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Home My WebLink About182-0027. 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 B-18 OA Squeeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 182-002 50-029-20702-00-00 9410 Conductor Surface Intermediate Production Liner 9239 80 2666 8557 1325 9338 20" 13-3/8" 9-5/8" 7" 9169 30 - 110 30 - 2696 28 - 8585 8080 - 9405 30 - 110 30-2695 28 - 8445 7962 - 9234 None 2670 4760 5410 None 4930 6870 7240 9123 - 9198 4-1/2" 12.6# x 5-1/2" 17# 13cr80 x L80 26 - 8136 8962 - 9034 Structural 4-1/2" Baker S3 Packer 7993, 7879 7845, 7993 7737, 7879 Stan Golis Sr. 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 0028310 26 - 8016 OA at Surface 1.5-gallons WellLock pumped with 1000-psi final pressure. Re-treat with .25-gallons WellLock at 1000-psi final pressure. 612 347 29329 30225 2035 2173 0 0 789 865 322-612 13b. Pools active after work:Prudhoe Oil 5-1/2" Packer 7845, 7737 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 No SSSV Installed ct to the best of my kno January 13, 2023 By Samantha Carlisle at 3:35 pm, Jan 13, 2023 WCB 11-1-2023 DSR-1/17/23 182-002 RBDMS JSB 012623 OA Squeeze PBU B-18 PRUDHOE BAY, PRUDHOE OIL Repair Well Sundry Number 322-612 ACTIVITY DATE SUMMARY 11/19/2022 T/I/O = 1020/50/0. Temp = 148°. Steam conductor (wellock). No AL. Evacuated blue goo & steam cleaned conductor. 20" Conductor depths = 2 o'clock side @ 6". 4 o'clock @ 6". 7 o'clock @ 13", 9 o'clock @ 13 ". Outer casing 9 5/8". SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:30. 11/19/2022 T/I/O=1020/50/0. RD OA & OA companion flange. Pull VR plug from companion side. RU Integral Flanges and block valves with 1502 caps. Torque flanges to API specs. 11/21/2022 T/I/O = 1100/0+/0. Temp = 146°. OA WellLock Squeeze (repair SC leak). No AL. OA cemented to surface. Remove 1502 cap & block valve, re-install hardline 90°. Poured 1 gallon of Wellock to fill OA void & hardline. Pumped 1.5 gallons of WellLock into OA. No returns in conductor. Heater installed in well house, man door ajar. Final WHPs = 1100/0+/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00. 11/22/2022 T/I/O = 1100/0+/580. Temp = 144°. WHPs (post wellock). No AL. OAP decreased 420 psi from increase at beginning of shift. Increased OAP to 1000 psi. Wellock consistancy of cold molasses. Heater still in WH with door propped open. Tree cap psi @ 1040 psi. Final WHPs =1100/0+/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:30 11/23/2022 T/I/O = 1060/0+/720. Temp = 146°. WHPs (post wellock). No AL. OA cemented to surface. Integrals installed on OA and OA companion. TP decreased 40 psi and OAP decreased 280 psi over night. Increased OAP to 1000 psi. Wellock sample has set. Heater still in WH with door propped open. Tree cap psi @ 1040 psi. Final WHPs = 1060/0+/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:30 11/23/2022 T/I/O = 790/0+/920. Temp = 143°. WHPs (post wellock). No AL. OAP decreased 80 psi from increase at beginning of shift. Increased OAP to 1000 psi. Wellock consistancy of taffy. Heater still in WH with door propped open. Final WHPs = 790/0+/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00. 11/23/2022 T/I/O = 790/50/700. Temp = 142°. WHPs (Well Lock). No AL. Integrals installed on OA and OA companion. Pressured up OAP to 1000 psi. FWHPs = 790/50/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 08:00 11/24/2022 T/I/O = 1060/0+/980. Temp = 146°. WHPs (post wellock). No AL. OA cemented to surface. Integrals installed on OA and OA companion. OAP decreased 20 psi over night. Increased OAP to 1000 psi. Wellock sample has not set up. Heater still in WH with door propped open. Tree cap psi @ 1040 psi. Final WHPs = 1060/0+/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 08:30 11/25/2022 T/I/O = 1050/40/850. Temp = 142°. WHP's (Well Lock). No AL. OA cemented to surface. Intergrals installed on OA & OA companion. OA decreased 150 psi over night. Increased OA to 1000 psi. Bled tree cap psi from 1050 psi to 0 psi. Well lock sample is set but not fully cured. Upon arrival heater was not working. Reinstalled new working heater upon departure, WH door ajar. Final WHP's = 1050/40/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 0915 Daily Report of Well Operations PBU B-18 g sample is set but not fully cured OA cemented to surface. OA WellLock Squeeze (repair SC leak). g set. Well lock Wellock sample has Poured 1 gallon of Wellock to fill OA void & hardline. Pumped 1.5 gallons ofg WellLock into OA. No returns in conductor Daily Report of Well Operations PBU B-18 11/26/2022 T/I/O = 1050/40/1000. Temp = 142°. WHP's (Well Lock). No AL. OA cemented to surface. Integrals installed on OA & companion. Did not increase OA. Bled tree cap psi from 500 psi to 0 psi. Well lock sample is not fully cured. Heater is working & installed w/ door ajar. Final WHP's = 1050/40/100. SV = C. WV, SSV, MV = O. IA, OA = OTG. 08:50 11/27/2022 T/I/O = 1020/40/840. Temp = 142°. WHPs (post wellock). No AL. Wellock sample firm with a slight give when squeezed. Heater in wellhouse with door propped open. SV = C. WV, SSV, MV = O. IA, OA = OTG. 13:30 11/28/2022 T/I/O = 1100/40/1000. Temp = 142°. WHPs (post wellock). No AL. Wellock sample firm with a slight give when squeezed. 5 gallon bucket with leftover wellock still soft. Heater in wellhouse with door propped open. SV = C. WV, SSV, MV = O. IA, OA = OTG. 13:30 11/29/2022 T/I/O = 1050/40/1000. Temp = 145°. WHP's ( Post Wellock). No AL. OA cemented to surface. Wellock sample not fully cured, can still make indent mark in sample. 5 gallon bucket w/ leftover wellock is still soft. Heater is working & installed w/ door ajar. Did not increase OAP. SV = C. WV, SSV, MV = O. IA, OA = OTG. 13:50 11/30/2022 T/I/O = 1050/40/1050. Temp = 150°. WHP's (Post Wellock). No AL. OA cemented to surface. Wellock sample is not cured, can still make indent mark in sample. 5 gallon bucket w/ leftover wellock is still soft. Did not increase OAP. Heater is working & installed with WH door ajar. SV = C. WV, SSV MV = O. IA, OA = OTG. 14:00 12/1/2022 T/I/O = 1050/40/850. Temp = 145°. WHP's (Post Wellock). No AL. OA cemented to surface. Wellock sample not fully cured. 5 gallon bucket is starting to set up. Increased OAP to 1000 psi. Heater working & installed w/ WH door ajar. Final WHP's = 1050/40/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 12:40. 12/2/2022 T/I/O = 950/40/1000. Temp = 145°. WHP's (Post Wellock). No AL. OA cemented to surface. Upon arrival wellock sample looked cured. During RD wellock @ 3:00 companion side was not set up. RU accumulator @ 3:00 companion side, increased OAP to 1000 psi. Wellock appears to be set up @ 9:00 position, guage = 0 psi. Moved heater trunk to direct heat @ 3:00 companion side. Wellock is not fully cured. Final WHP's = 950/40/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 12:30 12/3/2022 T/I/O = 950/40/900. Temp = 145*. WHP's (Post Wellock). No AL. OA cemented to surface. OA guage on accumulator reading 950 psi, guage on hardline reading 0 psi. Sample does not appear to be fully cured. SV = C. WV, SSV, MV = O. IA & OA = OTG. 13:30. 12/5/2022 T/I/O = 950/40/800. Temp = 142°. WHP's (Post Wellock). No AL. OA cemented to surface. Heater working & installed w/ WH door ajar. Wellock sample not fully cured. Increased OAP 200 psi. Final WHP's = 950/40/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 10:15 12/6/2022 T/I/O = 950/40/900. Temp = 145°. WHP's (Post Wellock). No AL. OA cemented to surface. Heater working & installed w/ WH door ajar. Wellock sample not fully cured. Increased OAP to 1000 psi. Final WHP's = 950/40/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:30 Daily Report of Well Operations PBU B-18 12/7/2022 T/I/O = 950/40/750. Temp = 142°. WHP's (Post Wellock). No AL. OA cemented to surface. Upon arrival heater was not working, ordered new heater. Wellock sample appears to be set up. Wellock on working side OA @ 9:00 positon appears to be cured, Wellock @ 3:00 companion side OA is not cured. Increased OAP from 750 psi to 1000 psi. Final WHP's = 950/40/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:30 12/8/2022 T/I/O = 950/40/1300. Temp = 142°. WHP's (Post Wellock). No AL. OA cemented to surface. Heater working & installed w/ WH door ajar. OA thermaled up over night. RD jewlery @ 3:00 position to check Wellock, appears to be foamy. Reinstalled Jewlrey & increased to 700 psi. Wellock still not cured @ 3:00 position. Final WHP's = 950//40/700. SV = C. WV, SSV, MV = O. IA, OA = OTG. 09:30 12/10/2022 T/I/O = 960/40/550. Temp = 142°. WHPs (Wellock). No AL. Heater working properly. Ajusted heater trunk. Wellock samples cured. OAP decreased 150 psi from 12/8/22. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:00 12/11/2022 T/I/O = 900/40/550. Temp = 140°. WHPs (Wellock). No AL. Heater working properly. Wellock samples cured. Increased OAP pressure to 700 psi with lift gas from B-29. OAP decreased 150 psi from 12/10/22. FWHPs = 900/40/700 SV = C. WV, SSV, MV = O. IA, OA = OTG. 09:00 12/12/2022 T/I/O = 940/40/550. Temp = 150°. WHPs (Wellock). No AL. Heater working properly. Wellock samples cured. TP increased 40 psi and temperature increased 10° over night. SV = C. WV, SSV, MV = O. IA, OA = OTG. 07:30 12/19/2022 T/I/O = 920/40/600. Temp = 146°. WHPs (Wellock). No AL. Heater working properly. Wellock samples cured. Wellock is not cured at 3:00 position. OA will have to be resqueezed with Wellock. SV = C. WV, SSV, MV = O. IA, OA = OTG. 09:00 12/28/2022 T/I/O = 900/40/0+. Temp = 141°. OA WellLock Re-treat. No AL. OA cemented to surface. Pumped 1/4 gallon of Wellock into 3:00 side of OA to 2000 psi. No returns into conductor and no communication with 9:00 side of OA. Moniitored for 1 hr. OAP unchanged. Bled OAP to 1000 psi. Accumulator hose attached to 3:00 side of OA charged with lift gas with valves closed for future psi increase. Heater installed in well house, man door left open. Final WHPs = 900/40/1000. