 1980 UOB NUMBER P, 0SS-16587 KELLY RUSHING ELEV. uPERA i uR-gA LKEN suB'SEA` DEPTH = 73,60 FT, MEASURED DEPTH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES ME-TVD VERTI DEPTH 'NCRT.H/SOUTH EAST/WEST" -uI~-.E~LNCE · CDRR~C ~252 ,:7573"60 ,-: "7'500, O0 ~572 ..... 767"3'~ 60 .... ?6OO.OU 9A90 7775.60 7700,00 c~G08 7873,60 7890.00 9725 ' -'797'3, ~ 0 7900,00 ... 984~ 8073.,60 . .. 8000,00 ~962 8,173.60 8100.00 10082 H275,60 1~'200m O0 10205 8373.60 8300.00 103~0 8~+73.60 8400.00 · 8575.,GD - /8500 8673,60' "-."8600 · 0 O 10591 ) 0714 -- I OSJl 1 0946 11061 11176 ~ 1290 11405 1777. 1.816.91 185.6 '19 I'8'96,25 .19'39,28 '198'6~'66" 20~7.5A 2093. ~2 S 222:0:' 1 5 S 228'0-- 66 2555'97' S' 2585.89 S 2.A~6,5~ S S 38q6,90 E 1717, S 3894.76 E 1735,1~ $ i' . ,'., "" S A13~. lO E 18~1,7q ~18q.86 E 1857,2R ~ 292",;GG".E']':-.'~':' ~-. 19'i'7' 72 ~356,52' E ' q585,0q E 1 972,86 qqlO.07 E 1988.06 ~8.1.,2~. S · ~455,0~. ~: .,.~ 200..2 . 2537.9~: S A~5~,51 .:E ..~. 2016,68 259z.o9':s o E"" ' .; 203Z. 97 , ,. ,, ,,,- 8773,60 8700, 8973.60 8900, 9073.60 9000. 9175.60' ' . 9273., 60 g2DO. 9373_.60 9300. DO O0 rio 0{3 00 O0 CAL TION 22,56 1¥,95 18,7~ 17.82 17.13 17,39 18,9~ 20.57 22.56 25,55 2v,2~ 31,18 23,03 i 6'"' 7 Ii 15.qO 15.20 14.lA 15,29 S~HIO ALASKA PETROLEbF -- -X~7--' ?Ri-ZFTiL) PRUOHOE SPERRY"SUN WE:LL SURVEYING · ANCHORAGE,~ ALASKA bATE OF SURVEY MAY lQ, ~AY 15, 19~0 NOB NU~ER POSS-16587 KELLY BUSHING ELEV. = . ~ . ~..: OPER~TOR~WALKER P~r~E 11 1980 "/3 · G 0 FT. TRUE SUB-SEA MEASURED VERTICAL VERTICAL :DEP T H: DEPTF! DEPTH .'. :i': ! 1522 9/-+73.60 "gqO0* O'O '~'i'~'~ i' ...... ~5 ~ J' ~ o~'~' '~s'o'o~ ~ 11691 ~615.63 95Ae.os TOTAL R.E CTANGUL/~R COORDINATES PE-TVD N'C~TH/SOUIH EArl/WE;Ell .: f]II':IFEi</NiJL 26q7 77 :S.::':~:~:~' '~98.5~ E ~0~9.11 27~2.1. S q530.71 E 2075.37 VERTICAL 17'lq ' 'i'~'. ~ ~ 7.82 THE CALCULATION PROCEDURES IJSE TILE' NEAREST 20 FOOT· ~D (FROM . LINE/~'R'IN'TERPOLATION' RETWE'EN RADIUS OF' CURVATURE) P.OINTS ............ ~ ._ ~__ HORIZONTAL :.-TVI EW ........ I -- SOHIO ALASKA!-PETROLEUM ...... i ...... i ..... WELL, X-7 ' '! ........ ~ ............. i ......... RADIUS OF CURVATURE ............. ~ ..................... t ...... ~YROSCOPIC SURVEY .............. , ~ MAY-~I'~1980~ ._ ........................................... t ~ ' .... ...................... : Controlled Drilling Consultants P.O. BOX 1189 PALMER. ALASKA 99645 PHONE 376-5423 ~.~r. Brtan R~se Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, AK 99502 1980 Magnetic Single-Shot Survey Job No. A0480-016 We~ X-? ( 42-0 8-10-14) Prudhoe Bay ~%eld North Slope, Alaska Date of Survey, 4/16/80 to 5/3/80 Dear Mr. Roses Please find enclosed the "Original" ar~ six (6) copies of,our Magnetic Single-Shot Survey on the above well. The method used in calculating the survey was radius .of curvature. The depth interval of the survey was 269~ to 11691. Thank you for giving us this opportunity to be of service. Yours very truly, Controlled DrLlling Consultants Directional Supervisor RECE VV , COMPLETION REPORT SOHIO ALASKA PETROLEUM MAGNETIC SINGLE SHOT SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR CDC BY FM LINDSEY & A$SOC 06 MAY 80 WELL X'7 K B ELEV 73.60 RECORD OF SURVEY ALL CALCULATIONs PERFORMED:BY I B M ELEcTRONIc COMPUTER TRUE · MEAs, DRIFT VERTICAL SUB : TOTAL DEPTH ANGLE DEPTH SEA DIREC D M DEG, 0 0 0 0.00 -73,60 N O-OOE 0,00 '5 0,00 W ASSUMED VERTICAL TO 2694 2694 0 0 2694.00 2620.40 N O.OOE 2814 2 45 2813.95 2740.35 S77.00E 2910 5 0 2909,72 283 3.032 6 0 3031,16 .OOE 3125 8 0 31.23.46 O'OE 3249 10 45 3245.79 3172.19 579.00E 3340 12 45 3334.88 3261.28 S78.00E 3430 15 30 3422.15 3348.55 578,00E 3523 17 15 3511.38 3437'78 57.8'00E 3647 20 15 3628,78 3555,.18 $75,00E 380'0 24 30 3770.23 3696,63 S78,00E 3923 27 30 3880.77 3807,17 S74.00E 4077 30 45 4015.28 3941.68 $74.00E 4229 35 0 4142.91 4069.31 $75.00E 4414 40 30 4289e13 4215.53 S74,00E 4566 45 0 4400e72 4327e12 $72.00E 5036 48 30 4722.71 4649,11 $72,00E 5524 51 0 5037e99 4964e39 S71.OOE 6047 51 45 5364.45 5290.85 S70.OOE 0.00 S 0.00 W 1.56 N 1.96 E 0,06 S 8,24 E 3,48 5 19,42 E 6.'88 S 310,23 E 11,77 5 49.82 E 15,46 S 67.97 E 20,03 $ 89.45 E 25'48 S 115.10 E 34.78 S I53,85 E 48e37 S 210,46 E 61e41 S 262.76 E 82.07 S 334e80 E 104.12 S 414.29 E 134e37 S 523,39 E 164,53 S 622.03 E 270,30 S 947.56 E 388.47 S 1300.73 E 524.86 S 1685.88 E 48,23S 2024,85 E 74,22 S 2361.81 E CLOSURES DISTANCE ANGLE D M 0.00 S 0 0 0 W 0,00 S 0 0 0 W 2.50 N 51 30 0 E 8,24 S 89 33 30 E 19,73 S 79 50 11 E 31,00 S 77 9 40 E 51.19 S 76 42 12 E 69e71 S 77 10 51 E 91e67 S 77 22 37 E 117,89 S 77 30 56 E 157.73 S 77 15 32 E 215,95 S 77 3 15 E 269.85 S 76 50 37 £ 344.72 S 76 13 32 E 427.17 S ?5 53 33 E 540.36 S 75 36 3 E 643.42 S ?5 11 2 E 985,36 S 74 4 42 E 1357.51 S 73 22 16 E 1765.70 S 72 42 25 E 2126,08 S 72 14 52 E 2485.48 S 71 51 1 E DOG LEG SEVERITY DEG/IOOFT 0,000 0.000 2.300 0.820 2.151 2.224 2.198 3.056 1.882 2,437 2,798 2.536 2ellO 2.804 2.982 3.033 0.745 0.527 0.186 0.37~ 0.289 SECTION DISTANCE 0.00 0,00 1,08 19.00 30,22 49,98 8~7 114,74 153.68 210.58 263,35 337,21 ~18,38 529,79 631,73 970,88 1746e48 210~,38 2463.62 SOHIO PAD X WELL X-7 SINGLE SHOT SURVEY RECORD Of SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER 06 MAY 80 TRUE :~ MEAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES DEPTH ANGLE DEPTH SEA DIREC D M DEG, CLOSURES DISTANCE ANGLE D M 729-8 ~ 6:~73,73: 6:L00:,i3 8 5:7'80 --:'. $ i: 8360 43 45 6913.01 6839~ S70,OOE 11'27~29:5 3292.39 E 8862 41 0 7283.83 72~0.23 $70.OOE ~243,00 S 36[0.~9 E 9031 39 45 7412,57 7338,97 S7~,OOE 1279,54 S 3713,48 E 8 =9'81 E o55.o 's 7o E 10500 40 ~5 86Z7069 8544,09 545,00E Z757,55 5 ~395,54 E ¢733.90 5 68' ~2 2~ E Z1184 29 0 9179,64 9106,0~ 529,00E 2066,44 5 ~628,31 E 5068,67 5 65 56 24 E 11631 32 15 956~,24 9~90!64~ 5~9_,90E_ 2265~57 S 4738069 E 5252,~3 S 64 26 50 E , ~'- _ . D.'EXTENDED TO 11691 MD - .. .BOTTOH HOLE CLOSURE 5278,5~ FEET AT S 6~ 14 45 E 27180-43 $ 71 36 21 E 3036,91 ,5 71 ],9 57 E 3480'03 5 71 5 56 E 3818.28 ,5 7,1, 0 6 E 3927,75 5 70 59 15 E DOG LEG SEVERITY DEG/IOOFT 002~0 00~02 0,~06 0,548 00778 20830 00889 0,682 1,539 1,73~ 0,727 0,000 SECTION DISTANCE 2696,., 3013,71 3~55.Z6 3791.76 3900.59 ~028041 ~32,07 ~722,60 5252~39 5278,5~ SOHIO PAD X WELL X-7 SINGLE SHOT SURVEY MEASURED DEPTH AND OTHER DATA :FOR EVERY EVEN 100 FEET OF sUB SEA DEPTH. 