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:00. 12/29/2022 T/I/O = 900/40/1050. Temp = 140°. WHP's (post Wellock). No AL. OA cemented to surface. Heater is working and installed @ 3:00 position w/ WH door ajar. Wellock sample is not fully cured, starting to set up. Did not increase OAP. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:00 12/30/2022 T/I/O = 900/40/950. Temp = 140*. WHP's (post Wellock). No AL. OA cemented to surface. OAP decreased 100 psi from 12-30-22. Heater is working and installed @ 3:00 position w/ WH door open. Wellock sample is not fully cured but is setting up. Did not increase OAP. SV = C. WV, SSV, MV = O. IA & OA = OTG. 15:00. () g Wellock samples cured. Wellock is not cured at 3:00 position. OA will y have to be resqueezed with Wellock Wellock sample g appears to be set up. Wellock on working side OA @ 9:00 positon appears to beg@ cured, Wellock @ 3:00 companion side OA is not curedA OA WellLock Re-treat () Wellock samples cured Pumped 1/4 gallon of Wellock into 3:00 side of OA to 2000 psi. No returnsAg into conductor and no communication with 9:00 side of OA Daily Report of Well Operations PBU B-18 12/31/2022 900/40/920. Temp = 142*. WHP's (post Wellock). No AL. OA cemented to surface. OAP decreased 30 psi from 12-30-22. Heater is working and installed @ 3:00 position w/ WH door open. Wellock sample is not fully cured but is setting up. Did not increase OAP. Final WHP's = 900/40/920. SV = C. WV, SSV, MV = O. IA & OA = OTG. 13:30. 1/1/2023 T/I/O = 950/40/920. Temp = 146°. WHP's (post Wellock). No AL. OA cemented to surface. OAP unchanged since 12/31/22. Heater is working and installed @ 3:00 position w/ WH door open. Wellock sample is not fully cured but is set up. Increased OAP from 920 psi to 1000 psi. Final WHP's = 950/40/1000. SV = C. WV, SSV, MV = O. IA & OA = OTG. 15:50 1/2/2023 950/40/900. Temp = 146°. WHP's (post Wellock). No AL. OA cemented to surface. OAP decreased 100 psi since 01/01/22. Heater is working and installed @ 3:00 position w/ WH door ajar. Wellock sample is not fully cured but is set up. Increased OAP from 900 psi to 1000 psi. Final WHP's = 950/40/1000. SV = C. WV, SSV, MV = O. IA & OA = OTG. 15:20 1/3/2023 950/40/1000. Temp = 142°. WHP's (post Wellock). No AL. OA cemented to surface. OAP unchanged since 01/02/23. Heater is working and installed @ 3:00 position w/ WH door ajar. Wellock sample is not fully cured but is set up. Final WHP's = 950/40/1000. SV = C. WV, SSV, MV = O. IA & OA = OTG. 17:10 1/4/2023 1250/40/850. Temp = 142°. WHP's (post Wellock). No AL. OA cemented to surface. Heater is working and installed @ 3:00 position w/ WH door ajar. Wellock sample is cured. Bled OAP to 0 psi, monitor overnight for pressure build up. Final WHP's = 1250/40/0. SV = C. WV, SSV, MV = O. IA & OA = OTG. 14:00 1/5/2023 950/40/850. Temp = 142°. Bleed OAP to 0 psi (post Wellock). No AL. OA cemented to surface. Wellock sample is cured in OA, ops notified. Bled OAP to 0 psi. Well support notified to re-install CV/VR plug & blind on OA. Heater released. Final WHP's = 1250/40/0. SV = C. WV, SSV, MV = O. IA & OA = OTG. 11:00 1/5/2023 T/I/O=1250/40/0. Post Wellock. Verified 0 psi on OA, RD working OA hardline and installed 3" McEvoy valve, Torque to API spec. RD Comp OA hardline and Iinstalled 3" tapped blind. Wellock in VR profile, unable to set VR plug. ***Job Complete*** Final WHP's 1250/40/0. () Wellock sample is cured in OA, ops notified g@ Wellock sample is not fully cured but is setting up. Post Wellock. 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Chmielowski Digitally signed by Jessie L. 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'+'5(648((=( 2$:,7+:(///2&.,) 1(&(66$5< 9DOYH6KRS 1'2$,17(*5$/182$*$7(9$/9( ͲϭϴŝƐĂŶĂƚƵƌĂů ĨůŽǁ ƉƌŽĚƵĐĞƌ ǁŚŝĐŚ ůĂƐƚǇĞĂƌ ďĞŐĂŶĞǆŚŝďŝƚŝŶŐďƵďďůŝŶŐŝŶƚŚĞ ĐŽŶĚƵĐƚŽƌďǇƐƵƌĨĂĐĞ ĐĂƐŝŶŐĂŶŶƵůƵƐ Ž KtĞůů>ŽĐŬ^ƋƵĞĞǌĞ tĞůů͗ Ͳϭϴ Wd͗ ϭϴϮͲϬϬϮ W/͗ϱϬͲϬϮϵͲϮϬϳϬϮͲϬϬ +LOFRUS 1RUWK6ORSH//&+LOFRUS 1RUWK6ORSH//&Changes to Approved Work Over Sundry Procedure'DWH 2FWREHU6XEMHFW &KDQJHVWR$SSURYHG 6XQGU\3URFHGXUHIRU :HOO %6XQGU\ $Q\PRGLILFDWLRQVWR DQ DSSURYHGVXQGU\ ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ &KDQJHVWRDQDSSURYHG VXQGU\ ZLOOEHFRPPXQLFDWHGWRWKH$2*&& E\WKH ZRUNRYHU:2³ILUVWFDOO´HQJLQHHU $2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6WHS3DJH'DWH 3URFHGXUH&KDQJH+163UHSDUHG%\,QLWLDOV+16$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH$SSURYDO$VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH3UHSDUHG)LUVW&DOO 2SHUDWLRQV (QJLQHHU 'DWH 7. 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): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well 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 B-18 OA Squeeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 182-002 50-029-20702-00-00 9410 Conductor Surface Intermediate Production Liner 9239 80 2666 8557 1325 9338 20" 13-3/8" 9-5/8" 7" 9169 30 - 110 30 - 2696 28 - 8585 8080 - 9405 30 - 110 30 - 2695 28 - 8445 7962 - 9234 None 2670 4760 5410 None 4930 6870 7240 9123 - 9198 4-1/2" 12.6# L80 26 - 8136 8962 - 9034 Structural 4-1/2" Baker S3 Packer 7845, 7737 7845, 7737 7993, 7879 Stan Golis Sr. 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 13.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 0028310 4-1/2" Baker S3 Packer 26 - 8136 7993, 7879 OA from Surface to 40' 17.9-gal 15.6-ppg Permafrost C cement (applied 20-psi squeeze pressure) followed by 19.1-gal WellLock 494 437 36888 19970 1783 2352 1000 300 999 811 321-451 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: By Samantha Carlisle at 8:22 am, Oct 08, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.10.08 07:05:29 -08'00' Stan Golis (880) MGR15OCT2021 DSR-10/11/21 RBDMS HEW 10/8/2021 SFD 10/8/2021 ACTIVITYDATE SUMMARY 9/13/2021 T/I/O = SSV/0/0. Verified Zero flow on working OA. Removed working side OA. Installed integral w/Block vlave and cap. FWHP = SSV/0/0 OTG. 9/16/2021 T/I/O = SSV/0/0. Temp = SI. Steam conductor (Pre Wellock). Performed a NFT test on the OA. Removed 1502 OA block valve and strapped the TOC in the OA @ 10' w/ 8' of liquid (25 gallon fill up). Steamed the conductor flutes for 5 hours. Flute @ the 4 o'clock position has a 61" void (leak point). All other flutes are ~18" deep. Flutes will need more steaming if conductor is to be cemented. Ran out of time. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:10 9/18/2021 T/I/O = SSV/0+/0. Temp = SI. Cement OA (Pre wellock). No AL. Performed a NFT on the OA. Removed 1502 block valve and strapped OA at 10' (2' of liquid in OA). Used a barrel pump to remove 1' of liquid from the OA (could not pull from exact bottom). Poured 18.4 gallons of perm - C into the OA to fill. Incrementally applied N2 to the OA to create a void (@ 200 psi conductor filled up w/ cement, ~ 1.5 gallons returned from conductor). Poured another gallon of Perm - C into the OA to fill and applied 40 psi of N2 (no returns from conductor. After initial set-up (2 hours) OAP decreased to 30 psi (no returns from conductor). FWPs = SSV/0+/30. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:50 9/20/2021 T/I/O = SSV/0+/0+. Temp = SI. OA WellLock Squeeze (repair SC leak). No AL. OA cemented surface (~7' TOC). Remove 1502 cap & block valve, re-install 1502 90° & pup joint. Poured 16 gallons of Wellock to fill OA void. Pumped 3.1 gallons of WellLock into OA when returns began coming out of the flute @ the 1 o'clock position. Monitor WH temp & Wellock sample until sample is set up. WH temp between 60° - 90° until sample is set up. Heater installed in well house, man door ajar. Final WHPs = SSV/0+/140. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 10/1/2021 T/I/O=SSV/0/0. Post well lock job. RD 3" 5000 integral and hardline. RU 3" McVoy O/A valve. Torqued to API spec. Job Complete. Final WHP's SSV/0/0. 10/1/2021 T/I/O = SSV/0+/80. Temp = SI. WHPs (post Wellock). No AL. Heater working properly. Both wellock samples are set up. Ops to keep heater. SV, WV, SSV = C. MV = O. IA, OA = OTG. 07:30 10/2/2021 T/I/O = 900/137/0. Temp = 132*. WHP's (post well lock). No AL. Heater removed, well was POP'd this AM. 10/3/2021 T/I/O = 920/270/0. Temp = 134*. WHPs (post wellock). No AL. OA cemented to surface. Heater has been removed and the well has been popped. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:00 10/4/2021 T/I/O = 880/350/0. Temp = 138°. WHPs (Post Wellock). No AL. IA FL @ surface. OA cemented to surface. IAP increased 80 psi since yesterday at 04:00. SV = C. WV, SSV, MV = O. IA, OA = OTG. 13:00 Daily Report of Well Operations PBU B-18 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name: Authorized Title: Authorized Signature: Date: Contact Name: Contact Email: Contact Phone: COMMISSION USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE COMMISSIONCOMMISSIONER PBU B-18 OA Squeeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 182-002 50-029-20702-00-00 N/A ADL 0028310 9410 Conductor Surface Intermediate Production Liner 9239 80 2666 8557 1325 9338 20" 13-3/8" 9-5/8" 7" 9169 30 - 110 30 - 2696 28 - 8585 8080 - 9405 2558 30 - 110 30 - 2695 28 - 8445 7962 - 9234 None 2670 4760 5410 None 4930 6870 7240 9123 - 9198 4-1/2" 12.6#L80 26 - 81368962 - 9034 Structural 4-1/2" Baker S3 Packer 5-1/2" Brown Packer 7845, 7737 7993, 7879 Date: Stan Golis Sr. Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY, PRUDHOE OIL 9/20/2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:15 am, Sep 07, 2021 321-451 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.09.04 16:10:32 -08'00' Stan Golis (880) DSR-9/7/21MGR15SEP2021SFD 9/7/2021 10-404 dts 9/15/2021 JLC 9/15/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.16 10:28:26 -08'00' RBDMS HEW 9/16/2021 OA WellLock Squeeze Well: B-18 PTD: 182-002 API: 50-029-20702-00-00 Well Name:B-18 Permit to Drill Number:182-002 Well Type P API Number:50-029-20702-00-00 Job Scope:OA WellLock Squeeze Reg.Approval Req’d?Yes Current Status:Under Eval, Offline Date Reg. Approval Rec’vd: Estimated Start Date:09/20/2021 Estimated Duration:2day Regulatory Contact:Mel Rixse First Call Engineer:Oliver Sternicki Second Call Engineer:Wyatt Rivard Brief Well Summary: B-18 is a natural flow producer which on 8/19/2021 began exhibiting bubbling in the conductor by surface casing annulus. The OA was fully cemented during a RWO in 2009 to repair a surface casing leak at ~57’. The pressure communication path for this recent bubbling was determined to be from the IA to the OA through the IC seals in the wellhead on 8/20/2021. An MIT-IA passed on 8/24/21 and a pressure test of the IC seals passed on 8/25/2021 after they were reenergized. Current Status: B-18 is currently under evaluation starting 08/19/2021. Scope of Work: Squeeze OA with Well Lock (or similar) to repair surface casing leak. Procedure: 1 Valve Shop ND OA GATE VALVE, NU OA INTEGRAL 2 DHD STRAP TOC. TOP OA WITH CEMENT AS NEEDED. WELL LOCK OA SQUEEZE 3 Special Projects A/DHD WELL LOCK SQUEEZE 4 DHD POP U/E, MONITOR FOR SC LEAK, 5 Valve Shop ND OA INTEGRAL, NU OA GATE VALVE 6 DHD RE-SQUEEZE OA WITH WELL LOCK IF NECESSARY. g bubbling in the conductor OA WellLock Squeeze Well: B-18 PTD: 182-002 API: 50-029-20702-00-00 � � • • f c 9 11- a) r LIVI v �t�w 440 `0 a CL H ca 4- D to h 0O 0 Y 0 a) E a 0 N Z --1 Z r r r r r r r r r r U 4 > O�m co 0 a0 Ls C. C C <-7-- O a m '� > y 73 d ❑ -' w co rm co m " C p 0- ma co ` N d r C7 Qa Oo o °Q cn N O tQ o p p « srw C u a)N N ,- ' N N r CD 0 C Z Q M -00 +' Z d q11 . a u CU > o v d F- • O C i ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ C t.- a -, U J J J J J J J J J J -" C y= O W W W W W W W W W Wt,, a LL LL LL LL LL LL U. LL LL LL a� aa) a) -0 C J J J J J J J J J J a 0 > Q) td d d d d d d d d d d (1) v, C , 4- 5 C, Z Z Z Z Z Z Z Z Z Z u ca a) O • c) LL U. U. U. U. U- U- U. U. 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O O 0 0 ++ < O O O O O O O O O O d coN , O TorN 0 of O N 4, 'B CO 00 a_0 N N C") 'Cr C) m N N N N N N N N N N N tn U NC) O) O) O) 0) O) C) O) C) O) C 0 091 N N N N N N N N N N 000000000 O fl0 aC O 0 0 0 0 0 0 0 0 0 y f' a/ 00 N N CL) in N in C() CC) U) 1l) a -a 0] CD tc LLti •y d w On $i E u C E O Z 0 •0q 0 0 CID W Y p :W. 3 of U .tit 14 co, Z @ 9 Z a a �+ Q W 3 ca m o M rn v E a -0 c mom d 6 E N _, ❑ 3 0 m co m c $ 6 E cc n J 0 �C r b 3 O O p O co c y . a L� Q H a` a ns m o7r27n o C~ Schlu~6erper Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anehorege, AK 99503-2838 ATTN: Beth Well Job # N0.5567 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mehnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD P2-16 F BB6M-00027. LDL - 1 - 07/20/10 1 1 -03A V 225 AYKP-00096 SCMT ~ ~ 07/22/10 1 i - S-100 BBKA-00039 BC22-00014 USIT _ USIT ... r ~ 07/01/10 07/14/10 1 1 1 1 2-58/S-09 BCZ2-00016 LDL 07/17/10 1 1 1-15/P-25 AYKP-00094 LDL - 07/11/10 1 1 W-19A BCRD-00036 USIT 07/25/10 1 1 01-228 AZ2F-00042 MCNL _ 05/19/10 1 1 8-20 AY1M-00042 RST - 05/07/10 1 1 04-20 8-18 05-32A BCRJ-00020 AYKP-00082 BBK5-00040 RST RST RST 05/30/10 06/02/10 05/19/10 1 1 1 1 1 1 H-25 P2-34 BCRD-00017 AVVO.00063 RST RST - 05/10/10 04/17/10 1 1 1 1 PLEACF A(`KNrIWI Fnr:F QCr `C1oT Cv Crnruu n_ wr.in oeT„nun,n ...,~ ........ ~..... ..... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Btvd. Alaska Data 8 Consulting Services 2525 Gambell Street, Suee 400 Anchorage, AK 99503-2838 +~'9 au~~ ~ a~ ~a1o ~~F,-,. • pit ~. ~ ~~ ib • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 11, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Pad B Dear Mr. Maunder, by :~ ~, A ~~ ' ~tU w : ~:r~r. . ~~o~nssar~ ,_ .~._. ~a-oo~- Q-l~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad B that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date: 12/11/09 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al B-01 1700080 50029200590000 Sealed Conductor NA NA NA NA NA B-02 1961110 50029200660100 Sealed Conductor NA NA NA NA NA B-03A 1870480 50029203060100 NA 0.5 NA 3.40 8/20/2009 B-04 1700320 50029200720000 Sealed Conductor NA NA NA NA NA B-058 2010680 50029202760200 NA 1.8 NA 13.60 8/22/2009 B-06 1770740 50029202790000 NA 1 NA 5.10 8/20/2009 B-07 1780020 50029202850000 NA 1 NA 5.10 8/20/2009 B-08 1780410 50029203140000 NA 1 NA 6.80 8/20/2009 B-09 1780490 50029203160000 NA 0.5 NA 3.40 8/20/2009 B-10A 2082050 50029203210100 Cellar liner welded to casin NA NA NA NA NA B-11 1780690 50029203310000 NA 0.5 NA 3.40 8/20/2009 B-12 1970090 50029203320100 NA 0.6 NA 3.40 8/22/2009 B-13 1990570 50029203410100 NA 0.4 NA 1.70 8/20/2009 B-14 2090590 50029203490000 NA 0.4 NA 1.70 8/20/2009 8-15 1790190 50029203600000 NA 0.1 NA 1.70 8/20/2009 B-16 1790250 50029203650000 NA 0.8 NA 5.10 8/21/2009 B-17 1790280 50029203680000 NA 0.1 NA 1.70 8/20/2009 B-18 1820020 50029207020000 NA 1.5 NA 15.30 8/21/2009 B-19 2001610 50029207030100 NA 0.1 NA 1.70 8/21/2009 B-20 1821680 50029208420000 NA 0.5 NA 3.40 8/21/2009 B-21 1821760 50029208500000 25 4.5 BBLs 0.1 11/30/2009 1.70 12/3/2009 B-22A 2001570 50029207590100 34 6.5 BBLs 0.2 11/30/2009 1.70 12/3/2009 B-23 1970590 50029207790100 12 2.2 BBLS 3.2 11/30/2009 10.20 12/4/2009 B-24 1821400 50029208150000 NA 3 NA 22.10 8/21/2009 B-25 1821510 50029208260000 NA 0.25 NA 1.70 8/13/2009 B-26 2000570 50029209760200 NA 0.3 NA 1.70 8/21/2009 B-27 1961010 50029214710100 Sealed Conductor NA NA NA NA NA B-28 1853030 50029215100000 NA 1.1 NA 6.80 8/22/2009 B-29 2002090 50029215230100 NA 0.7 NA 6.80 8/21/2009 B-30 2011050 50029215420100 NA 0.2 NA 1.70 8/21/2009 B-31 1910460 50029221520000 NA 0.3 NA 1.70 8/20/2009 B-32 1991180 50029221650100 NA 0.3 NA 1.70 8/20/2009 B-33 1931450 50029223390100 NA 1.2 NA 8.50 8/21/2009 8-34 1930370 50029223520000 NA 1.2 NA 10.20 8/21/2009 B-35 1931460 50029224060000 NA 0.3 NA 1.70 8/20/2009 B-36 1960650 50029226670000 NA 0.3 NA 1.70 8/21/2009 B-37 2071450 50029233750000 Sealed Conductor NA NA NA NA NA STATE OF ALASKA Q ALA OIL AND GAS CONSERVATION COM~ION ~ u CEP ~ ®?Q0~ REPORT OF SUNDRY WELL OPERATIONS - 1, Operations Performed: °`'°' `- ='" ~~ .. ^ Abandon ®Repair Well , ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ®Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill. Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 182-002 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20702-00-00' 7. KB Elevation (ft): 73 8,, 9. Well Name and Number: PBU B-18 - 8. Property Designation: 10. Field /Pool(s): ADL 028310 ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9410' feet true vertical 9239' , feet Plugs (measured) 8054' Effective depth: measured 9338' feet Junk (measured) None true vertical 9169' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2696' 13-3/8" 2696' 2695' 4930 2670 Intermediate 8585' 9-5/8" 8585' 8445' 6870 4760 Production Liner 1325' 7" 8080' - 9405' 7962' - 9234' 7240 5410 ~cy~}~~ ~~; ~. ~ 2008 Perforation Depth MD (ft): Below Plug: 9123' - 9198' Perforation Depth TVD (ft): 8962' - 9034' 5-1/2", 17# x 4-1/2", 12.6# 13Cr80 / L-80 8136' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker S-3 Packer 7845' 9-5/8" x 5-1/2" BOT Packer 7993' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing from 7934'. Cut and pu119-5/8" casing from 2120'. Run 9-5/8" (47#, L-80) tieback to surface. Cement w/ 155 bbls Class 'G' 870 cu ft / 750 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 Subsequent to operation: 397 7701 3107 1740 600 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ~ ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A if C.O. Exempt: Contact Hank Baca, 564-5444 308-230 Printed Na a Sondra Stewman .Title Drilling Technologist `.~~ Prepared By NamelNumber: ~ ~ ignature Phone 564-4750 Date Terrie Hubble 564-4628 j Form 1 Revised 04 Submit Original Only __ /~~ _ ~~ SEP ~~ ~QQ~ .~ ~~ t ~ ~ 1 v/ fit-. l\ 41 WELLHEAD= Cameron ACTUATOR= Cameron KB. ELEV = 73.75' BF. ELEV = ..45.3' KOP = 5900' Max Angle = 22@ 6500' Datum MD = 9032' Datum TV D= 8800' SS 9-518" CSG PATCH, 47#, L-80; iD = 8.681" ~~ 211s 13-3/8" CSG, 72#, L80, ID = 12.347" 2696' L T 20' CONDUCTOR -~ 110' B-18 S OTES: ***4-1 /2" CHROMETBG*** 2102-19 5/8" HES ES STAGE CEMENTER 2125' 4-1,2" OT1S X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3296 3295 0 MMG DOME RK 16 08!17/08 3 5618 5617 0 MMG SO RK 20 08/17/08 2 6966 6904 21 MMG DCv1Y RK 0 48J13108 1 7753 7648 17 MMG Div1Y RK 0 48J13108 Minimum ID = 3.725" @ 8094' 4-1/2" OTIS'XN' NIPPLE 7$24" -14-112" OTIS X NIP, ID = 3.813" 4-112" TBG, 12,6#, 13CR80, .0152 bpf, ID = 3.958" ~ 7920' 4-1/z" TUBING STUB (07/22108) 7934' 5-1/2" TBG, 17#, L80, .0232 bpf, ID = 4.892" ~~ 7993' TOP OF 7" LNR ~~ 8080' 4-1/2" TBG,12.6#, L-80 .0152 bpf, ID = 3.958" ~ 8136' 9-518" CSG, 47#, L-80, ID = 8.681" 8585' PERFORATION SUMMARY REF LOG: DA-BHCA ON 05/21/82 ANGLE AT TOP PERF: 15 @ 9156' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 9090 - 9116 S 04/06/89 3-1/8" 4 9120 - 9123 S 04/06/89 3-3/8" 4 9123 - 9147 O 04/13/89 2-7/8" 4 9156 - 9166 S 04/06/89 2" 4 9164 - 9174 O 05/24/00 3-3/8" 4 9184 - 9198 O 04/13/89 PBTD 9338' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9405' MA RKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 05/25/82 ORIGINAL COMPLETION 08/14/08 N4ES RWO 08/18/08 KDGSV GLV GO (08/17/08) PRUDHOE BAY UNIT WELL: B-18 PERMfr No: x1820020 API No: 50-029-20702-00 SEC 31, T11 N, R14E BP Exploration (Alaska) 7845' 9 5J8" x 4-1?2" BKR S-3 PKR, ID = 3.875" 7870' 4-112" OTIS X NIP, ID = 3.813" 7925' 9-5I8" x 5-1f2" UNIQUE OVERSHOT 7973' BOT SBR SEAL ASSY 7993' 9 5/8" x 5-1/2" BOT PKR, ID = 4.75" 7993' 5-1 /2" x 4-1 /2" XO $054' 4-1/2" OTIS X NIP, ID = 3.813" 8094' 4-1 /2" OTIS XN NIP, ID = 3.725" 8136' 4-1/2" TTL BOT SO SUB, ID = 4.063" 8128' --~MD TT LOGGED 06/29/83 .Page 1~ of 3 Well: 6-18 Well History Well Date Summary B-18 7/16/2008 T/I/O = 30/0+/0. Temp = SI. Bleed WHPs to 0 psi pre PPPOT (RWO prep). No AL line. TBG FL near surface. IA FL near surface. Bled TBGP from 30 psi to 0 psi in 10 min into BT. Bled IAP from 0+ to 0 psi in 2 min into BT. Monitored pressures for 30 min. TBGP &IAP unchanged. Cellar liner previously installed around conductor, fluid in cellar -2" above cellar liner. Final WHPs = 0/0/0. MV &SSV open. Swab & WV closed. IA & OA valves OTG's. B-18 7/17/2008 T/I/0= 0/0/0. Temp= SI. WHPs post- bleed pre- PPPOT. TP, IAP, OAP unchanged overnight. SV, WV=Closed. SSV, MV= Open. IA and OA= OTG. B-18 7/17/2008 T/I/0= 0/0/0, Temp=S1. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Alemite external check previously installed. Stung into test port (400 psi), bled to 0 psi. Function LDS, all moved freely. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Alemite external check previously installed. Stung into test port (0 psi). Function LDS, all moved freely. Pumped through void, clean returns. Re energized secondary Y seal with plastic. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. B-18 7/18/2008 ***WELL S/I ON ARRIVAL**** PUI I Ff) P-PRONG FROM PX PLUG BODY (c~ $054' MD PULLED 4 1/2 PLUG BODY FROM 8054' MD DRIFTED TBG W/ 4.50" CENT TO TOP OF 4 1/2 XO @ 7993' MD DRIFTED TO 8200' SLM W/ 3.70" CENT ***CONTINUED ON WSR 07/19/08*** **NOTE: FLUID IN CELLAR ON ARRIVAL** B-18 7/19/2008 ***CONTINUED FROM WSR 07/18/08*** RIG DOWN SLICKLINE UNIT ***WELL LEFT S/I, DSO NOTIFIED*** B-18 7/19/2008 T/I/0=13/2/1. Temp=Sl. WHP's & check cellar for liner. (Pre-RWO). TP increased 13 psi in 2 days. IAP increased 2 psi in 2 days. OAP increased 1 psi in 2 days. Cellar has a removable liner around SC with 4" walls and is attached with velcro. Cellar has 8" of standing water in it and needs to be vac'ed out. SV & WV CLOSED MV &SSV OPEN. IA & OA OTG. B-18 7/20/2008 ***WELL SHUT IN ON ARRIVAL. INITIAL T/I/O: 0/0/0.*** RIH--TS: HEAD/ 2 WEIGHT BARS/ CCU HALLIBURTON SETTING TOOU 4.5" HALLIBURTON PLUG. SET TOP ELEMENT AT 8030 FT PER PE'S INSTRUCTIONS. SURFACE AND VISUAL IND ATION OF SETTING. RUN SLB LEAK DETECTION LOG WITH LRS PUMPING. ***JOB IN PROGRESS AND CONTINUED ON 21-JUL-2008 WSR*** B-18 7/20/2008 T/I/0=0+/0+/0+. SI. TBG & IA FL (for-Fullbore). TBG FL near surface. IA FL C~ 42' (2 bbls). SV, WV=closed. SSV, MV=open. IA & OA valves OTG. B-18 7/20/2008 T/I/0= 0/0/0. Assist E-Line with LDL. (RWO Prep) Pressure the TBG to 3000 psi with 5 bbls of crude. ***WSR continues on 07/21/08**" B-18 7/21/2008 ***LOG CONTINUED FROM 20-JUL-2008*** CONTINUE SLB LEAK DETECTION LOG WITH LRS PUMPING. RIH WITH HEAD/2 -WEIGHT BARS/ CCL FIRING HEAD/ HALLIBURTON SETTING TOOU 4.5" HAL FASDRILL PLUG. MAX OD= 3.66", TOOL WEIGHT= 250 LBS. IGNITOR DID NOT FIRE, PLUG DID NOT SET. POOH. RIH WITH TS: HEAD/2 -WEIGHT BARS/CCL FIRING HEAD/ HALLIBURTON SETTING TOOU 4.5" HAL FASDRILL PLUG. MAX OD= 3.66", WEIGHT= 250 LBS. SURFACE AND VISUAL CONFIRMATION OF PLUG SETTING. RIH WITH HEAD/CCL/WPSA/SHOCK MANDREL X 2/FIRING HEAD/4.15" POWER CUTTER. MAX OD = 4.15", WEIGHT = 200 LBS. ***JOB IN PROGRESS AND CONTINUED ON 22-JUL-2008 WSR*** B-18 7/21/2008 ****LOG CONTINUED FROM 20-JUL-2008"`*** CONTINUE SLB LEAK DETECTION LOG WITH LRS PUMPING. RIH WITH HEAD/2 -WEIGHT BARS/CCL FIRING HEAD/ HALLIBURTON SETTING TOOU 4.5" HAL FASDRILL PLUG. MAX OD= 3.66", TOOL WEIGHT= 250 LBS. IGNITOR FIRED, PLUG DID NOT SET. POOH. Page 2 of 3 " ~ ~ ON SETTING TOOU 4.5 2 -WEIGHT BARS/ CCL FIRING HEAD/ HALLIB RIH WITH TS: H HAL FASDRILL PLUG. MAX OD= 3.66", WEIGHT= 250 LBS. SURFACE AND VISUAL CONFIRMATION OF PLUG SETTING. RIH WITH HEAD/CCL/WPSA/SHOCK MANDREL X 2/FIRING HEAD/4.15" POWER CUTTER. MAX OD = 4.15", WEIGHT = 200 LBS. ****LOG CONTINUED ON 22-JUL-2008**** B-18 7/21/2008 T/I/O = 0/0/0. Temp = SI. Install Katch Kan in cellar (pre rig). No AL line. Installed 36" Katch Kan around conductor. Cellar liner previously installed is partially frozen to ground, will need heater & vac truck after Katch Kan is removed. MV &SSV open. WV & SV closed. IA & OA valves OTG's. B-18 7/21/2008 T/I/0= 0/0/0. Temp = SI. Assist E-Line (RWO Prep)MIT-T *PASSED* to 1000 psi. Pumped 1.2 bbls of 74* crude to achieve test pressure. Lost 40 psi / 1st 15 min & 20 psi / 2nd 15 min. Lost 60 psi during the 30 minute test. Bled back -1 bbl to FWHP= 0/0/0. Annulus casing valves are open to gauges. E-Line had well control upon our departure. B-18 7/21/2008 ****LOG CONTINUED FROM 20-JUL-2008**** CONTINUE SLB LEAK DETECTION LOG WITH LRS PUMPING. RIH WITH HEAD/2 -WEIGHT BARS/ CCL FIRING HEAD/ HALLIBURTON SETTING TOOU 4.5" HAL FASDRILL PLUG. MAX OD= 3.66", TOOL WEIGHT= 250 LBS. IGNITOR FIRED, PLUG DID NOT SET. POOH. RIH WITH TS: HEAD/2 -WEIGHT BARS/ CCL FIRING HEAD/ HALLIBURTON SETTING TOOU 4.5" HAL FASDRILL PLUG. MAX OD= 3.66", WEIGHT= 250 LBS. SURFACE AND VISUAL CONFIRMATION OF PLUG SETTING. ****JOB COMPLETE. NOTIFIED DSO OF VALVE POSITIONS.**** B-18 7/21/2008 ****LOG CONTINUED FROM 20-JUL-2008**** CONTINUE SLB LEAK DETECTION LOG WITH LRS PUMPING. RIH WITH HEAD/2 -WEIGHT BARS/CCL FIRING HEAD/ HALLIBURTON SETTING TOOU 4.5" HAL FASDRILL PLUG. MAX OD= 3.66", TOOL WEIGHT= 250 LBS. IGNITOR FIRED, PLUG DID NOT SET. POOH. RIH WITH TS: HEAD/2 -WEIGHT BARS/CCL FIRING HEAD/ HALLIBURTON SETTING TOOU 4.5" HAL FASDRILL PLUG. MAX OD= 3.66", WEIGHT= 250 LBS. SURFACE AND VISUAL CONFIRMATION OF PLUG SETTING. B-18 7/21/2008 ***WSR continued from 7/20/08*** Assist E-Line with LDL. Pump 2 bbls of crude to maintain 3500 psi during logging., MIT-T *FAILED* to 1000 psi. (3 attempts) Lost 80 psi / 1st 15 min & 80 psi / 2nd 15 min. Lost a total of 160 psi during minutes of test #3. Final WHP = 0/0/0. Annulus casing valves are open to gauges. SWS E-Line had control of the well upon our departure. B-18 7/21/2008 T/I/O = 0/0/0. Temp = SI. Eval cellar for possible gravel removal pre-Katch-Kan. Cellar is -59"deep with 10" fluid in cellar (measured C~1 tree). Conductor is 30" and gravel level is -2' below conductor top. Flutes are -14" deep with 2" fluid. Well currently has yellow cellar liner installed, will need removed prior to any gravel removal/Katch-Kan installation. Wellhead valves turned over to SLB unit currently on well. B-18 7/22/2008 ***LOG CONTINUED FROM 21-JUL-2008**'* CONTINUE TO RIH WITH HEAD/CCL/WPSA/SHOCK SUBS X 2/FIRING HEAD/4.15" POWER JET CUTTER. JET CUT 5-1/2" TBG C~3 7934'...POSITIVE INDICATION OF FIR --Fi1~TALT/17~(J7fJ7QF ****WELL LEFT SHUT-IN. DSO NOTIFIED**** B-18 7/23/2008 T/I/0= 0/80/0 Temp=S/I Circ well CMIT TxIA PASSED to 3500 psi (RWO prep) Pumped a 5 bbl neat spear followed by 824 bbls of 9.3 NaCI brine down the tubing taking returns up the IA to the flow line. Pumped 34 bbls of diesel into the tubing to freeze protect, U-Tube diesel into place. CMIT TxIA with 6 bbls of diesel. T/IA lost 40/40 psi in the 1st 15 mins, T/IA lost 20/20 psi in the 2nd 15 mins for a total loss of 60/60 psi in 30 mins. Bled pressures. Final WHP's = 0/0/0 Valve positions at time of departure: Swab closed /Wing closed /SSV closed /Master open / IA open to gauge / OA open to gauge B-18 7/24/2008 T/I/0=0/0/0. Set 6" CIW J BPV. Pre Nabors 4ES. B-18 8/1/2008 ~~ T/I/O =Vac/0/0 Pulled 6 3/8" CIW J BPV Rig 4ES move on well. B-18 8/2/2008 T/I/O = 0/0/0 Pulled 6-3/8" CIW "H" TWC #419 C~ 102" 3-5" ext. used ....post BOP test for 4ES...no problems. B-18 8/14/2008 T/I/0=0/0/0; Pull 4-1/16" CIW "H" BPV #255 thru tree for 4ES Completion; 1-2' ext. used, tagged C~3 102"; (Best/Wortham) B-18 8/14/2008 T/I/0= 0/0/0; pull 4-1/16" CIW "H" TWC #255 thru tree for 4ES Completion; 1-2' ext. used, tagged C~3 108"; (Best/Wortham) Page 3 of 3 B-18 8/15/2008 T/I/0=0/0/0; Pull 4-'716" CIW "H" BPV thru tree post 4ES; 1-2' ext. used,~gged C 102"; (Best/Wortham) B-18 8/16/2008 ***WELL S/I ON ARRIVAL*** (post rig) PULL B&R FROM X-NIP C~ 7870' MD. ULL RK-DGLV FROM # 56 8' MD, RKP-DCR GLV FROM STA #4 @ 3296' MD. ****CONT JOB ON 8-17-08**** B-18 8/17/2008 ****CONT JOB FROM 8-16-08****(post rwo) SET RK-LGLV IN STA # 4 ~ 3296' MD, RK-OGLV IN STA #3 ~ 5618' MD. PULL RHC PLUG FROM X-NIP ~ 7870' MD. TAG TD W/ 3.68" CENT, TEL, S-BAILER ~ 9220' MD. (S-BAILER EMPTY) ****WELL LEFT S/I, PAD OP NOTIFIED**** B-18 9/4/2008 ***WELL FLOWING ON ARRIVAL***(GL for rate) SET 4 1/2" WHIDDON CATCHER C~ 8071' SLM PULLED DGLV FROM STA# 1 ~ 7744' SLM PULLED DGLV FROM STA# 2 ~ 6959' SLM PULLED DGLV FROM STA# 3 ~ 5612' SLM ****CONT ON WSR 9/5/08**** B-18 9/5/2008 ****CONT FROM WSR 9/4/08**** (gl for rate) PULLED LGLV & SET LGLV IN STA# 4 C~3 3287' SLM (PORT 16/64" TRO 1677 LBS) SET LGLV IN STA# 3 C~3 5612' SLM (PORT 16/64", TRO 1679 LBS) SET LGLV IN STA# 2 ~ 6959' SLM (PORT 16/64", TRO 1669 LBS) SET OGLV IN STA# 1 C~ 7744' SLM (PORT 24/64") PULLED WHIDDON CATCHER FROM 8071' SLM (EMPTY) ****WELL TURNED OVER TO PAD-OP UPON DEPARTURE**** Print Date: 9/8/2008 Page 1 of 1 • BP EXPLORATION Operations Summary Report Page 1 of 9 Legal Well Name: B-18 Common Well Name: B-18 Spud Date: 5/11/1982 Event Name: WORKOVER Start: 8/1/2008 End: 8/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/14/2008 Rig Name: NABOBS 4ES Rig Number: Date From' - To Hours Task Code NPT Phase Description of Operations 8/1/2008 13:00 - 15:00 2.00 RIGD P PRE Scoped down and lowered derrick. 15:00 - 16:00 1.00 MOB P PRE Moved rig from B-27A to B-18. 16:00 - 18:00 2.00 MOB P PRE Laid Herculite. Spotted and bermed sub, pits, and pipe shed. Spotted camp. 18:00 - 20:00 2.00 RIGU P PRE Raised and scoped derrick. ' ' ' Accepted rig at 19:00 hrs 8/1/2008. ' ' ' RU circulating lines to tree and tiger tank. Took on hot seawater. 20:00 - 22:00 2.00 WHSUR P DECOMP RU DSM lubricator and tested to 500 si. Pull and RD lubricator. 22:00 - 00:00 2.00 KILL P DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. Held Fire Drill. Tested circulating lines to 3500 psi. Displaced well with 588 bbls hot 8.5 ppg seawater. Pumped 5 bpm, max circ pressure 1400 psi. Circulated out estimated 30 bbls diesel. 8/2/2008 00:00 - 01:00 1.00 KILL P DECOMP Continued displacing well with hot 8.5 ppg seawater. 01:00 - 01:30 0.50 KILL DECOMP Shut down pump and monitored well. Tubing and annulus dead and stable. 01:30 - 02:30 1.00 WHSUR P DECOMP Set TWC with T-Bar. Tested TWC from above to 3500 si for 10 charted minutes. Tested TWC from below to 1000 psi for 10 charted minutes. 02:30 - 05:00 2.50 WHSUR P DECOMP RD circulating lines. ND tree and adapter flange. 