06 MAY 80 MEASURED DEPTH 174 174, 274 274. 374' 474 574 674 774 874 974 :1074 1174 i'3 TRUE VERTICAL SUB ;: MD'TVD DEPTH SEA :DIFFERENCE 1374 1474 1674 1774 1874 1974 2074 2174 2274 2374 2474 2574 2674 2774 2874 2974 3075 3176 3277 ' 3380 3483 3588 100 0 200 0 674. 600 0 774. 700 0 874, 800 0 1074. ::: 1200 VERTIcAL : CORR EC T ION: :: 0 0 0 1374, 1300 1474. 1400 1574' ::i: 1674. I 17:74. 1 1874, 1-800 1974. 1900 2074. 2000 2174, 210.0 2274. 2200 2374. 2300 2474. 2400 2574, 2500 2674e 2600 2774e 2700 2874. 2800 2974. 2900 3074e 3000 3174e 3100 3274. 3200 3374. 3300 3474. 3400 3574e 3500 2 3 6 9 14 0 0 0 0 0 0 o o 0 0 0 0 0 0 0 0 0 0 o o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 5 TOTAL COORDINATES 0.00 $ 0.00 S 0,00 S' O.OO S 0.00 S 0,00 5 0.00 $ 0.00 $ 0,00 5 0.00 S 0.00 S 0.00 $ 0,00 S 0.00 S 0,00 0,00 S 0.00 S 0.00 $ 0.00 S 0.00 S 0.00 0.00 S 0.00 0.00 $ O.OO S 0.00 S 0.98 N 0e69 N 1.73 S 4.94 S 8.94 12e81 $ 17.37 S 23.07 S 29.94 S 0.00 W 0,00 W 0.00 W 0.00 W 0.00 W 0.00 W 0,00 W 0.00 W 0.00 W 0.00 W OJO0 W 0.00 W 0.00 W 0.00 W 0,00 W 0.00 W 0.00 W 0.00 W 0,00 W 0.00 W 0.00 W OeO0 W 0,00 W 0*00 W 0,00 W 0.00 W 0e67 E 5.45 E 13.86 E 23e99 E 37.49 E 55.09 E 76.97 E 103.75 E 134.73 E SOHIO PAD X WELL X-? SINGLE SHOT SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 06 MAY 80 TRUE MEASURED VERTICAL SUB MD-T'VD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRE(TION 3695 3804 3915 4029 4146 4267 4394 4528 4670 4815 4962 5113 5266 5422 5581 5741 5901 6061 6222 6380 6536 6691 6845 6997 7148 7298 7446 7593 7738 7882 8025 8166 8305 8444 8580 3674. 3600 21 3774. 3700 30 3874' 3:1800 41' 3974, 3900- 55 4o 74. 00o 4174, 4100 93 4274, 4200 120 4374, 4300 154 9:6 4674, 4774, 4?00 339 4874, 4800 392 4974, 4900 448 5074, 5o0o 5o7 5174, 5100 5'66 5274, 5200 627 5374. 5300 687 5474, 5400 748 5574, 5500 806 5674. 560o 862 5774 · 5700. 917 5874, 5800 97! 5974, 5900 1023 6074, 6000 1074 6174, 6100 1124 6274, 6200 1172 6374, 6300 1219 6474, 6400 t264 6574, 6500 1308 6674, 6600 1351 6774, 6700 1392 6874, 6800 1431 6974, 6900 i4,70 7074, 7000 1506 7 9 11 17 27 34 42 4.5 47 51 53 56 59 59 6O 58 56 55 54 51 5O 48 47 45 44 43 39 39 36 TOTAL COORDINATES 39,08 5 170,44 E 48,70 $ 211,96 g 60,41 5 259,22 E 75,41 $ 311,57 E 91e93 5 369,72 E 109,88 $ ~35,63 E 130,83 $ 510,98 E 156,45 5 596,71 E 187,3.6 S 692,29 E 219,72 $ 791,88 E 253,32 S 895,31 E 288,28 $ 1002,62 E 324,81 S 1112,96 5 362,99 $ 1226,21 E 402,94 $ 1342,63 5 485,97 $ 1578,20 E 528,62 $ i696,21 E 571,65 $ 1814,45 E 613,58 $ 1929,65 5 654,53 $ 2042,11 E 695,43 $ 2153,22 5 736,26 S 2262,19 E 777,12 $ 2369,38 E 817,69 $ 2475,06 5 857,74 $ 2579,40 5 897,13 S 2682,02 E 935,71 $ 2782,51 E 973,33 $ 2880,52 E 1010e33 $ 2977,51 E 1046,06 S 3072,32 E 1080e71 S 3165e40 ~ 1114,32 S 3256,81 ~ 1146e97 S 3346e45 E 1178,78 $ 3433.85 E SOHIO PAO X WELL X'7 SINGLE SHOT SURVEy MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET ~OF SUB SEA DEPTH. O6 MAY 8O MEASURED DEPTH 8715 8848 898O 9109 9234 9355 9475 9594 9711 9829 9948 10068 10190 10315 10443 10573 10700 10823 10944 11061 11177 11292 11408 11524 11642 TRUE VERT!CAL SUB MD'TVD VERTICAL ! DEPTH SEA DIFFERENCE CORRECTION 7174. 7274. 737~. 7574. 7674, 7774. 7874. 7974, 8074. 8174. 8274. 8374. 8574. 8674, 8774, 8874. 9074, 9274, 9374, 9574, 7200 1574 7300 1606 32 7400 1635 29 7500 1660 25 7600 1681 21 7700 1701 20 7800 1720 19 7900 1737 17 8000 .1755 18 8100 1-774 19 8200 1794 20 8300 1816 22 8400 1841 25 850.0 1869 28 8600 1.899 30 8700 1926 27 8800 1949 23 8900 1970 21 9000 1987 17 9100 2003 16 2oo 2o 8 93002034 16 ~ . 9400 2050 16 9500 2068 18 TOTAL COORDINATES 1209.76 S 3518.98 1239.85 ~ 3601.65 1268,84 S 3682,65 1297,17 5 3759.40 1330,21 5 3825,80 1365.29 5 3885.12 1400.37 S 3941'41 1470,30 S 4045.13 1506,41 $ 4095.70 158~,26 5 4199,79 1628.66 S ~254,35 1677,82 $ 4310,84 1732,01 $ 4369.24 179Q,SQ & ~427.88 ~849.07 S 4480,23 1905.67 S 4525,92 1960,40 & 4565,35 20i3,04 $ 4598,84 2063,45 $ 4626,78 2112.74 S 4653.97 2163.66 $ 4682.20 22~6,32 $ 4711,39 2270,71 S 4741,53 SOHIO PAD X WELL X-7 sINGLE sHOT SURVEY : .. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, MEASURED DEPTH 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 t i 000 TRUE VERTICAL :' SUB ' DEP TH , $1EA TOTAL CooRDINATES : 1000, 926, 0,00 S 0,00 2000, 1926, 0,00 S 0,00 2999, 2925, 2,48 $ 16,30 5975, 5902, 777,99 S 2B71,64 6656, 6582, 1039,87 S ~055,85 82i7' :~: ~::i:~a ~ :~ l~l. ~i:7~0':o~ 9 0:2i ~ 9 ~ 5::8i · 06 MAY 80 SOHIO ALASKA PETROLEUM ~/ELL X-7 · RADIUS OF CURVATURE MAGNETIC SINGLE- SHOT SCALE !"=1000' MAY 5~ 1980 ~HORIZONTAL ,,'VIEW ........................... 360O i .......................... i ..... ALL DEPTHS SHOWN I.... ' ARE TVD _ ! ..................... TVD= 9,615' : i' , TMD=II~691~ ' - Check Form for timely compliance with our regulations. Operator, Wel 1 Name and Number Reports and Materials to be received by: Date Completion Report Well History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data Required Yes Yes Yes Date Received Remarks SOHIO ALASKA PETROLEUM COMPANY May 8, 1980 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton 3111 "C" STRE~ TELEPHONE (907) ANCHORAGE, ALASK ~.