05:00 - 06:00 1.00 BOPSU P DECOMP NU BOPE. 06:00 - 08:30 2.50 BOPSU P DECOMP Held crew change. Serviced rig, checked PVT alarms. Continued NU BODE. RU BOPE test equipment. 08:30 - 14:00 5.50 BOPSU P DECOMP Tested BOPE to 250 si low / 3500 si hi h per BP and AOGCC requirements. Tested VBR with 3-1/2" and 5-1/2" test joints. Tested annular with 3-1/2" test joint. BOPE test witnessed by J. Crisp, AOGCC. RD BOPE test equipment. 14:00 - 16:00 2.00 WHSUR N WAIT DECOMP Waited on DSM for lubricator to pull TWC. 16:00 - 17:00 1.00 WHSUR P DECOMP RU DSM lubricator and tested to 500 psi. Pulled TWC and RD lubricator. 17:00 - 18:00 1.00 WHSUR P DECOMP MU landing joint with XO to 7" IJ4S pin. Screwed in to tubing hanger. BOLDS. Pulled tubing hanger free with 140k Ib PU. LD tubing hanger. 18:00 - 20:00 2.00 PULL P DECOMP Held crew change and performed pre-tour checks of PVT equipment and derrick. MU head pin and RU to circulate. Circulated 535 bbls seawater around from just above tubing cut depth. Required 16 bbls to fill well, then lost 4 bbls during circulation. Pumped 5 bpm and 150 psi. Shut down and monitored well; well stable. 20:00 - 00:00 4.00 PULL P DECOMP POH and LD 5-1/2" tubing. Spooled dual control lines and braided cable. Used pneumatic chisel on control line clamps. 47 jts LD at 00:00 hrs. 8/3/2008 00:00 - 06:00 6.00 PULL P DECOMP Continued POH and LD 5-1/2" tubing. RD control line spooling unit after jt #48. Recovered 23 plastic control line clamps and 5 ss bands. 135 jts LD at 05:00 hrs. 06:00 - 06:30 0.50 PULL P DECOMP Crew change. Service Rig. Check PVT alarms. Inspect Derrick. 06:30 - 09:30 3.00 PULL P DECOMP Finish laying down 5 1/2" completion. Recovered 179 Jts 5 1/2" Tubing, SSSV, 13 GLMs, SS, and a 9.24-ft jet cut stub. Jut cut flare =normal. Clean and clean floor. 09:30 - 10:30 1.00 PULL P DECOMP Hold weekly safety meeting with Crew, TP, and WSL. 10:30 - 11:30 1.00 CLEAN P DECOMP Install Wear Bushing (ID = 9 1/8"). Bring BHA tools to Pipe Printed: 9/2/2008 11:47:36 AM BP EXPLORATION Page 2 of 9 Operations Summary Report Legal Well Name: B-18 Common Well Name: B-18 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date From - To Hours Task Code NPT 8/3/2008 10:30 - 11:30 1.00 CLEAN P 11:30 - 14:00 2.50 CLEAN P 14:00 - 16:00 2.00 CLEAN P 16:00 - 17:30 1.50 CLEAN P 17:30 - 18:00 0.50 CLEAN P 18:00 - 21:00 3.00 CLEAN P 21:00 - 22:00 1.00 CLEAN P 22:00 - 22:30 0.50 CLEAN P 22:30 - 00:00 1.50 CLEAN P 8/4/2008 00:00 - 02:30 2.50 GLEAN P 02:30 - 05:30 3.00 CLEAN P 05:30 - 06:00 0.50 CLEAN P 06:00 - 07:00 1.00 CLEAN P 07:00 - 08:00 1.00 CLEAN P 08:00 - 09:00 1.00 EVAL P 09:00 - 14:00 5.00 EVAL P 14:00 - 14:30 0.50 EVAL P 14:30 - 16:00 1.50 EVAL P Spud Date: 5/11 /1982 Start: 8/1 /2008 End: 8/14/2008 Rig Release: 8/14/2008 Rig Number: Phase Description of Operations DECOMP Shed. Rig up to handle BHA. DECOMP Make up BHA #1 as follows: 8 1/2" x 5.625" Dress-Off Shoe, 3 ea WP EM (16-ft swallow), (4 7/8" Tbg Dress Mill up inside WP), Washover Boot Basket, XO, 9 5/8" Casing scraper, Bit Sub, Bumper Jar, XO, 6 ea 6 1/4" drill Collars, XO, Pump-Out-Sub. DECOMP RIH with BHA #1 and single in with 3 1/2" drill Pipe from Pipe Shed. Stop with 73 joints picked up. DECOMP PJSM. Cut and slip Drilling Line (84'). DECOMP Resumed RIH with BHA #1, picking up 3-1/2" DP. DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. Continued RIH with BHA #1. DECOMP Held weekly safety meeting with all rig personnel. Discussed Safety Alerts, recent incidents, rig ops performance, and individuals' concerns. DECOMP Continued RIH with BHA #1. DECOMP Ta ed 5-1/2" tubin stub 7 '. PU kelly and established parameters: PU 140k Ib, SO 125k Ib, Rot 133k Ib, 60 rpm, 130a, 2900 Ib-ft, 4 bpm, 515 psi, 1-3k Ib WOB. Rotated and milled over stub with shoe. Continued rotating over stub, swallowed 18'. Increased WOB to 5k Ib. Dressed 1' to mill de th of 7926'. Shoe depth 7944'. PU above stub and made two unrestricted passes to mill depth of 7926', with and without rotation. DECOMP Pumped 40 bbl high-vis sweep. Reverse circulated around until clean returns. Sand, metal and rubber pieces in returns. Pumped total of 640 bbls at 4 bpm and 1100 psi. DECOMP POH with dress-off BHA #1, standing back 3-1/2" DP. DECOMP Lay down BHA #1. Stop for Crew change. DECOMP Crew change. Check PVT alarms. Inspect Derrick. Spot SWS E-line Unit. DECOMP Lay down BHA #1. TIEB1 PJSM. Rig up SWS E-Line equipment and tools. TIEB1 RIH with USIT to in suite. Log well from 4,050' back to surface. Field TOC pick at 2,150'. Rig down SWS. Send log results to Anchorage Engineer. TIE61 Pick-up Halco Running Tool and 9 5/8" RBP. TIEB1 RIH with RBP and 3 1/2" Drill Pipe. Set RBP with the center element at 2.150'. Top of RBP at 2.145'. 16:00 - 16:30 0.50 EVAL P TIEB1 Pressure test RBP at 1 000 six 10 minutes. Record on chart. 16:30 - 18:00 1.50 EVAL N HMAN TIEB1 Dumped 25 sk 20/40 mesh sand on RBP. Discovered error in RBP setting depth; RBP inadvertently set 100' high at 2150'. 18:00 - 18:30 0.50 EVAL N HMAN TIEB1 Held crew change and performed pre-tour checks of PVT system and derrick. Reverse circulated and washed sand 2093' - 2145' (TOFN). Reversed 130 bbls seawater at 5 bpm and 370 psi, until clean returns. 18:30 - 19:30 1.00 EVAL N HMAN TIEB1 Engaged 9-5/8" RBP at 2145'. Released RBP. RIH 2 stands, reset at 2250 COE 2245' TOFN. Released from RBP and POH 2 stands. 19:30 - 23:30 4.00 EVAL P TIE61 Pressure tested 9-5/8" RBP to 1000 si for 10 charted minutes. Good test. Dumped 44 sk 20/40 mesh sand dawo_3-1/2" DP and allowed to settle on RBP. Cleared drill pipe with 15 bbls seawater. RIH and tagged sand at 2198' DPM. Printed: 9/2/2008 11:47:36 AM • • BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: B-18 Common Well Name: B-18 Spud Date: 5/11/1982 Event Name: WORKOVER Start: 8/1/2008 End: 8/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/14/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To III Hours '.Task Code's NPT II Phase ~ Description of Operations 8/4/2008 23:30 - 00:00 0.50 EVAL P TIEB1 POH with RBP setting tool, standing back 3-1/2" DP. 8/5/2008 00:00 - 01:00 1.00 EVAL P TIEB1 Continued POH with RBP setting tool. LD setting tool and cleared floor. 01:00 - 04:00 3.00 EVAL P TIEB1 PU 9-5/8" casin cutter BHA #2: multi-string cutter, stabilizer, XOs, 6 x DC. Blade retaining wire repositioned on cutter and blades duct taped to prevent premature blade extension. RIH on 22 stands 3-1/2" DP. Pumped 3-1/2 bpm to extend blades. Located casing joint gaps at 2097' and 2136'. Placed cutter blades at 2120' DPM nd established parameters: PU 54k Ib, SO 54k Ib, Rot 53k Ib, 60 rpm, 60 a, 1100 Ib-ft, 3-1/2 bpm, 100 psi. Increased pump rate to 5-1/2 bpm and 800 psi. Torque increased to 150 a, 3000 Ib-ft, and lost 300 psi pressure after about 10 minutes rotation. Continued rotation for 15 additional minutes. Stopped rotation and reciprocated cutter to confirm cut. 04:00 - 06:00 2.00 CASE P TIEB1 RU to take returns from OA. Attempted to establish circulation throw h cut and u OA immediate) observed fluid retur into well cellar. Shut down pump, fluid returns continued into cellar. Positioned vac truck to evacuate cellar. Began pumping OA fluid from cellar; fluid returns stopped. 06:00 - 07:00 1.00 CASE P TIE61 Crew change. Service Rig. Inspect Derick. Check PVT alarms. Re-position Lil' Red Hot Oil Unit. Off-load second Vac Truck with hot 9.8 Brine in Pits. 07:00 - 16:30 9.50 CASE P TIEBi LRS start 140 deg diesel at 1 bpm. fluid returns in cellar after 13 bbls pumped. Continue at 1 bpm and allow returns to stabilize in cellar. Starting to get returns from OA in containment tank. Had to reduce rate to 0.5 bpm several time when cellar returns started to getting gas-cut. Shut down diesel with 70 bbls pumped. Start hot 9.8 Ib/gal Brine with Rig Pump at 1.0 bpm. Tried to increase rate to 1.5 bpm several times. However celar returns still gas cut. Returns = 60% cellar, 40% containment tank. End 9.8 Ib/gal Brine with 50 bbls pump. Pump a 20 bbl 9.8 Ib/gal Hi-Vis pill. Shut down and let hot fluids soak. Total bbls pumped = 140. Total bbls recovered 160. Returns =thin Arctic Pack, diesel, and a brown colored fluid. Resume circulations. Second Vac Truck on location. Put two Vac trucks on cellar. Bring Rig Pump on line with hot 9.8 Ib/gal Brine at 1 bbl/min. Returns in cellar after 2.5 bbls pumped. Walk rate up to 6.0 bpm/900 psi. Pump a total of 140 bbls 9.8 Ib/gal Brine. Shut down and let hot Brine soak. Recovered thin Arctic Pack, Diesel, brown fluid, Brine. Pumped 140 bbls recovered 150 bbls. Returns 70 containment tank, 30% Vac Trucks. Resume circulations. Bring LRS on with 140 deg Diesel at 1.5 bpm. End diesel with 50 bbls pumped. Bring Rig pump on line and pump a 20 bbl 9.8 Ib/gal Hi-Vis pill. Displace diesel and Hi-Vis pill with 140 bbls of 9.8 Ib/gal Brine at 5.0 bpm/750 psi. Returns =diesel, thin Arctic Pack, dirty brine. 16:30 - 18:00 1.50 CASE P TIE61 Close OA Valve. Open Hydril. Circulate bottoms up with 9.8 Ib/gal Brine and take Sea Water returns to Tiger Tank. 18:00 - 20:30 2.50 CASE P TIE61 Held crew change and performed pre-tour checks of PVT system and derrick. POH with casing cutter BHA #2, standing. back 3-1/2" DP and 6~x DC. LD BHA #2. Pulled wear ring, Printed: 9/2/2008 11:47:36 AM • BP EXPLORATION Operations Summary Report Page 4 of 9 Legal Well Name: B-18 Common Well Name: B-18 Spud Date: 5/11/1982 Event Name: WORKOVER Start: 8/1/2008 End: 8/14/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/14/2008 Rig Name: NABORS 4ES Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 8/5/2008 18:00 - 20:30 2.50 CASE P TIEB1 cleared rig floor. 20:30 - 22:30 2.00 CASE P TIE61 MU 9-5/8" casing spear ass'y and stood back in derrick. RU casing handling equipment. 22:30 - 00:00 1.50 CASE N WAIT TIE61 Waited for delivery of 9.8 ppg brine. 8/6/2008 00:00 - 02:00 2.00 CASE N WAIT TIEB1 Continued waiting for delivery of 9.8 ppg brine. 