~t STAT ~J STATTEC i , CONFER: EILF: ...... Gentlemen: Well X-7 (42-08-10-14) Enclosed, in duplicate, is Form l0-404, Monthly Report of Drilling and Workover Operations', for the above-namedwell for the month of April, 1980. AMR: ja Enclosures cc: Well File #17 Yours very truly, Austin Reid Acting District Drilling Engineer Form No. 10-404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20441 6. LEASE DESIGNATION AND SERIAL NO. ADL 28313 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Sohio Alaska Petroleum ~y Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6-612, Anchorage, Alaska 99502 X-7 (42-08-10-14) 4. LOCATION OF WELL At surface: 408' SNL, 156' WEL, Sec. 7, T10N, R14E, UPM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec, 8, T10N, R14E, UPM 12. PERMIT NO. 80-13 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. April, 1980 Spud well at 2100 hours, 4/14/80. Drilled 17 1/2" hole to 2700'. Ran 68 jts. 13 3/8" 72# L-80 Buttress casing to 2695'. Cemented with 3720 cu. ft. Permafrost cement. Installed and tested BOPE. Cleaned out to 2653', tested casing to 3000 .,.osi, okay. Drilled out to 2726', ran leak-off test to 0.66. psi/ft, gradient. Directionally drilled 12 1/4" hole to 10575'. Ran 269 jts. 9 5/8" 47# L-80 Buttress casing to 10568'. Cemented in tw~ stages: First stage with 1552 cu. ft. Class G c~ent; second stage.through D.V. packer at 2616'with 130 cu. ft. Permafrost cement preceded by Arctic Pack, Cleaned out to 10525', tested casing to 3000 psi, okay. Drilled out to 10598', ran formation conpetency test to 0.69 psi/ft, gradient. Directionally drilled 8 1/2" hole to 10610'. 14. I hereby certify that the f~goin~rtrue a~l ~ect Acting SIGNED /A1]g~-_~T~~ ~'~'~'~La~ TITLE D~ .~.~'%,~.~_ Dr5 ] 1 ina~ Erl(Jirl~6aJlfATE 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Alaska Oil'and Gas Conservation Commission Hoyle H. Hamilton_~~ Chairman of the Comm~ion Lonnie C. Smith/J~~ Commissioner April 18, 1980 Petroleum Inspector Witness BOPE test on SOHIO's X-7 Sec. 7, T/ON, R14E, UM Permit % 80-13 w~,~day. A~,ril 16. ~980 After ¢~mpleting the BOPE test on SOHIO's E-8, I traveled to SOHIO's X-7 and witnessed the BOPE test. The test began at 11~00 PM and was completed at 2~00 AM. The results of this test are attached to this re~ort. In summary, I witnessed the BOPE test on $OHIO's X-7. Attachi I was contacted on 4-19-80 by Mr. Jack Barr informing me that the repairs had been made on the BOPE stack. Wel 1. Sign ig ACCU[,]U LA2OR S ¥ST t'2,! 65~''/ Ful 1 Charge 'Pres:~u.uo~. ~ ~)~ Pressure After Closure_~O~ ........ ~sig 200 psig A~ve Prechargc Ab~aimnd-- min~..s Full O!argc Pressure Attain~: ~ mJ_~ s Con~ols: Master ........ ~ r ....... :- ~iz ...... ~ ..... :~-- ~ ::'Tr-, ........................................................... : -- icsu [res~re ~,~].ii, ~,,d L ~..,(.L o,-.~ BOPE S tack Allllul a L- Prever ~, t{'2r Pi[~ Rams Blind Rams __'/ 0~7~00 Choke Line Valves / .0~o00 H. c. ~. v~lv~ ...........~_ ........ ._~.e_e_e ....... .... Kill Line Valves / _sS'oeo Ball ~Dl~;e / Tesk Prcr.~::u~:e_~o~ ................. Inside E/OF / Test PL-O:~SUCC' Choke Manifold~ I No. Valves /{ i t-,}~.arm.~.i.cally co~a~., ~ .... ~ ,.. ............................ .............................. ilLz .................. ~'_ ........ , ........~ ..................=-= .... -. Test Rr, q~lts' Failures ~ . Test T.J~:e ~ nfs. Repair or Replac~nent of failed ~uipnen~. to ~x0 made witi~in,~ ~]ays Insi~2ctor/Canmission office nohificd. orig. - noa~c-~ ~ ~n r ~','. ,. r - - --~~ ..... cc - Field O}~ra~or/Ju[ ..... January 30, 1980 Re: Prudhoe Bay Unit X-7 Sohio Alaska Petroleum Company Permit No. 80-13 Sur. Loc.: 409'SNL, 156'WEL, Sec. 7, T10N, R14E, UPM. Bottomhole Loc.: 2560'SNL, 750'WEL, Sec. 8, T10N, R14E, UPM. Mr. P. R. Judd District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Dear Mr. Judd: Enclosed is the approved application for permit to drill the above referenced well. Well samples, core chips and a mud log are not required.. A directional survey is required, if available, a tape contain- ing the digitized log information on all logs shall be sub- mitred 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 16.50.8-70 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted 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. P. R. Judd Prudhoe Bay Unit X-7 -2- January 30, 1980 co~mencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate, your notifying this office within 48 hours after the well is spudded.. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Hoyle H, Hamtl ton Chairman of BY ORgER ~F FHE COMMISSION Alaska Oil & Gas Conservation Commission Enclosure cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/enc1. Department of Labor ~ Supervisor, Labor Law Compliance Division w/o encl. SOHIO ALASKA PETROLEUM COMPANY January 17, 1980 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Cc~m%ission 3001 Porcupine Drive ~nchorage, Alaska 99501 Attention: Mr. H. H. Hamilton Gentlemen: Well X-7 (42-08-10-14) Enclosed are the following documents, in triplicate, along with our Check for $100.00 to cover the permit filing fee. 1. Application for Permit to Drill, 2. Proposed Drilling program Outline, 3. Surveyor's .plat showing well location. PPJ: ja Enclosures Cc: Well File #17 Yours very truly, SOHIO ALASKA PETROLEUM CCMP~ District Drilling Engineer Form 10403. REV. 1-Z-7! la. TYPE OF WORK STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL l~ DEEPEN F-'! b. TYPE OF WELL OIL GAS WELL [~ OTHER WELL O 2. NAME OF OPERATOR Sohio Alaska ?etroleum ~y SINGLE~----~ ZONE ( SUBMIT IN TRI.I~ £E (Other instructioi~ on reverse side) 3.ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 99502 4. LOCATION OF WELL At surface 409' SNL, 156' WEL, Sec. 7, T10N, R14E, UPM At proposed prod. zone 2560' SNL, 750' WEL, Sec. 8, T10N, R14E, UPM 13.' DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 10 miles NW of Deadhorse MULTIPLE API #50-029-20441 6. LEASE DESIGNATION AND SERIAL NO. ADL 28313 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME 9. WELL NO. X-7 (42-08-10-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay,Prudhoe Oil Poo 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 8, T10N, R14E, UPM 12. 14. BOND INFORMATION: mE Blanket S=etyand/orNo. American Insurance Co. 3348616 mount $100,000.00 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, it'any) 750' west of ADL 28312 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2596 ' NW of Well D.S. 14-( 21. ELEVATIONS (Show whether DF, RT, CR, etc.) est. KBE = 75' AMSL 16. No. OF ACRES IN LEASE 2501 19. PROPOSED DEPTH 11833 'MD 9521'TVD !7. NO.ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS 22. APPROX. DATE WORK WILL START March 20, 1980 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE ~ SETTING DEPThTV~ Qua'ntity of cement 36" 30"x20" £nsulated. Con~uctor 110' 110' 12 cu.yds. Arcticset concrete 174" 13 3'/8" 72# L-80 2670' 2670' 3860 cu. ft. Permafrost II 12g" 9 5/8" 47# $oo-95 [0593' .8646' 1528 cu. ft. Class G;130 cu. ft. ~'i 8~" 7" 29# L-80 ]]833' 9521' 325 cu.ft. Class G _ See attached proposed drilling program outline. RECEIVED Alsska Oil & G~,}s i,uns, UU,~isSi0n An0horag~ IN 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 subiufface locations and measured and true vertical d?,,i~s. Give blowout preventer program. 24. I h~reb¥ c.rtif¥ that the F~¢nd Cot% ~,"- ; . / District Cl'his space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] ~s .l~. No DIRV_CrIONAL SURWY REQUIRED, J~,YF.,S ~ NO MUD LOG [] YES '~LNO CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE PERMIT NO. ~" O "/'~ APPROVAL DATE APPOVED BY ~ -~ ~ ~ *See Instruction On Re~,.~ DATE 01/.30/80 PNDPOSED DR~TI.~ AND ~LETION PROGRAM Dry bucket 36" hole to 80' below ground level and cement 30" x 20" insulated conductor to surface using Arcticset concrete. Drill 17 1/2" hole to 2700' and cement 13 3/8" 729 L-80 Buttress casing to surface using 3860 cu. ft. Permafrost II cement. Blowout Preventer Program consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer frc~ 13 3/8" casing point to T.D. Directionally drill 12 1/4" hole to 8646'+ TVD. Run 9 5/8" 47~ L-80 Buttress casing to 8646' TVD and cement first stage with 1528 cu. ft. cement. Cement second stage through D.V. packer collar at 26'00'+ with 130 cu, ft. Permafrost C cement. 9 5/8" casing will be hung at surface, ~he9 5/8" x 13 3/8" annulus will be Arctic Packed. Directionally drill 8 1/2" hole to T.D. at 9521'+ TVD. Cement 7" lin. er to 500' inside 9 5/8" casing shoe with 325 cu. ft. Cl--ass G cement wi.th 18% salt. Run 4 1/2" 12.759 L-80 tubing with a production packer assembly, at 8258'+~ TVD. A subsurface safety valve with dual control lines' will be Placed at 2000T+_, Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release.' Details of proposed perforations to be submitted on Sundry Notice to follow.. ......... I Ill , : : - - ............... ~! ' - -- t {Proposed) ,' x-5 ...... 6 . . .fo -'~- .... z4eo' · 031~ (Propo~ed) :3 . X- ~ I [$/. 5 -/o./4) t. Gl r,o ,ct. ' ---- EAST COND, LAT. = 70°t4':~1.13'' LONG.--I48e39~ I9.22" X= 666,488 Y = 5~9 ~9~ 890 (Proposed) PORTION OF T ION, R 14 E, UM SCALE I ":.t/£ MiLE · CONDUCTOR HOLES PAD DETAIL SCALE 1":300' CERTIFICATE OF SURVEYOR (42 - 8 - lo- SUMP i hereby certify that i am properly registered to practice land surveying in the State of Alaska and that this plat represents a location survey of the welipad shown and the wells thereon. This survey was made by me or under my supervision and all dimensions and other details are correct. Bottom !~1 locations are furnished by others ~-~..~ ~. ?,. ~ ~ ,,~¢ :~, /¢7? Date Su r Ye Y°~J~ska Note: All bottom holes are BSO0' sub sea, Revised BHL(X-2) from 2450' to 2490' EWL. Added proposed bottom hole loc. X-7 PJR 9/1Z/1979 C.J.R. 1/14/80 AS- STAKED PAD "X" Located in PROTRACTED SECTtONS Surveyed for SOHIO PETROLEUM CO. C.J.R Surveyed bY F.M. LINDSEY & ASSOC. LAND S HYDROGRAPHIC SURVEYORS 2.502 West Northern Lights gAoulevorct Box Anchorage Atdska CHECK LIST FOR R~EW ~'~LL PERMITS Yes No _. Is the penait fee attached .......................................... ~ / ~. Is ~ell to ke located in a defined pool ~/~ 3. Is a registered survey plat attached ................................ ~ 3. Is ~11 located proper distance frcm property line .................. ~ 5. Is well located proper distance frcm other wells .................... /~//~ 6. Is sufficient undedicated acreage available in this pool ............ ~ 7. Is well to be deviated .............................................. ~. / 8. Is operator the only affected party ................................. ~ 9. Can permit be approved before ten-day wait .......................... ~_ 0. Does operator have a bond in force .................................. 1. Is a conservation order needed ...................................... .2. Is administrative approval needed ................................... .3. Is conductor, string provided ........................................ ~ .4. Is enough cement used to circulate on conductor and surface ......... ~ 5. Will cement tie in surface and intermediate or production strings ... ~ .6. Will cement cover all known productive horizons ..................... ~,. .7. Will surface casing protect fresh water zones ....................... ~ Lease & Well No. Item Approve (1) Fee ~_ (2) Loc. (4) Casg. ~ ~_8. Will all casing give adequate safety in collapse, tension and burst.. ~9. Does BOPE have sufficient pressure rating - Test to ~OO psig .. Approval Reccmmended: (5) BOPE ~ ~dditional Requirements: Engineering: LCS ~ rev: 12/12/79 Well History File APPENDIX Information of detailed nature that is not padiculady 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. ********************** Alaska Oil & Gas ~ns. ~ummission Anchorage L'qP OIO,HO~ VERIFIC~.TION LISTING PAGE C~: : St)HIO .~[,~SKA P.ETRObEU. M CO~P,ANY _ 000 RA. NG: I 4E: 000 T~ I0~ -:.':: - S~CT: 7 000 ,~ SLmPE · 000 ST.~.T: ~L.aGK Z~ o00 - : c~ usa ooo 000 030 065 000 003 O65 000 012 065 000 004 065 000 004 065 000 002 065 000 008 065 000 006 O65 000 004 065 PAGE ****************************************************************************** , STATF = hLaSKA RUN ~, DATE-L[)GGED~ I2 MA~.~ 83 '[,~P: OI~ KOhRI~JG C~SI~'~ = 9.6~5" ~FACE TO !056~' ~-_ . 'CUBI~<,G = ~.500" Si!'~PACE TO lOl!O' TY~ E FLUIC~ =':~:F~R~JT :: ~J. :/ :~":: ':" ' ~ --: : ' ~ Fbi!ID Lf~VF[., = FI]!.-L _ '~ . ~ . : ~-- - _ ~I:-1 ils-. 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FTDT 527~52 a I(1~4 'O0q;2500 FSIC -. ~.. _ - i. 4 0 4-: 0 ~ 0 4 0 TRAT NTDT TRAT TRAT NTDT TRAT NTDT TROT NTDT 4,1055 TRAT .45,3438 NTDT -990.2500 TRAT PAGE 1 68 1 68 I 68 I 68 1 68 I 68 I 68 1 68 I 68 1 68 I 68 1 68. 