02:00 - 03:30 1.50 CASE P TIEB1 Loaded 9.8 ppg brine in pits. 03:30 - 06:00 2.50 WHSUR P TIE61 RIH, speared casing hanger and set grapple. BOLDS on casing hanger. PU 225k Ib, casing hanger would not come free. Wrapped and steamed wellhead. Continued pulling with max PU 260k Ib. 06:00 - 06:30 0.50 WHSUR P TIE61 Crew change. Inspect Derrick. Service Rig. Check PVT alarms. Continue to monitor cellar. 06:30 - 07:30 1.00 WHSUR P TIEB1 Continue to wotk to pull 9 5/8" Casino Hanoer free. Dead gull 07:30 - 09:30 2.00 WHSUR C TIEB1 Lay down Spear assembly. Pick up pick-up pack-off release tool. Attempted to pull 9 5/8" pack-off. Worked to pull pack-off free. Pull up to 80K per Cameron Rep. No joy. End steaming Wellhead. Cameron Rep pulled all lock down pins one at a time to inspect for broken pins. None were found. Pins were re-installed in the correct "backed out" position. 09:30 - 10:00 0.50 WHSUR C TIE61 Submit and discuss plan forward to jar hanger free with Anchorage Eng. 10:00 - 11:30 1.50 WHSUR C TIE61 PJSM. Make u surface 'ar tool strin as f II :Casing Spear, Oil Jar, 1 ea 6 1/4" Drill Collar, Accelerator Jar, 3 1/2" Drill Pipe Pup Joint (S-135 Grade), TIW Valve. 11:30 - 16:00 4.50 WHSUR C TIEB1 Plant Casing Spear. Begin jarring to free Casing hanger. Tripping jars at 50K and work up to 90K to un-seat Hanoer. No 'our. Discuss higherjaring parameters with Anch Eng. C ntinue to tri 'ors to un-seat Han er at 10 K d rk to 150K. Han er remains stuck Total 'ar licks = 210. Accelerator Jar starting to leak. Stop further jarring. Inspect Derrick. Discuss next option with Anch Eng. 16:00 - 17:00 1.00 WHSUR C TIEB1 Disengaged spear. LD spear ass'y. Discovered bull nose off casings ear lost in hole. Lost " OD x 1.33' Ion . 17:00 - 18:00 1.00 BOPSU C TIE61 Waited for instructions. 18:00 - 18:30 0.50 BOPSU C TIE61 Held crew change and performed pre-tour checks of PVT system. Re-inspected derrick, continued waiting for instructions. 18:30 - 23:00 4.50 BOPSU C TIEBi Split stack below tubing spool. PU stack, 9-5/8" casing pack-off lifted with spool. Set stack down, ND BOPE from top of tubing spool. Set back BOPE. Removed old tubing spool with pack-off and replaced with new spool without pack-off. Set test plug in tubing spool. Notified AOGCC at 22:15 hrs of upcoming BOPE body test. C. Scheve (AOGCC) waived test witness. 23:00 - 00:00 1.00 BOPSU C TIEB1 NU BOPE. 8/7/2008 00:00 - 00:30 0.50 BOPSU C TIEB1 Continued NU BOPE. 00:30 - 02:30 2.00 BOPSU C TIEB1 Tested BOPE break to 250 psi low / 3500 psi high. Discovered pinhole-sized leak in mud line. About 1/2 gal 9.8 ppg brine leaked to secondary containment. Made all Level '0' notifications. Traction No. 2008-IR-2741334. Pulled test plug. 02:30 - 04:00 1.50 WHSUR C TIEB1 MU 9-5/8" casing spear. Engaged grapple. Pulled casing hanger to rig floor with 102k Ib PU. Printed: 9/2/2008 11:47:36 AM BP EXPLORATfON Page 5 of 9 Operations Summary Report Legal Well Name: B-18 Common Well Name: B-18 Spud Date: 5/11/1982 Event Name: WORKOVER Start: 8/1/2008 End: 8/14/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/14/2008 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/7/2008 04:00 - 06:00 2.00 CASE C TIE61 Disengaged and LD spear. Broke out and LD casing hanger 06:00 - 06:30 0.50 CASE P TIE61 06:30 - 16:00 9.50 CASE P TIEB1 16:00 - 16:30 0.50 CASE P TIEB1 16:30 - 18:00 1.50 CASE P TIEB1 18:00 - 19:30 1.50 FISH N DPRB TIEB1 19:30 - 21:30 I 2.001 FISH I N I DPRB I TIEB1 8/8/2008 21:30 - 23:00 I 1.501 FISH I N I DPRB I TIE61 23:00 - 00:00 1.00 FISH N DPRB TIEB1 00:00 - 01:30 1.50 FISH N DPRB TIEBi 01:30 - 03:30 2.00 FISH N DPRB TIEB1 03:30 - 04:00 0.50 FISH N DPRB TIE61 04:00 - 06:00 2.00 FISH N DPRB TIE61 06:00 - 06:30 0.50 FISH N DPRB TIEB1 06:30 - 08:00 1.50 FISH N DPRB TIEB1 08:00 - 08:30 0.50 FISH N DPRB TIEB1 08:30 - 09:30 1.00 FISH N DPRB TIEBi 09:30 - 10:00 0.50 FISH N DPRB TIEB1 10:00 - 11:30 1.50 FISH N DPRB TIEBi 11:30 - 13:00 1.50 CASE P TIEB1 13:00 - 14:30 I 1.501 CASE I P I ITIEBI 14:30 - 16:00 I 1.501 CASE I P I I TIE61 16:00 - 18:15 I 2.251 CASE I P I ITIEBI No visible marks on hanger. RU 9-5/8" casing handling equipment. Crew change. Service Rig. Inspect Derrick. Test PVT alarms. Maintain watch on cellar. Lav down 9 5/8. 47 Ib/ft. L-80. BTC Casino. Recovered 53 'oi inta and a 26.40' cut-off stub. Cut was "texbook". Rig down casing handling equipment. Clear and clean floor. Held crew change and performed pre-tour checks of PVT system and derrick. PU fishing magnet BHA #3: 8" cut lip magnet, bit sub, bumper jar, XO, POS. RIH with BHA #3 on 23 stands 3-1/2" DP. Tagged 9-5/8" casing stub at 2120'. Manually rotated into stub. Had fluid returns to well cellar. PU kelly. PU/SO/Rot 43k/43k/43k, 20 rpm, 45a, 900 Ib-ft. Tagged fish at 2196', SO 5k Ib. POH with fishing magnet BHA #3. No recovery. LD magnet ass'y. PU RCJB BHA #4: RCJB, bit sub, bumper jar, X0, POS. RIH with RCJB BHA #4 on 3-1/2" DP. Continuing to take fluid returns to cellar. Evacuating cellar with vac truck. Repaired mud pump fluid end seal. Tagged fish or sand top at 2196'. Dropped ball, rotated and washed to 2203'. Pumped 6 bpm at 800 psi, rotated 90a, 1900 Ib-ft. POH with RCJB BHA #4. LD BHA #4, cleared RCJB, no recove .discuss plan forward with Anch Eng. Crew change. Service Rig. Inspect Derrick, Check PVT alarms. Maintain cellar watch. Re-run BHA #4. RIH with RCJB. PUW = 43K. SOW = 43K. Amps = 60. RPMs = 52. Pick up Kelly. RWT = 45K. Wash and rotate down to TOS at 2,204-ft. Reduce pump rate to 0.5 bpm. Rotate into sand down to 2,209'. Stalled out and pressured up. Pulled free. Back surge pressure from Drill Pipe. Pull up hole . Re-establish circulations. POOH. Break down RCJB. Fish recovered complete. Lay down BHA #4. Cler and clean rig floor. Make-up BHA #5 as follows: 12" x 9 5/8" Dress-off shoe, W P Ext, Csg Dress Mill (inside Ext), washover Boot Basket, XO 13 3/8" Casing scraper, XO, Bumper Jar, XO, float sub, 6 ea 6 1/4" Drill collars, XO. TIH with BHA #5 and 3 1/2" Drill Pipe to 1150-ft. Mix and pump a 40 bbls 9.8 Ib/gal Brine Hi-Vis sweep. Chase to surface with 9.8 Brine. Returns to cellar via 13 3/8" x Conductor continue. Continue to TIH. Pick-up Kelly. RTW =55K, Amps = 90, Pump Rate = 3.5 bpm/150 psi. Tag top of 9 5/8" stum at 2 120-ft. Dressed off top of Casing to 2,121- wallowed 8-ft down to 2,129-ft. Returns in Cellar bridged-off and quit. Circulate and condition well bore. Mix and pump 20 bbl 9.8 Ib/gal Brine Hi-Vis pill. Swap over to hot 1 %KCL Water. Mix a 40 bbl Safe-Surf-O pill and chase to surface with hot 1 %KCL Printed: 9/2/2008 11:47:36 AM • BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: B-18 Common Well Name: B-18 Spud Date: 5/11/1982 Event Name: WORKOVER Start: 8/1/2008 End: 8/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/14/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To I' Hours Task Code I NPT Phase I' Description of Operations 8/8/2008 16:00 - 18:15 2.25 CASE P TIE61 Water until well cleaned up. 18:15 - 20:30 2.25 CASE P TIE61 Held crew change and performed pre-tour checks of PVT system and derrick. POH with dress-off BHA #5, standing back 3-1/2" DP. 20:30 - 22:00 1.50 CASE P TIE61 Stood back DC. LD BHA #5. Cleared boot basket. 22:00 - 23:30 1.50 CASE P TIEB1 Cleared and cleaned rig floor of Arctic Pack solids. 23:30 - 00:00 0.50 CASE P TIEB1 PUMU 13-3/8" RTTS. 8/9/2008 00:00 - 02:00 2.00 CASE P TIEB1 RIH with 13-3/8" RTTS on 20 stands + single 3-1/2" DP. 02:00 - 04:00 2.00 CASE P TIEB1 Set RTTS at 2113' COE. RU head pin and line. Tested 13-3/8" casina shoe to 2000 psi for 30 charted minutes. 04:00 - 06:00 2.00 CASE P 06:00 - 06:30 0.50 CASE P 06:30 - 07:00 0.50 BOPSUFj P 07:00 - 13:30 6.50 BOPSU P 13:30 - 14:00 0.50 BOPSUF~ P 14:00 - 15:00 1.00 CASE P 15:00 - 18:00 3.00 CASE P 18:00 - 22:00 4.00 CASE P 22:00 - 00:00 2.00 CASE ~ P 8/10/2008 100:00 - 01:30 I 1.50 I CEMT I P 01:30 - 02:30 I 1.00 I CEMT I P 02:30 - 04:30 I 2.001 CEMT I P Pressure ell about 200 psi in 20 minutes. RD pump-in line and head pin. Unset RTTS. TIEB1 POH with RTTS, standing back 3-1/2" DP. LD RTTS., TIE61 Crew change. Service rig, Inspect derrick. Check PVT alarms. Maintain cellar watch. TIEB1 Install test plug. RILDS. TIE61 Rig up test equipment. Test BOPE per BP/AOGCC requirements at 250/3500 psi. Tested VBPRs with 3 1/2" and 4 1/2" Test Joints. Tested Hy-Dril with 3 1/2" Test Joint. State's right to witness test was waived by C. Scheve 18:45 hrs 8/7/2008. TIE61 BOLDS. Pull Test Plug. TIE61 Rig up to handle 9 5/8" Casing. Rig up Torque Turn equipment. TIEB1 Run 9 5/8" Casin as follows 9 5/8" Bowen Casing Patch, Pup Joint, Halco ES Stage Cementer, XO Joint, 53 Jts 9 5/8" 47 bl/ft L-80 Hydril 563 Cond B Casing. Baker-Lok ES Cementer threads. TIE61 Continued RIH with 9-5/8" 47# L-80 Hydril 563 tieback casing. Ran total of 53 jts and 52 centralizers. PU 98k Ib, SO 96k Ib. Slowly rotated over and engaged overshot. Bottomed out on casing stub and SO 25k Ib. PU 30k Ib over neutral to set grapple. PU total of 250k Ib to confirm set. SO to 200k Ib, holding 100k overpull tension. TIE61 RD casing handling equipment. RU cementing head and lines. Pressure tested 9-5/8" tieback to 2000 psi for 30 charted minutes. Good test. Increased pressure to 2600 psi to shear open ES cementer. Established circulation through cementer ports with warm 1 %KCI brine, at 5 bpm and 125 psi. TIEB1 Moved in and spotted SWS cementing equipment. Spotted vac trucks for fluid and returns. Laid and MU cementing lines. Circulated 1 %KCI through ES cementer to warm wellbore. TIEB1 Held pre-cementing safety meeting with all rig personnel and contractors. Continued RU cementing equipment. TIE61 Tested cement lines to 4000 psi. Cemented 9-5/8" tieback casing with 155 bbls CI G cement + additives. Pump pressure 370 - 350 psi while pumping cement at 5 bpm. Released plug, saw tattle tale move. SWS displaced cement with 1%KCI brine at 5 bpm. Caught cement at 65 bbls displacement. Began getting cement returns to cellar at 115 bbls displacement. Max displacement pressure 1055 psi. At 145 bbls displacement reduced