1 68 ! 68 I 68 1 68 I 68 I 68 1 68 1 6S 1 68 1 6~ 1 68 I 68 1 6L~ I 68 1 68 ~999,2500 '999,2500 '999.2500 -999 2500 -999 2500 '999 2500 '99~ 2500 -99 ~500 -999 500 -999 2500 2~805 8; 922 -9 9,2500 WTD~ -O~O.PS00 SIG~ .009,25C)0 ~SIC -999,2500 TRAT ~- ~:-~:~: ,::::':F::~:~:~' - -::'-'~99~:~ : NTDT '999'~500 FTDT -~99. 2500 . D~:PT 11500 0000 S'IG~ i9,0625 FSIG 16,8437 TRAT 2 ,9785 GR 23 '8~8{.. ~{~CK.:~: AC~ ~ /~ ~3:i5Q~0 NTDT .7500 ~0~) 8I~t~ ~'g,'0755 'FSIG 17,2!87 TRAT ::/::~ :~ ?:;. :~--- :56~)~'J - NT:DT ~57 3438 FTDT ! *.30 FTDT ! 60 20,1562 FSIG 16,9531 T..AT ':!::: C: ':-' ~59~8 - NTDT !918~40 FSIG 17,6016 TRAT ':' "'"~'' '0 B~ 58 i328 NTT 15~ 0348 2 9805 180 2500 3 0901 173 5498 813 4 4414 109!9375 6406 TRAT 3 9922 6563i~ -NTDT 97.9375 2842 TRAT 4,2568 .5~5~ NTDT 122. 3066 6875 TRAT 4 476~ ~00'0_ NTD~ 102:5625 9531 TROT 4,1641 ~6250' ,TDT 94,0625 DEPT ~.1300 0000 SIC.~ 18, 5000 FS!G 16,06~5 TRAT 5000 S~G~'~ 1.8, 1250 FSIO !6,0!56 T~AT 2500 $IG?~ ! 8 6~50 S!G~ !7 6563 FSIC, 16,9844 TRAT 8997 FS;lrG 16,0774 TROT 5938 FSlC ~6,4531 TRAT 0000 8TG~ 18,0781 F8IC, 15,4065 TRAT 000o StC~~ 17,50~0 FSIr; 16,~344 TRAT 3-04~:: ~K::: :. .;..~AC' - :.56~6250. NTDT 5625 SIG~ 17,4297 FSIG 15,3027 ~AT -t914. BACK:. ::-~:":~:'.:I::~4:.~:7~:3'~:':: - C :'..60~5547-' ?TDT ~7 ~'I~i 18,3501 FSTG 15,699~ FRAT TRAT FTDT 1 ~5 F T D ~r 140 59 FTD~ 147 O~]PT t l.~00 F~DT 124 FTDT ! 33 FTDT 125 3 0391 161 5000 2,~395 166 5OO 3 0332 160 0000 ~,979B 150,6172 3,009~ 160,5000 3 0566 149 2500 3 037! 137 3750 3 0659 142 0000 9855 56~5 143,0946 FTDT I 15 FT DT 13 5 P !? o,r 13 o MTDT PAGE 161.0625 2 t34 124 2 3750 8I~4 15,,7090 FSIG !4,0!.37 TRAT 2 :;62 :::i;.;i.~iiii~ _ - .:.._ ~ qqTDT 115. ~750 SIGM 16,7266 ~SIG 14,~359 TROT 2 ~3:;:'?':~g~i ~8'~~ :~:/-. ~ :::- ~5:-NTDT 126 7324 8750 000 6563 0000 72~! ~250 8574 4219 OEPT 1!000 0000 $IGi~ . 17 234.4 .~'8IG 14,6!06 '. MAT FTOT 123 5625 SIC~ 1.7 9375 F~IG 14,593.8 TRAT ~ ' '35 8359',.: .~B -~: ~. :.,:' :': 567;9687 NTDT FTDT 155 FTDT 139 FTDT 126 4844 81G~ 16 ,2266 SIG~ !,7 ]80q FSlO 15.53 3 TRAT 4460 PS ! ...:. i5,5~32 TRAT :/.:: C: _ :- 66;~635:: -NTD~ 7051 FSIG 14.8013 TPAT :.:-_ :i~ i:j: 00oO 8 I'~,.~ 16,4a44 1P,q IG 13,5078 TRAT :~:,0' h/ iC.-: ..::-.I04i;1250: t~!:~DT 6250 S [G~,'~ 16~4375 FSI~ 14.3359 TRAT 5000 S IG~,~ 17,~13 FS~C; 13,9453 TRAT 0000 S'[ (;~4 16,9636 FSIG 14,7820 TRAT Oa2~ S]~ ~ 15.6240 F3IC i3.1880 TRAT 2 6035 131 2500 2 6211 169 5000 t5~ 6989 8906 2 7285 125 4531 2 6484 170 5938 ,7227 20 ,8750 2.8359 205.8750 2 7910 20~ 0000 707~ 19] 4063 0220 166 1562 5313 TRAT I406 TRAT 6875 N~DT 156~ TRAT NTDT 8242 TRAT 041,0 24 6250 2 9609 236 1250 3 0391 313 5000 50o 2 9233 286 4063 4,~461 34~, 500 ,8383 P~GE 7 FTDT 2 2. 1 F~ P'r. 2 ~ 2 DE_PT J, 062~ FT[)T 244 FTD? 260 ~'~DT 230 ~T[ T 242 t. 875 19375: :D K';:. -: ;"~ ':'11'7~0000.. ~: F:B:AC ' i00~18~.5 NTDT J.4-3 ] S I G~,!' 38~0938 FSTG '.40,3750 T~T , ._-: 2500 $IGa 38.2a80 FSIG 40,2/85 TROT ~8 914. ':~ ~: :':FB~C;~ -< :: ~i 0G~::158~75 NTDT 7 8125 FSIG 39,0625 TRAT 500.0 F$IG .39'3750 :;8..'~57£)':>: : ' 1106'~156251 NTDT 9062 FSlf; . 40.28!3 TROT 9687 FolG 38,03!3 TRAT ~C: : 115~ 3.~ 2.51 NTDT' 371.6563 4 9248 31715156 5 0430 36915000 4.7347 362.9687 5 1602 398 7500 5 0625 398 2500 5 2148 369 5000 5 0J17 39~ 0000 9~87 374 7500 EOF DATE .83/0 11 11 1111 1111 11 1 11 11 11 It 11 111111 11111,1 77777777'17 0 O0 77 O0 O0 0 ' 0.000 77 O0 0000 00 00 00 7-7 00 00 O0 0000 O0 77 0000 OO 77 0 00 00 77 0000 O0 '77 0 O0 7-7 O0 O0 77 O0 O0 77 O0 O0 77 000000 77 :~000000 77 77 77 77 77 77 77 77 GGGG G G G G GGG G G GGG 666.666 606666 66 60 66 66 ~6666666 ~6666666 ~ 66 66 ~' .~ 66 66 ,,::: ~ 66 66 .... ~ff 666666 H H J 1 44 44 44 44 7777777777 : 77 77 77 77 77 77 1 ! 4444444444 4444444444 I1:44 77 11 44 44 , 77 77 11 44 44 77 ~1tJli 77 111111 44 44 77 BBBO PPPP RRRR U -U - DDDD H: H -1300 EEEEE B B P P R Iq U U D D H H 0 0 E B B- P P R:-R :.O- tJ : D -D H:' H 0 0 E -' ' I - - 0 EEEE BBB ..... PPPP RRRR U ] D D HHHHH O ! ' B P P R U U D D H., lq 00 E B B P [~ P U il D D H H 0 0 E BBBB P-iR R UUUUU DDDD H: H DO0 EEEEE *STAP, T* USER PChl, [10:07,61447] dOB SlqIP 'SEO. J.:t28 0AT~; 3o-l~.AR-el 12:57:37 *STAPT* USE¢. PCAb [!0:07 614471, JOB SHIP SEO. 1]28 DATE BO-MAR--81 12:57:32 NIONIT[.IR SWS }<L10E40 NI3'q ...... 80[ *START* '' ' ' I I I ! I I P P PP PPP P III!II PPPPPPPP II PP PP II PP PP II PP PP II PP PP II PPPPPPPP II PPPPPPPP II PP PP IIIIII PP TTTTTTTTTT TTTTTTTTTT TT TT TT TT TT TT TT TT TT TT 0.00000 0000(~0 O0 O0 00 O0 0 O0 (~ 0 00 O0 O0 0 0 0 0 {Jr] O0 O0 O0 O0 O0 (]!} (][i 0000[]0 0000(]0 12:57:32 /SPACING:I /LIMIT:123 /FORMS:NORMAL SHIP TO PCCC SHIPPING INSTRUCTIONS iSSUED tO-MAR-.81 12:~ CALIFORNIA 9~00~ ~V YV VV YV V¥ VV VV V¥ YV vV VV EEEEEEEEEE RRRRRRRR EEEEEEEEEE ~RRRRRRRR EE EE ~R RR EE RR E ~P ~R EEEEEEE R~RRRRRR EEEEEEEE RRRRRRRR EE RR RR E~ RR RR EE RR RR E RR RR EEEEEEEEE RR RR EEEEEEEEEE IIIIII IIllII II II II II II II II II IIIIII RR RR IIIIII FFFFFFFFFF FFFFFFFFFF FF FF FF FF FT;'F I;~FF. FF FFFFFFF[; FF FF FF FF FF FF YY ¥¥ YY YY YY YY YY YY YY YY Y¥ YY YY YY YY 000000 000000 O0 OO O0 O0 O0 OOOO O0 O000 OO O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 000000 222222 OHO000 222222 O0 O0 22 22 °° O0 O0 0000 22 O0 O0 O0 22 O0 O0 O0 22 0000 O0 22 0000 O0 22 O0 O0 22 O0 O0 22 000000 2222222222 O0000n 2222222222 $STAR~* USER PCAL [10707,61447] dOB SHIP SEO. I]28 DATE lO-MAR-81 MONITOR SWS RL10E40 NOV-80. *STAI~T* . FILE: DS~H:VERIF¥.O02<057>[10707 61447] CREATED: 30-MAR-81 12:56.13 PRINTED: 30-M~R-81 12:5":59 QUEUE SWITCHES: /FILE,FORTi/COPiiES:I /SPACING:I /]JIMIT:I2R /f~:OR~S:NORMAL 12:57:32 LIS VERSION 15.ROI 79101126. . . REEl., H~;ADEP . TAPE HEADE~ LENGTH: 132 BYTES TAPE NAME:~1447 DATE: 'Ell ~0 SEPV1CE ~AME:, El)IT . 7'AFE C[)NflN[]AflON NUMBER: PREVIOUS TAPE ~AME. CQMMENTS: UNIOUE WELL IDENTIFICATION NUMBER IS 50-029-2044~ TAPE COMb~ENTS THE T~G AND GRBIJ CURVES ARE STRAIGHT-LINeD ON T~E TAPE- RUN ONE-LOGGED 1- i R- . RUN ONE'LI3GGED' 1-HAR-8 . 1F'tI~E HEADER LENGTH: 6~ BYTES FILE NAaE, P :' ~ ' ~ : HAXI~,iU~ ,H¥SICAL RECJRD. LENGTH~ 1024 BYTES PREVIOUS FILE NAME: FILE CO~tNENTS : mH!S FIL~ CONTAINS. PASS ONE. C[t~4FANY WELL : ~-7 . RUDHOE BA FIEI~D : RANGE : TOWNSHIP SECT!i)N : 7 COUNTY : NORTH SLOPE CTATE : ENS[T~ : 800. DATA F('I~MAT SPECIFICATION LENGT~,~: 450 BYTES ENTRY BLOCKS: TYPE -SIZE REP COD~ ENTRY 0 1 66 JO DATUS~ SPECIFICATION BLOCKS: NA~E TOOL UNIT API API APl API FILE SIZE SAM REP PROCESS INDICATORS 1 DEPT 2 GR T-~ 3 GRBU ~TMTM 4 SIGN TDTM 5 FSIG TDTM 6 TNSK TDTM 7 TFBK TDTM 9 TFG TDTM I0 ~RAT TDT~ 11 tM!lID TDTM FT 0 0 0 0 - O' 4 1 68 GAPI 51 31 32 O. 0 4 68 GAPI 5~t 32 0 0 4 I CU 51 40 1 0 0 4 ~ 68 CU 5 140 ~ 0 0 4 1 68 CPS 51 39 99 0 0 4 1 68 CPS 51 39 '99 0 0 4 I 68 C/C 0 .0 0 4 ~ 68 0 O' 0 -4 1'68 USED DEFINED UIITPUT ARRAY OUTPUT GR AT 2 OUTPUT GRBU AT 3 OUTPUT SiGM AT 4 OUTPUT ~'SIG AT 5 OUTPUT T~B~ AT ~ OUTPI~T T~B.~ A~[ 7 OUTPUT TNG AT 8 OUTPUT TFG AT 9 OUTF~T TRAT AT 10 OUTPUT TblOD AT 11 DEPTH 1t600.O00 1~500.000 11400.000 .1.306.000 1.1200.000 It100.000 11000.000 10900.000 10800.000 !0700,000 10600.000 In59o.ooo baNENONIC VALUE MNEMONIC 'VAL[IE c - MNEMONIC VALUE GP 43.783 GRBU 200~000 SIGM 19.720 .277 GR 3'9'329 GRBU 2-00.000 SIGN 20.740 ~NBK 26~.200 TFB.K 798.999 TNG 421 289 TRAT '497 TMOD 147;802 ' GR 43.232 GRBU 200.000 ~: SIGN 19.075 GR 33.4751 GRBU' .200°O00 SIGN. 18.190 TNBK 300.350 TFBK 816.270 TNG 401.799 TRAT 2~5~6 TMOD 53.546 GR 30'323 GRBU 190.950 SIGN 17.201 NBk 323..242 TFBK 8.23.780 TNG 377 811 RAT 2,43I TMO-D · 5'6,1943 GR I9.865~ GRBU 199"950 ? SIGN 15.401 TNB[ 33~.875 TFBK 782.228 TNG 361 319 TRAT i0]] '~ TMOD ~ 61,289 : ' ' NBk 354.391 TFBK 757.697 TNG 457.271 RAT ' 2i232 TNOD '70-1330 RAT .904 . TMOD 78;721 : GR ' 62.~597 GRBU 109.800 / $IG~ ~6.651 TNBK 399.9~5 TF..BK 726.909 TNG 901.049 TRAT 4,572 TgOD ~ 77i672' GR -73.705 GRBU- 199.800 : S!GM 36.591 TNBK 413.4.35 T~'BK 735.169 TNG 89.3.553 TRAT 4 i737 TMOD 86~214 GR -999.,250 GRBU -999.~50 SIGN 999.250 TNBK 99 K 6999.250 A l~ T . · ~ : ' . ~ _.. MNEMONIC FSIG TFG F$IG TFG FSIG TFG FSIG TFG FSIG TFG FSIG TFG FSIG TFG FSIG TFG FSIG TFG FSIG TFG FSIG TFG FSIG TFG VALUE t4.717 1.735 17.787 1.735 16.349 1.735 14.956 1.735 14.477 12.200 1.735 14.896 1.719 12.994 1.731 17.023 1.731 ~7.468 1.001 36.195 0.999 -1000.050 -999.250 SOHO'lAtelY OF DATA RECORDS NUMBER OE RECORDS: 88 I~ENGTH OF RECORDS: 1018 BYTES LENGTH QF LAST RECORD:' 886' BY'.~ES F[I,E T~AILER I.,F~NGT}t: b~ BYTES FILE NAME: EDIT .001 MA×IMUH PHYSICA. L RECORD NEXT FILE NAME;: _ LENGTH: 1024 BYTES FILE H~:ADER L~,NGT., 62 BYTE5 FILE NAME: EDIT .002 MAXIN[,iN PHYSICAL RECORD LENGTH: 1.024 BYTES PREVIOUS FILE NAME: FILE COMMENTS THIS FILE ·CONTAINS PASS TWO AND. PASS THREE. .i · · DATA F£)R~AT SPECI['ICATION I, ENGTH: 850 BYTES ~NTR ~ BLOCKS: TYPE SIZE REP CODE ENTRY 0 1 66 0 NAME TOOL INIT API API API API FILE SIZE SAM REP PROCESS I DEPT ' 'I · - 0 0 0 0 0 4 1 68 2 GP.., TDTM ,G, API 51 31 32 0 0 4 I 68 .] GRBU TI)TM GAPI 51 31 32 0 0 4 I 68 4 SIG~ TDT~ CO 51 40 I 0 0 4 1 68 5 FSIG TDTM CU 51 40 2 0 0 4 · 1 68 ~ TNB~ TD~M CPS 51 39 99 0 0 4 1 68 8 TNG TDT~ CPS 51 39 ~9 0 0 4 1 68 9 TFG TDTM CPS 5i ~9 99 0 .0 ' 4 -. 1' 68 12 GR TDT~ GAPI 51 31 32 0 0 4 I 68 13 GRBU TDTM GAPI- 51 3! _32~' 0 0 4 - I 68 14 SIGM TDT~ CU 51 40 1 0 0 4 1 68 15 FSIG TDTM . CU 5I 40 - 2 0 -0~ 4 I 68 C S 51 39 99 0 0 4 1 68 16 T~BK TD~ 17 TFBK TD?'M CPS 51-39 99 . 0 0 4' 1 ~68 20 TRAT TDTSI C/C 51 42 0 0 0 4 1 68 21 TMOD TDT~ 51 4~ 0 0 0 4 i 68 OUTPUT GR OOTPU% GRail SIGM OUT~UT FSIG OUT[:: lit OUTPU~ TFG OUTPU~:r TRAI' AT 5 AT 7 9 0 OUTPUT F"SIG AT 15 OUTPIIT TNBK' OUTPIIT TFB~ AI~ 17 OUTPUT TNG t;T 18 OUTPUT TF'G AT !9 OUTPUT TROT ~ 20 : OUTPUT TMOD AT 21 INDICATORS DEPTH 1!600.000 1!500.000 I 1 lO0. 000 113OO°0O0 11200.O00 I1 100.000 11000.000 10900.000 10@00.000 - 9 'ooo -9 .ooo - 99.ooo TNBK ~999,000 TFB~ ~999,000 ~NG :9~,000 ,,,9 9.ooo 9 .ooo 8IG~ ~999.006 FSIG -999.000 TNBK ~999.000 TNG ' g99~000 TFG -999,000 TRAT ..999,000 GR 36'828 GRBU 199,800 . SIGM 20.620 TNBK 366.900 ~FBK 803,004 TNG 431.784 TRAT 2,379 7MOD 61-9.38 --GR 39.730 ;""" -2~553 TMOD 6?·083' GR 51.238 SIGH 18.700 F$IG 16.394 TNBK 414·916 TNG: 379,310 TFG 1.711 TRAT 2.511 GR 46.4,5 GRBU lqg.800 SIG, 17.861 TNBK 378.284 T~'BK 823.279 TNG ~RAT ' ~'3~ TMOD 67..682 GR -~·234 SiGN 18,355 FSIG 14.9~6 ~NB~ 422.942 TNG 40i'799 - TFG. 1,731 TRAT 2·579 GR 38,479 GRBU 199·800 SlGM 17,591 TNBg 388,416 TFBK 818,022 TNG 40'!.796 TRAT 2;:449 TMOD 67i283 GR 41.181 SIGM 17.486 FSIG 14.118 TNBK 426 TNG 3§7"301 TFG 1.73I -TRAT 2'445 29 GR 34.926 GRBU I99,800 $IGM 15.101 NBE 13 78 !.lO1 TFBK 801,251 TNG 359 ,019 T~OD :71.379 GR 36-~20 SIG~ 15.581 FSIG 12.126 TNBK 442.957 TNG 407~796 TF'G 1.~]l : TRAT 2·049 GR 35.627 : GRBU ' 199.~00 ~ SIG~ 17.561 TNBK ~0,433 TFBK 823,780 TNG 383.808 TRAT "1~708 TaOD 70~879 - GR 46·485 $IGM ,17,276 ~SIG 15,436 TNB~ 428,696 TNG ~9~835 TFG 1'731 / TRAT 1,788 GR 34~276 GRBU 199,800 : 6IG 15,521 TNBK 412,434 TFBK 780·225 TNG 457,271 ~RAT ~*~4 TMOD 80;869 · - GR 3~.179 S!GM 16.0]1 F$IG · 12.620 ~NBK 435.702 TNG 55'7,-721 : TFG 1,731 - 1RAT 2.202 ~ g GR 83-262 GRB. 199.~00 'i SIGM 20.635 TRA.~TNBK 43 ~,699 TFBK 643.304 ~NG 701·649 92 '758 TMOD 84~565 ' GR .469 ~IGN ~0 FI ~G 9 T i~ 450,q63 TNG 668 ' 1.959 . MNEMONIC FSIG TFG GRBU TFBK TMOD FSIG TFG GBBU TFBK TMOD FSIG TFG GRBU TFBK TMOD FSIG TFG GRBU TFBK TMOD FSIG TFG GRBU TFBK TMOD FSIG TFG GRBU TFBK TMOD FSIG GRBU TFBK TMOD FSIG TFG GRBU TFBK TMOD FSIG TFG GRBU TFB~( TMOD -9 -9 -9 -9 -9 AL 99 99 99 99 99 18 1 199 802 70 16 1 199 848 72 i5 823 UE .000 .000 .000 .000 .000 .072 .731 .800 .253 .679 .304 .733 .800 .310 .577 .615 · O0 .780 ·075 13,698 1.731 199.800 82.~.029 78.122 12. 1. 199. 785. 81. 14. 1. 199· 847. 80. 12. 1. 199. 724. 80. 16. 1. 199. 005. 95. 