pump rate to 2 bpm and pressure to 875 psi. Reduced OA valve opening to force good cement Printed: 9/2/2008 11:47:36 AM • • BP EXPLORATION Page 7 of 9 Operations Summary Report Legal Well Name: B-18 Common Well Name: B-18 Spud Date: 5/11/1982 Event Name: WORKOVER Start: 8/1/2008 End: 8/14/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/14/2008 Rig Name: NABORS 4ES Rig Number: Date From - To Hours ! Task Code NPT Phase Description of Operations 8/10/2008 02:30 - 04:30 2.00 CEMT P TIEB1 04:30 - 06:00 I 1.501 CEMT I P 06:00 - 07:00 1.001 WHSUR P 07:00 - 09:00 2.00 CASE P 09:00 - 12:00 3.00 WHSUR P 12:00 - 14:00 2.00 BOPSU P 14:00 - 15:00 1.00 CASE P 15:00 - 15:30 0.50 CASE P 15:30 - 18:00 2.50 CASE P 18:00 - 19:30 1.50 DRILL P 19:30 - 21:00 21:00 - 22:00 22:00 - 00:00 8/11/2008 00:00 - 00:30 00:30 - 01:30 01:30 - 02:30 02:30 - 04:00 1.50 DRILL P 1.00 DRILL P 2.00 CASE P 0.50 CASE P 1.00 CASE P 1.00 CASE P 1.50 CASE P TIEB1 TIEB1 TIEB1 TIEBi TIEB1 TIE61 TIE61 TIE61 TIE61 TIE61 TIE61 TIEB1 TIEB1 TIEB1 TIE61 TIEB1 into conductor annulus and cellar. Reduced pump rate to 1 bpm, had about 15 bbls uncontaminated cement returned to cellar. Bumped plug at 159.5 bbls displacement (4.5 bbls over calculated volume) and increased pressure to 2500 psi. Held pressure for 5 minutes. Released pressure, bled 1-1/2 bbls back to cementers. CIP at 04:00 hrs. Blew down cementing lines. Sucked out BOPE. RD cementing equipment. Collected all cellar and catch tank fluids for disposal. Crew change. (Cement top seen in the 13 3/8" x Conductor Annulus at surface. Unable to see cement top in the 9 5 8" x 13 3/8" Annulus). fipple down Choke and Kill Lines. Pick-up BOP Stack and Spool. Install slips and set with 100k tension. Rig up WACHS cutter. Cut 9 5/8" Casing per Cameron Rep. Rig down cutter. Lay down a 17.14' 9 5/8" Casing stub. Install new 9 5/8" Pack-Off. RILDS. Nipple up Spool and BOP Stack. Test Spool void at 3,800 psi x 30 minutes. Good test. (Compressive strength of the cement at 11:15 hrs = 301 psi) Install test plug. Fill stack. Rig up test equipment. Body test BOP stack at 250/3,500 psi per BP/AOGCC requirements, Record on chart. State's right to witness test was waived by C. Scheve. Pull test plug. Install Wear Bushing. Hold Weekly Sunday Safety Meeting with all. Pick-up BHA #6 as follows: 8 1/2" Blt, 2 ea Boot Baskets, Bit sub, Oil Jar, XO, 6 ea 6 1/4" drill Collars, XO, Pump-Out- Sub. (Compressive strength of cement at 15:30 hrs = 693 psi). TIH with BHA #6 and 3 1/2" drill Pipe. Pick-up Kelly. Parameters as follows: PU/SO/Rot 55k/55k/55k, 60a, 1100 Ib-ft, 50 rpm, 3 bpm, 100 psi. Tagged cement at 2104'. Held crew change and performed pre-tour checks of PVT system and derrick. Drilled cement 2104' - 2127'. WOB 5k-6k Ib. Pumped 3-1/2 bpm, 140 psi. Rotated up to 84 rpm, 80a, 1900 Ib-ft. PU 3 singles. Rotated and washed 2127' to hard sand at 2206'. Pumped 3-1/2 bpm, 150 psi. Dry drilled on hard sand 2206' - 2208'. Pumped 40 bbl high-vis sweep around and reciprocated pipe. Had sand, cement and metal shavings in returns. Pumped 6 bpm and 400 psi. Closed VBR. Pressured up to 3500 psi to test tieback. Discovered pinhole sized leak in mud line. Bled pressure. About 5 gallons 1 % KCI brine released to secondary containment. Made all Level '0' notifications and cleaned up leaked fluid. Traction No. 2744644. Polar bear made way onto pad, then moved off toward CPS, attracting quite a bit of attention and traffic along the way. Resumed test of 9-5/8" tieback to 3500 psi for 30 charted minutes. Good test. Held weekly safety meeting with night rig personnel. Discussed recent incidents, STOP cards, and rig performance. POH with drill-out BHA #6, standing back 3-1/2" DP. Stood back drill collars. LD BHA #6. Cleared junk basket. Cleared and cleaned rig Printed: 9/2/2008 11:47:36 AM • • BP EXPLORATION Page 8 of 9 Operations Summary Report Legal Well Name: B-18 Common Well Name: B-18 Spud Date: 5/11/1982 Event Name: WORKOVER Start: 8/1/2008 End: 8/14/2008 Contractor Name: NABOBS ALASKA DRI LLING I Rig Release: 8/14/2008 Rig Name: NABOBS 4ES Rig Number: Date ;From - To Hours Task- Code NPT Phase , Description of Operations 8/11/2008 02:30 - 04:00 1.50 CASE P TIEB1 floor. 04:00 - 06:00 2.00 CASE P TIEB1 PU RCJB BHA #7: RCJB, boot baskets, 9-5/8" scraper, bit sub, oil jar, XO, 6 x DC, XO, POS. 06:00 - 07:00 1.00 CASE P TIEB1 Crew change. Service Rig. Inspect Derrick. Check PVT Alarms. 07:00 - 07:30 0.50 CASE P TIE61 TIH with BHA #7 RCJB #1 and 3 1/2" Drill Pipe. 07:30 - 09:00 1.50 CASE P TIEB1 Pick-up Kelly. PUW = 55K, SOW = 55K, RTW = 56K, Amps = 80, RPMs = 64. Tag Top of sand at 2,208'. Wash and rotate 09:00 - 10:30 1.50 CASE P 10:30 - 11:30 1.00 CASE P 11:30 - 12:30 1.00 CASE P 12:30 - 13:30 1.00 CASE P 13:30 - 14:00 0.50 CASE P 14:00 - 15:00 1.00 CASE P 15:00 - 18:00 I 3.001 CASE I P 18:00 - 20:00 2.00 CASE P 20:00 - 22:00 I 2.00 I CASE I P 22:00 - 00:00 2.00 CASE P 8/12/2008 00:00 - 01:00 1.00 CASE P 01:00 - 03:30 2.50 CLEAN P 03:30 - 06:00 2.50 CLEAN P 06:00 - 06:30 0.50 CLEAN P 06:30 - 09:00 2.50 CLEAN P 09:00 - 12:30 3.50 CLEAN P 12:30 - 20:30 8.00 CLEAN P 20:30 - 22:30 2.00 CLEAN P 22:30 - 00:00 1.50 CLEAN P 8/13/2008 00:00 - 02:00 2.00 BUNCO TIE61 Set back Kelly. Start Trip out. Tubing still plugged. Drop ball and open pump-out sub. Continue TOH. TIEB1 .Lay down RCJB and Boot Baskets and clean out. Recovered several pieces of cast, brass, and rubber. Also cleaned out gummed-up sand. TIEB1 Clean flo d make u RCJB for run #2 BHA #8). TIE61 Trip in with RCJB #2 and 3 1/2" Drill Pipe. TIEB1 Pick-up Kelly and tag top of sand at 2,210'. Wash and rotate down to 2,230'. TIE61 Reverse in with a 20 bbls Hi-Vis sweep. Reverse circulate ar 4.6 bpm/1500 psi. Recovered much 20/40 mesh sand and a few bit of rubber. TIE61 POH with RCJB BHA #8. Stood back 3-1/2" DP and DC. LD BHA and cleared boot baskets. Recovered few metal and rubber pieces. TIEB1 Held crew change and performed pre-tour checks of PVT equipment and derrick. Cleared rig floor. PU RBP retrieving tool. RIH on 23 stands + double 3-1/2" DP. TIEB1 MU head pin and closed annular. Reverse circulated and washed 2233' - 2245'. Reversed around 20 bbl high-vis sweep. Some Arctic Pack in returns. Pumped 5 bpm and 700 psi. Held Fire Drill in pits. TIEB1 PU/SO 40k/40k. Engaged RBP at 2245'. PU 35k Ib over string weight to release RBP. CBU from 2245' at 5 bpm and 350 psi. POH with RBP on 3-1/2" DP. TIE61 BO and LD 9-5/8" RBP. Cleared rig floor. DECOMP RU to handle 2-7/8" PAC DP and shear-out guide. PU tubing slug mill BHA #9; 3-5/8" mill, shoe, TSWP bushing, shear guide, 8 x PAC DP, XOs, boot baskets, bit sub, bumper jar, oil jar, XO, 6 x DC, XO, POS. DECOMP RIH with tubing plug mill BHA #9 on 3-1/2" DP. DECOMP Crew change. Rig service. Inspect Derrick. Check PVT alarms. DECOMP Cont RIH w/ BHA. Tag fill ~ 7986'. DECOMP Rotate & mill from 7986' to 8030'. Cont to push 3 5/8" mill thru 4 1/2" tail to 8156'. PUW = 139K, SOW = 125K. Rotate ~ 4000 ft-Ibs, 53 RPM, WOB = 3-5K. Pump rate 3 BPM ~ 521 psi. Nothing over shakers while milling. Well went on vac. Maintain continuous hole fill ~ 60 bbls/hr. DECOMP POH. LDDP while maintaining 60 bbl/hr. DECOMP L/D PAC pipe & BHA. Recovered 3 gallons of sand and fine fibers. DECOMP Clear rig floor. Pull wear ring. R/D drill pipe equipment. RUNCMP R/U 4 1/2" chrome completion equipment. Printed: 9/2/2008 11:47:36 AM • BP EXPLORATION Page 9 of 9 Operations Summary Report Legal Well Name: B-18 Common Well Name: B-18 Spud Date: 5/11/1982 Event Name: WORKOVER Start: 8/1/2008 End: 8/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/14/2008 Rig Name: NABOBS 4ES Rig Number: i Date From - To 'Hours Task I'I Code ~, NPT I' Phase Description of Operations 8/13/2008 02:00 - 06:00 4.00 BUNCO RUNCMP PJSM with all crews. MU &RIH w/ 4 1/2" 13Cr80 Vam-Top completion. MU torque = 4440 ft-Ibs. RIH w/ 25 jts. High winds slowing stabbing of connections. 06:00 - 07:00 1.00 BUNCO RUNCMP Service Rig. Inspect derrick, check PVT alarms. 07:00 - 16:00 9.00 BUNCO RUNCMP Con't to RIH w/ 4 1/2" 12.6" 13Cr-80, Vam To tubin .Ran total of 180 jts. P/U Wt = 106K, S/O Wt = 96K. 16:00 - 16:30 0.50 BUNCO RUNCMP P/U jt # 181 & go down over tubing stub. Saw shear pins go ~ 6K over. Con't in stack out & P/U & re-verify taa C«~ 7932'. P/U 2' & perform space out. MU 10' pup & install below Jt # 180. M/U landing jt & tubing hanger. 16:30 - 17:00 0.50 BUNCO RUNCMP Land TBG hanger. RILDS. LD landing joint. 17:00 - 19:00 2.00 BUNCO RUNCMP RD torque turn equipment. RU lines in cellar to reverse circulate. Spot & RU brine trucks. 19:00 - 20:00 1.00 BUNCO RUNCMP C/O pop-off valve on mud pump -leaking by. Test to 3500 psi. 20:00 - 23:00 3.00 BUNCO RUNCMP Circulate inhibited seawater ~ 3 BPM / 50 psi. Circulated 490 bbls of inhibited seawater. 23:00 - 00:00 1.00 BUNCO RUNCMP Drop Ball & Rod. Pressure up on TBG. Gland nuts leaking. C/O gland nut packing. 8/14/2008 00:00 - 02:30 2.50 BUNCO RUNCMP Set packer & test tubing to 3500 psi for 30 min. Bleed tubing to 500 psi. ressure to si or min. sheared DCR ~ 2400 psi differential. Circulate thru port 3 BPM both ways. Entire test charted. 02:30 - 03:00 0.50 BUNCO RUNCMP FMC dry rod TWC. Test above & below for 10 min -charted. 03:00 - 05:00 2.00 BOPSU P RUNCMP P M. 3 1 ' x 6" VBR to 2 7/8" x 5" VBR. 05:00 - 06:30 1.50 BOPSU P RUNCMP ND B E. Set BOP in cradle and secure. Noticed some bubbles in the annulus 06:30 - 09:00 2.50 WHSUR P RUNCMP N/U adapter flange & X-mas tree. Pressure tested hanger void to 5000 psi for 30 min. Filled & tested tree to 5000 psi. 09:00 - 10:00 1.00 WHSUR P RUNCMP P/U lubricator & test to 500 psi, Ok. Pull TWC, L/D TWC & lubricator. 10:00 - 11:30 1.50 BUNCO RUNCMP R/U LRS & pressure test lines to 2500 psi. Pump down IA & freeze protect well w/ 150 bbls of diesel. Pumped 2 BPM ~ 350 psi. 11:30 - 12:30 1.00 BUNCO RUNCMP R/U & allow well to U-tube from IA to Tubing. 