126 731 8O0 732 369 672 731 800 309 619 081 731 80O 906 120 1.10 731 800 832 554 DEPTH 10700.000 ~0600.000 105'90.000 MNEmONiC VALUE .MNeMONiC VALI:iE MNEMONIC VALUE GP 74'906 : GRB. U 199.800 ' S.IGM 36.811 NBK 446.960 TFBK 738.173 . TNG 896,552 RAT :~4'726 ' ~TMOD 8'7~151'2 -~ GR 81.961 IGM ]7.296 ~'SIG 36,839 TNBR 45].465 NG 911,544 : : TFG 1'00I : TRAT 4.635 GR 76'457 GRBU : 199.800 $IG~ 36.516 GR TNBK TRAT SIGM TNG MN EMON FSIG TFG GROU TFBK TMOD F$IG TFG GRBU TFBg TMOD FSIG TFG GRBU TFBK TMOD lC VALUE 37.198 1.001 199.800 708.886 93.257 ]8.681 1.001 199.800 753.166 94.705 -1000.050 -999.250 -999.250 731.665 94.705 SUMMARY OF DATA RECORDS NUMBER OF RECORDS: 169 LEN,~IH (iF RECORDS: 1014 BYTES ~ENGTH OF L~ST RECORD: 426 BYTES FILE TRAILER ENGT}J: 62 BYTES ILE NAME: EDIT .002 .= M~×IMUM HYSIC.AL REC(]RD LENGTH: 1024 BYTES NEXT FIL~ NAME: - ' · ~ ~ _ EDP' FILE HEADER I,ENGT~: , 62 BYTES FILE NAME: EDIT ·.003 MAXIb~UM PHYSICAL R.EC(.]RI) PREVI[}US FILE NAME: FILE COMMENTS THIS FILE CONTAINS PASS LENGTH: 1024 BYTES · ' FOUR ~.~ND_FiVE. DA?A ~'~RMAT SPECI~ICATION : :' LENGTI4: 950 BYTES _: ENTRY BLOCKS: -_ · TYPE S-!ZE. REP CODE ENTRY 0 ' : 1 66 - -0 · ' j - . ~ - ~ · . . ·. · · .' _ · . ~. . _ _ · _ . _ · . · ~ - - · . . . ~ . - -:- .: ~ . - . ~ - _- ~ · . ' . - ] . .- - ' . . - . ~ 1 // DATUM SPECIFICATI(]N BLOCKS: NAME T(J{3L UNIT APl API API API FILE SIZE SAM REP PROCESS FT 0 0 0 0 O- 4 ~ 68 GAPI 51 31 32 0 0 4 I 68 GAPi 51 31 32 ' O' 0 -4 1 68 CPS ~ 9 99 0 CPS ~ i ~9 99 0 CPS 5, 39 99 0 0 4 1 68 CPS 99 0 0 ~4 '68 C/C CtC GAP CU 51 40 ! 0 0 4 ~. 68 CU 5 ! .40 2 ~0: 0 ~ 4 I 68 CP~. 51 39 99 0 0 4 1 68 CPS 51 39 99:0 0 4 i 68 1 42 0 0 0 4 1 68 i 4~ 0 0 '-0 4' i 68 US~R DEFINS;D OUTPUT ARRAY OUTPUT GR AT 2 OUTPUT OUTPUT SIGM AT 4 OUTPUT FSIG AT 5 OUTPU~ TNBK AT 6 OUTPUT TFBK AT 7 OUTPUT TNG AT OUTPUT TFG AI 9 OUTPUT TRAT AT OUTPUT TMO[) AT 11 OUTPUT GR AT 12 OUTPUT GRBU AT 13 OUTPUT SIGM AT 1.4 OUTPUT FSIG AT 15 OUTPUT TNBK AT 16 OUTPUT TF~K AT 17 OUTPUT TNG AT 1.8 OUTPUT T~G AT 19 OUTPUT T~AT AT 20 (.IUTP~.!T ?M(JD AT 21 INDICATORS DEPTH 600. 000 11500.000 11-~00.000 1 i 300. 000 11200.000 11100.000 I I000. 000 10900.000 10800.000 MNEMONIC VALUE MNEMONIC VALUE _ MNEMONIC VALUE GR -999,000 GRBU '999.O00 SIGM -999.000 TNBK ~999.000 TFBK 2999.000 TNG -999.000 TRAT .... 999'000' TMOD ....... 999.000~ --. GR ]0.273 6IGM 51.9,32 F$IG 52.325 TNBK 448.46 1 TNG 565'2]7 ~ TFG 0~577 i TRAT 2.069 GR ]8,429 i GRBU 19.9-8_O0 - fiIGM 20.935 TNBK ]79.284 ~FBK 821.276 TNG 431.784 TRAT 2,516 TMOD 67~283 ! GR 48,837 SIGM 20.860 ~SIG 17.143 TNB~ ]91.669 TNG 406.2:97 TFG ' 1.735 i TRAT 2.484 GR 47"836 : GRBU" 199,8OO $IGM 18.940 TNBK 387.9].62 TFBK 805.757 TNG 421.289 TRAT .529 TMOD 69~48! ~ GR 59.445 IG M 19.795 FSIG 16.229 TNB~ 409.682 NG 440'$186 ' TFG i'-735~~ TRAT 2.610 GR 43,032 GRBU 19-9-800 ~-SI.GM 17.681 ~NBK 39~.920 TFBK 830.288 TNG ]65.817 ~RAT ~462 TMOD 71.778 ~ GR 46.7]5 RAT .4.69 : TMOD · 74,476 54.141 IG 18.280 FSIG 14.492 TNB~ 41~.814 N.G 427-286 TFG- 1.7,5 ~ TRA? ".439 O~ ~6.678 6RBU -' 199.800 :~ $1G~. 15.401 THBK 426.320 TFBK 807.259 TNG 389.805 TRAT ~,0~5 75~24 ~ G~ 41.131 $IGM ~5.236 . FSIG 11.]02 TNBA 432.449 TNG 377.811 TFG' 1~735.' :~ TRAT 1.984 GR 48-887 GRBU i-. 190-800 i :j $IGM ' 17.111 TNBK 425.694 TFBK 81].016 TNG 356.822 TRAT 1.578 TMOD 78.72~ ' L GR 57.89] IGM 17.876 PSIG 15.555 TNBK 441.956 NG . 365.847 TFG~ . ~ 1.467 ~ TRAT 1.830 G~ 79.309 GRBU 199.800 -~ SlGM 15.581 TNBK 4~1,691. .TF~K 748.185 TNG 47? .760 TRAT ~.214 .'T~£.D- ' 82-567~ GR 5~.~90 IGM ~5.476 FS~G 1~.335 TNBK 425.944 NG 491.754 TFG~ I1735 ~ TRAT 2.209 GR TT NBK RAT TNG. 9~.823 GRBU 199.800 ~ SIGM 20.035 F5 [G .4 TNBK 441.956 fRAT 2' 049 MN EMON F$iG TFG GRBU TFBK TMOD FSIG TFG GRBU 'rFBK TMOD FSIG TFG GRBU TFBK TMOD F$IG TFG GRBU TFBK TMOD FSIG TFG GRBU TFBK FSIG TFG GRBU TFBK TMOD FSIG TFG TFBK TMOD FSIG TFG GRBU TFBK TMOD FSIG TFG GRBU TFBK TMOD lC VALUE -999.000 -999.000 200.000 ~03.504 100.450 17.712 1.731 200.000 795.745 67.732 15.855 1.731 200.000 801.001 72.478 15.256 1.7]3 200.000 815.770 72.078 14.178 I. 7,51 200.000 791.739 76.274 12.380 1.731 200.000 801.752 82.617 13.953 1.733 200.000 828.285 94.905 12.395 1.735 200.000 758.949 91.009 16.694 1.733 200.000 640.050 98.501 DEPTH 10700.000 10600,000 1,0590.o00 MNEMONIC VALUE MNEMONIC VALUE MNEM~]NIC VALUE GR 95'321 GRBU 199'800 ~<~ siam 37,416 T"Bg 456.968 ~BK 715.144 . NC 911.544 Slam 36.756 F$IG ·37.363 TNBS 463.723 TNG 851'574 TFG 1.o03 ~q TRAT 4'5]2 aP 89.817 : GRBU 199.950 TRAT 4~723 TMOD 98,052 ~ GR 0.000 NG 5998: ::~ "" ;":~:' ,,, .,: !Ii.:,: i . - -" :. ' .... ' 6.000 aR 9I.:519 : ~. ~RBU -999'250 SIGM 37.J71 TNBK 458,469 IFBK :999,250 TNG .899,550 TRAT 4.738 : TMOD ........ 999~250 i:: GR ,999.250 NG -6999.250 TFG : i,,,,999.250 TRAT ,'999.250 · · · ' . ' · - . . . _ . :. ~ · . - _ ' . MNEMON lC FSIG TFG GRBU TFBK TMOD FSIG TFG GRBU TFBK TMOD FSlG TFG GROU TFBK TMOD VALUE 38.42 1.00 200.00 733.66 93.45 38.]2 1.00 0.34 0.00 0.15 39.17 -999.25 -999.25 -999.25 -999.25 -£ SUMMARY OF DATA RECORDS ~ · NUMBER OF RECOIqDS; 169 IL~ENGTH OF RECORDS: 1,014 BYTES ENGTH OF LAST ~ECORD:' 426 BYTES- < ' FILE T~AILER ~ LENGTH: FILE NA~E: MAXIMUM PHYSICgL RECORD LE GI'H. 1024 BYTES EOF TAPE TRAILER LENGTH: t]2 B Y TE 6 TAPE NAME.. 61447 SF~RVICE NAME: EDIT NEXT TAP~ NUMBER NAME:~ ~ ~.. ~_ ... : -_ C~}MMENTS: UN1QUE WEEL IDENTIFICATION NUMBE~ IS 50-029-20441 - . '- . _ . . .~.. . . .:: · - . . ~. . . : - . ~ . _. ~. - _ - '<. : ~ '.~ · I1 --000000 ii 000000 1111 O0 O0 1111 O0 O0 11 O0 0000 11 O0 0000 11 O0 O0 O0 11 O0 O0 O0 11 0000 O0 11 0000 O0 11 O0 O0 11 O0 O0 111111 000000 1i1111 000000 77777 7777 000000 '7 oooooo 77 O0 O0 77 77 O0 O0 77 77 O0 0000 77 77 O0 0000 77 77 O0 O0 O0 77 77 O0 O0 O0 71 7? OOOO O0 77 77 0000 O0 77 77 O0 O0 77 77 O0 O0 77 77 000000 77 77 000000 77 666666 000000 666666 000000 66 O0 O0 66 O0 O0 66 O0 0000 66 O0 0000 66660666 O0 O0 O0 '66660666 .... O0 O0 O0 66. 66 0000 ::00 66 66 0000 O0 66 06 O0 O0 66 66 O0 O0 666666 000000 666666 000000 44 44 666666 666606 44 44 666666 666666 44 44 66 66 44 44 66 66 44 44 66 66 44 44 66 66 4444444444 66666666 66666666 4444444444 6~.6666.66. 6U666666 44 66 66 66 66 44 66 66 66 66 44 66 66 66 66 44 6~ 66 66 66 44 666666 666666 44 666666 666666 *START* USER PCAL [10701,604266]_ JOB VERITY SE~. 422-0 DATE 05-dUN-80 22:31:56 MONITOR SWS KLIO~3'/ APR-80. *S ART* *START* USER PCAb [10707,60466] dOB VERIFY SE~ 4220 DATE 05-JUN-80 22:31:56 MONITOR S~6 KL10E37 APR-80' *START* · MON1ToR*START*sw,USERKL10E37PCAb APR[10:07'60466]80. *START*ODS VERiF~ SEQ. 4220 DATE 05-JUN-80. 22:31:56 *START* USER PCAL [10707,60460] JOI~ VERIFt SE~ 4220 DATE 05-dUN-B0 22:31156 MONITOR $~S KL10E37 APR-80. *START* ' *START* USER PCAb [I0~707,60406J JOB VERIF~ *E~ 4220 DAT~ 05-JUN-80 22:31:56 MONITOR 6NS KLIOE37 APR-BO. *~TART~ ' SCHLUMBERGER COMPUTING CENTE~ 10707,6046~ REEL HEADER LENGTH: 112 BITES REEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CONTINUATION NUMBER: Ol PREV1OUS REEL NAME: C[)MME, NTS: bis FORMAT CUSTOMER TAPE DATE: 80!1 O/ 5 TAPE HEADER LENGTH: 132 BYTES TAPE NAME: 60466 DATE: 80/ 6/ SERVICE NAME: EDiT TAPE CONTINUATION NUMBER: O1 PRE¥1OUS TAPE NAME: COMMENTS: ~APE COMMENTS CASING SIZE 9.875/BOTTM DRILLER 10568/BIT SIZE 8.5/ FLDiD T~PE GEL-XC-POLY/DENS 9.5/ViSC 34/PH 10.5/ FLUID LOSS 7.8 ML/RM 1.66~75 F/RMF 1.77~65 F/RMC~ 2.35~65 MAX REC TMP 193 P/ ~rAKEN FROM RUN#I DIL LOGGED 5MA~80 5;0~~ FILE ~EADER LENGTH: ~2 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: PREV1OiJS ~'iLE NAME: 1024 B~TES WELL SiTE IN~'ORMAT1ON RECORD LENGTH COMPAN'~ WELL: FIELD: RAN GE: TOWN: SECTION C 0 ~J;'"%( 176 B~TES 6OHiD AI~ALKA P~TRO, CO, PRUDHOE BAY 14E 7 N. SLOPE AT,AKKA VV VV VV V¥ VV VV VV VV VV V¥ VV VV VV VV YV EEEEEEEEEE RRRRRRRR VV EEEEEEEEEE RRRRRRRR VV EE RR RR VV EE RR RR VV EE RR RR VV EE RR RR VV EEEEEEEE RRRRRRRR VV EEEEEEEE RRRRRRRR VV EE' RR RR VV EE RR RR EE RR RR EE RR RR EEEEEEEEEE RR RR EEEEEEEEEE RR RR IIIIIi Iiiiii II 1i II II II ii II ii II 1I Iillii IIIIii X¥ ¥¥ YX YY XY YY YY YY XY YX X¥ YX XX YY 000000 000000 666666 000000 000000 666666 00 00 00 O0 66 O0 O0 O0 O0 66 00 0000 00 0000 66 00 0000 00 0000 66 O0 O0 O0 O0 O0 O0 66666666 O0 ' O0 O0 O0 O0 O0 66666666 0000 O0 0000 O0 66 66 0000 O0 0000 O0 b6 66 00 00 O0 00 66 66 O0 O0 O0 O0 66 bb 000000 000000 666666 000000 000000 666666 *START* USER PCAL [10707 60466] ,]OB VERIFX SEW. 4220 DATE 05-jUN-80 MONITOR 5W6 KL10E37 APR-BO[ *START* FILE: DS~H:VERiFY.006<05/>[10707.60466] CREATED: 05'JUN-80 221281]2 PRINTED: 05-JUN-80 22:321 12 OUEUE SWITCHES: /fiLE:ASCII /COPIES:I /SPAC1NG:I /LiMI~:5g /FORMS:NORMAL 22:31156 LENGTH: 650 BYTES ENTRY BLOCKS: TYPE 0 DATUM SPECIFICATION SLOCKS: SIZE REP CODE ENTRY lC TOOL S¥ORD# UNITS AP1 API APl AP1 FT 0 0 0 0 MY 7 1 0 0 OHMM 7 12 46 0 OHNM ? 12 44 0 OHMM 7 22 ! 0 GAPI 7 31 32 0 GAPi 42 3! 32 0 IN 42 28 1 0 G/C] 42 44 0 0 PU 42 68 2 0 G/C] 42 35 I 0 C/C 42 42 1 0 CPS 42 34 92 0 CPS 42 34 93 0 GAPI 60 ~1 32 0 ~$/F ~0 52 32 0 VALUE MNEMONIC VALUE ]. DEPT 2 SP D1L ] ILD D1L 4 1EM DIE 5 SFLU DiE 6 GR 7 GR CML 8 CALl CML g DRHO FDC 10 NPHI CML 1! RHOB CML 12 NRAT CML 13 NCNb CML 14 FCNL CML 15 GR BHC 16 DT BHC DEPTH MNEMON1C SP GR NPHI FCNL -16.203 lED 3.572 110.313 GR 0.000 -I.611 RHOB -2.000 0.000 GR 110.688 1]?09.000 SP -16.453 ILD ].572 GR 110.313 GR 0.000 NPBi -1.61i RHOB -2.000 FCNL 0.000 GR 110.688 11700.000 SP -17.203 ILD 3.656 GR 111.375 GR 98.438 NPHI 26.953 RHOB 2.629 FCNL 810.500 GR 105.438 11600.000 ENTRY 0 11500.000 FLEE# SIZk 400,000 EXP PROC 11300.000 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 0 4 0 0 MNEMONIC VALUE CALl NRAT DT IbM CAbI NRAT DT CALl NRAT DT · 8. 0. 84. · 8. 0. 84. 9. 2. 85. SP -77.688 ILD 1.890 IbM 2. GR ~1.95] GR 31.125 CALl $. NPH1 22.754 RHOB 2.396 NRAT 2. FCNL 1321.000 GR 21.422 DT 88. ~f -04.688 I5[) 6.172 iSM 6. GR 29.875 GR 30.484 CALl 8. NPHI 20.459 RHOB 2.426 NRAT 2. FCNL 1486.000 GR ]0.109 DT 82. SP -78.188 II,,O 2.025 ILM GR 30.750 GR 32.563 CALl NPHi 20.996 RHOB 2.254 NRAT · SAM REP DEPT SH£FT 994 50O 000 000 994 500 000 000 842 912 563 207 414 529 56.] 918 469 379 750 260 ] 75 ,t06 68 0 ~8 0 68 0 68 0 68 0 68 0 68 0 68 0 68 0 68 0 68 0 68 0 68 0 68 0 68 0 08 O MNEMONIC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 VALU~ SFLU DRHO NCNL 3.270 -6.945 0.000 DRHU NCNb 3.271 -6.945 0.000 SFLU DRHO NCNb 0.074 2224.000 St,'LU DRHU NCNb DRHO NCNb SFLU DRHO NCNb 5.359 0.021 3198.000 13.875 O.OjO 3462.000 11200.000 SP -77,469 GR 31.734 NPHi 18.457 ~"CNL 1580.000 11100.000 SP -78.688 GR 21.553 NPHI 13.135 FCNL 2330.000 I1000.000 SP -64.969 GR 44.313 NPHI 19.629 FCNL 1457.000 10900.000 SP -79.969 GR 27.344 NPHI 22.021 FCNL 1334.000 ILD GR RHOB GR iLD GR RHOB GR iLD GR RHOB GR ILD GR RHUB GR ]0800.000 SP -36.484 GR 118.125 GR NPHI 20.264 RHOB FCNL 2276.000 G~ DEPTH MNEMONIC VALUE MNEMONIC 10700.000 8P -26.688 lED GR 102.313 GR NPHI 40.088 RHUB ~CNL 395.250 OR 10600.000 SP -27.45] GR 98.938 NPHi 34.i31 FCNL 572.500 10536.000 SP -1019.250 GR -999.250 NPHi -99925.000 FCNL -999.250 SUMMAR~ OF DATA RECORDS NUMBER OF RECURDS: 157 LENGTH OF RECORDS: 966 LENGTH O~~ LAST RECO~O: B2TES 454 BYTES GR RHOB GR ILD GR RHOB GR 1.89i 31.063 2.252 34.500 3.295 19.547 2.348 18.156 11.070 34.438 2.289 36.969 30.219 26.797 2.229 24.719 15.953 129.875 2.66O 127.188 VALUE 1.812 88.500 2.480 92.813 1.819 102.250 2.352 10].375 -999.250 -999.250 -999.250 -999.250 CALl NRAT DT ILM CALl NRAT DT CALl NRAT DT CALl NRAT DT CALl NRAT DT MNEMGNIC CAb/ NRAT DT 1LM CALl DT CALl NRAI DT 2 8 2 91 3 8 1 77 .172 .555 .254 .750 .768 .523 .894 .563 12.695 9.648 2.420 90.563 22. 8. 2. 93. 15. 8. 2. 77. VALU I . lb. 4. 110. . 14. 3. 127. -999. -999. -999. -999 . 063 484 486 563 750 828 395 000 E 833 65b 016 188 78O 8O5 578 000 25O 25O 250 25O SFLU DRHO NCNb SFLU DRHO NCNb SE'GU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb MNEMONIC SFLU DRHO NCNb DRHO NCNb DRHU NCNb B~TES 1024 TRAILER LENGTB: 62 B~TE$ FILL NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: NEXT FILE NAME: 4.480 0.010 3488.000 5.710 0.010 4496'000 15.~J3 0.013 3298.000 23.172 O.OOl 3340.000 18.656 -0.017 4082.000 VALUE 2.213 0.335 1531.000 1.73"1 0.105 2025.000 -999.250 -999.250 -999.250 TAP~ TRAILER bENGTH: 132 BYTES TAP~ NAME: ~0466 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O! NEXT TAPE NAME: COMMENTS: DATE: 801 6/ 5