12:30 - 13:00 0.50 WHSUR P RUNCMP Install BPV w/ T-bar. Pressure test BPV w/ 1000 psi for 10 min. Charted test. 13:00 - 14:00 1.00 WHSUR P RUNCMP Blow down & remove lines. Secure well & cellar. ELE~i ASE RIG C~3 1400 hrs. Printed: 9/2/2008 11:47:36 AM 08/25/08 \` ~~ .._ _~ ~P5}~ +~e ~CII~~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall .Inh ik N0.4826 Company: State of Alaska ~"''`~~~y t+E~ ~ ~ +1{1~~ Alaska Oil & Gas Cons Comm e~ea J LU Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Inn rlacrrin+inn n~fa RI (`nlnr !_rl A-02 12086677 RST ~ - 0 ( 07/23/08 1 1 A-24 12034903 RST - 06/18/08 1 1 A-13 12086676 RST (~ 07/23/08 1 1 G-02A 11968945 RST ~ ~ 06/08/08 1 1 B-19A 12017500 RST / ~~ 06/14/08 1 1 15-18A 12005216 MCNL - ~ - 06/24/08 1 1 C-02 11982437 RST / ~ 06/19/08 1 1 X-14A 11978452 CH EDIT PDC-GR (MEMORY DDL) _ G / 04/21/08 1 1 B-37 12034907 CH EDIT PDC-GR 06/10/08 1 V-207 11999031 MDT aO~' 07/23/08 1 1 V-207 11999031 MDT QUICKLOOK "~ 07/23/08 1 1 V-210.- 12096908 MEM INJ PROFILE 08/08/08 1 1 L-116 12071885 SBHP SURVEY /(p 08/16/08 1 1 C-37A 12005221 MEMORY CBL (REVISED) - ~ Q 07/28!08 1 1 B-18 11978471 USIT _~ /(~ ~ ~ 08/04/08 1 1 05-31A 12057635 LDL '~ 6 07/21/08 1 1 13-29L1 11962614 LDL ~ ~ -d(~ / 07/30!08 1 1 13-29L1 11966271 USIT q /(p '~ 08/05/08 1 1 H-11 12017507 USIT 08/04/08 1 1 /-' w t rLCAac A~.nrvvvvLeulle r{CVCIYI fib JWrvIrvU AIVU MtI UtS1V11V1a VIVt LVYT tAl:tt 1 U: BP Exploration (Alaska) Inc. ` r ~, ~ ~. °~=~ x~,t PetrotechnicalDataCenter LR2-1 ~ ~ ~~,,,„; 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~~~ '~ ~ ~~C~j x, 1' sc,; Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-283 ATTN: Beth Received by: ~~ t~s V 07/23/08 ~-^'_ Sch~mberg~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth sai~d~~ ~V l~'~ .s. .~~ LUUt~ wou _i..h ~ ~ .... nse.. ...:,... N0.4786 Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 WB-05 12021166 MEM SBHPS / 06/13/08 1 1 G-16 1 9 2438 PRODUCTION P OFILE _ a~ a 06/21/08 1 1 R-12 12034908 PRODUCTION PROFILE _ ~?~ 07/14/08 1 1 01-03A 12017505 PRODUCTION PROFILE ~,.,~ ' ~(p 07/15/08 1 1 J-158 11970838 SCMT 07/17/08 1 1 01-23 12057631 PRODUCTION PROFILE 07/16/08 1 1 B-18 12071875 LDL G 07/20/08 1 1 4-04/T-26 11999025 LDL / ~ 07/12/08 1 1 J-14A 12066524 MCNL ~ p (- 05/25/08 1 1 G-15B 11963096 MCNL `p'-(~(p ' 05/30!08 1 1 L3-19 11968944 RST X65 - 06/07/08 1 1 L2-11 12014019 RST ~' 06/05/08 1 1 r~cnvc nvn,w ~~ccvVC 1'1cVClr 1 D7 ~71V1711Y\7 AIYY 11C1 Ur11Y11Y~7 V17C IiVYT CNCn 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Service 2525 Gambell Street, Suite 40 Anchorage, AK 99 3-2838 ATTN: Beth -s-~~._ Received by: • F "l S ~ s 6 p, ~~~, ,~ AI,ASSA OIL A1~TD GA5 COrTSERQATIOI~T CO~`II-II551O1~T David Reem Engineering Team Leader ~~~~~® ~ U ~ ~, ~ 2008 BP Exploration Alaska Inc. L~ SARAH PALlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PO Box 196612 Anchorage, AK 99519-6612 ~ ga,~ ~ D Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU B-18 Sundry Number: 308-230 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 rehe ~g date of this 1 tterelor the next worlflng 4:30 PM on the 23rd day following day if the 23rd day falls on a holida ~orCoeeuk~e unles s rehearing has been a Commission decision to Supe requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this ~ day of J e, 2008 Encl. ~'-8 ~ „ ~ ~ %~~~` ~,~`~ STATE OF ALASKA I O ~ti `~ ~~AL~A OIL AND GAS CONSERVATION COMMISSION ~ `t'its ~~~ ~ 0' ~° / ~~ APPLICATION FOR SUNDRY APPROVAL A1~~~~ ~~~ °, u~-:~ ~~ ~,,. ,a ,~~ ;;~ 20 AAC 25.280 ~:°;;; :; 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ~ Alter Casing - ~ ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ,® Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 182-002 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: - P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20702-00-00 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 B_~ $ Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028310' 73.8'- Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9410' ~ 9239' ' 9338' 9169' 8054' None Casin Len th Size MD TVD Burst Colla se Structural Conductor 110' 20" x 30" 110' 110' Surface 2696' 13-3/8" 2696' 2695' 4930 2670 Intermediate 8585' 9-5/8" 8585' 8445' 6870 4760 Prod ction Liner 1325' 7" 8080' - 9405' 7962' - 9234' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 9123' - 9198' 8962' - 9034' 5-1 /2", 17# x 4-1 /2", 12.6# L-80 8136' Packers and SSSV Type: 9-518" x 5-1/2" Baker Packer Packers and SSSV MD (ft): 7993' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: August 15, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Name vid Reem Title Engineering Team Leader ~ Prepared ey NamelNumber: Signature ~ Phone 564-5743 Date 6 LE ,~~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ~~ Conditions of approval: Notify Commission so that a representative may witness _ ^Pluglntegrity ~OPTest ^MechanicallntegrityTest ^LocationClearance +~~'~~ ~'~- '~ ~ ~ ~~` )~ ~ , /4''L r" ~ Other: _~~~ s~c~~ +~~~v~,~~.~ a-~~~~ ~:5'~ Subsequent Form Required: ~`~ APPROVED BY '~ / A roved B . COMMISSIONER THE COMMISSION Date (((JJJ Form 10-403 ReYiisq(i ~6%2006 ',IGINAL - ~ ~ ~xCJE_ ~ ~' 2~~~ Submit In Duplicate by cr,~,y B-18 Rig Workover (Restore OA/IA integrity) • Scope of Work: Pull 5.5/4.5" L-80 completion, cut and pull 9 5/8" casing, tie-back w/ new 9-5/8" casing (cemented to surface), replace 9 5/g" hanger and primary pack-off, and run 4.5" 13 Cr-80 completion. Engineer: Hank Baca MASP: 3231 psi We11 Type: Producer Estimated Start Date: August 15th, 2008 S 1 Pull P-prong and PX plug body at 8,054' MD. Drift past 7,950' for 5-1/2" Power Jet cutter and 5- 1/2" Fasdrill. E 2 Set 5-1/2" Fasdrill at 7,950' MD (P/T to 1000 psi). If P/T passes, Power Jet cut tubing C~ 7,945' (Ref: 5/26/82 tubing summary). Jet cut desired to be in the middle of the 1St full joint above the aaker. F 3 CMIT TxIA to 1000 psi for 30 minutes. Circulate well with seawater and FP w/ diesel thru the cut. Bleed WHP's to 0 si. O 4 PPPOT-T, -IC, check all LDS. O 5 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the ri . Proaosed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/ 3500 psi high. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD tubing string to the cut. 3. RU wireline and run USIT from cut to surface. 4. Run 9-5/8" RBP and set 100' below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set. Stack ~50 ft of sand on RBP. 5. Mechanically cut 9-5/8" casing in 1St full joint above top of cement. Pull casing thru stack. Dress-off 9- 5/g" stub in preparation of casing overshot. Note: VBR's will not be changed to 9-5/e" pipe rams as the well has two tested barriers (Fasdrill ~ -7,950' MD and RBP) to the reservoir. 6. Run back in with new 9 5/8", 47#, L-80 casing and land on new emergency slips with new primary pack-off. PT 9 5/$" pack-off to 3500 psi. Cement new 9 5/$" casing to surface 7. Cleanout above 9 5/a" RBP. Pull 9 5/" RBP. 8. Fish/mill up remaining 5.5" & 4.5" tubing. Packer at 7993', 4.5" tubing tail C~ 8136' 9. Run 4-~/z" 13Cr-80 completion with Baker S-3 packer. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 12. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. TREE = 6" IWELLHEAD= MCEVOY 'ACTUATOR= OTIS KB. EL(=l/ = 73.75' BF. ELEV = 45.3' KOP = 5900' Max Angle = 22@ 6500' Datum MD = 9032' Datum TV D= 8800' SS - ~ ~ S NOTES: 20'CONDUCTOR 110' 2040' S-1/2" OTIS SSSV LANDING NIP, ID = 4.562" GAS LIFT MANDRELS 13-3/8" CSG, 72#, L80, ID = 12.347" ~~ 2f Minimum ID = 3.725" @ 8094' 4-112" OTIS 'XN' NIPPLE ST MD TVD DEV TYPE VLV LATCH PORT DATE 13 3113 3039 0 OTIS DOME RM 16 02/04/06 12 4486 4412 1 OTIS SO RM 20 02/04/06 11 5312 5238 0 OTIS DMY RA 0 10 5797 5722 6 OTIS DMY RA 0 9 5949 5872 11 OTIS DMY RA 0 8 6353 6260 22 OTIS DMY RA 0 7 6501 6397 22 OTIS DMY RA 0 6 6863 6734 21 OTIS DMY RA 0 5 7013 6873 21 OTIS DMY RA 0 4 7425 7261 19 OTIS DMY RA 0 3 7581 7420 17 OTIS DMY RA 0 2 7734 7553 17 OTIS DMY RA 0 1 7887 7703 16 OTIS DMY RA 0 ~ ~ 7906' -{5-1/2" OTIS XA SLIDING SLV, ID = 4.562" ' 7973' BOT SBR SEAL ASSY 5-1/2" TBG, 17#, L80, .0232 bpf, ID = 4.892" 7993' 7993' 9 518" x 5-1/2" BOT PKR ID = 4.75" 7993' 5-1/2" X 4-1/2" XO $054' 4-1/2" OTIS X NIP, ID = 3.813" TOP OF 7" LNR 8080' $054' 4-1/2" PX PLUG (01/09/08) $094' 4-1/2" OTIS XN NIP, ID = 3.725" " " ' 4-1/2 TBG,12.6#, L-80 .0152 bpf, ID = 3.958 8136 8136' 4-1/2" TTL BOT SO SUB ID = 4.063" , " ' 8128' ELMD TT LOGGED 06/29/83 9-5/8 CSG, 47#, L-80, ID = 8.681" $5$5 PERFORATION SUMMARY REF LOG: DA-BHCA ON 05/21/82 ANGLEATTOPPERF: 15 @ 9156' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 9090 - 9116 S 04/06/89 3-1/8" 4 9120 - 9123 S 04/06/89 3-318" 4 9123 - 9147 C 04/13/89 2-7/8" 4 9156 - 9166 S 04/06/89 2" 4 9164 - 9174 C 05/24/00 3-3/8" 4 9184 - 9198 C 04/13/89 PBTD 9338' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9405' DATE REV BY COMMENTS DATE REV BY COMMENTS 05/25/82 ORIGINAL COMPLETION 08/19/06 COM/TLH WA V ER SFTY NOTE DELETED 04/05/03 JDW/KK PERF CORRECTIONS 07/19/07 BSE/PJC PULL PXN @ 8078' (07/09/07) 11/21/05 WTS/PJC XXP PLUG CORRECTION @ 8054' 01/15/08 SEW/SV SET PX PLUG (01/09/08) 01/05/06 EZL/PJC UPDATE WANER SFTY NOTE 01/14/06 KSB/PAG PULLED TTP 07/04/06 GJF/PAG SET PXN PLUG I MARKER JOINT I PRUDHOE BAY UNff WELL: B-18 PERMff No: 1820020 API No: 50-029-20702-00 SEC31, T11N, R14E BP Exploration (Alaska) TREE = 6" CM! WELLHEAD= MCEVOY ~ - ACTUAT01~= OTIS ' PROPOSED KB. EL~1/ = 73.75 BF. 6iEV = 45.3' KOP= 5900' 20' CONDUCTOR 110' Max Angle = 22@ 6500' Datum MD= 9032' ' NEW 9-5/8" CSG, 47#, L-80 from TOC to surface DatumTVD= 8800 SS GAS LIFT MANDRELS 13-3/8" CSG, 72#, L80, ID = 12.347" 2696' 4-1/2" 12.6#/ft, 13Cr-80, Vam Top @ 8140` 3.5" X NIPPLE Baker S-3 Chrome PKR @ 8000` 3.5" X NIPPLE 3.5" XN NIPPLE TOP OF 7" LNR 8080' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8585' 8732' MARKER JOINT PBTD 9338' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9405' PRUDHOE BAY UNfT WELL: B-18 PERMfT No: 1820020 API No: 50-029-20702-00 SEC 31, T11 N, R14E BP Exploration (Alaska) DATE REV BY COMMENTS DATE REV BY COMMENTS 05/25/82 ORIGINAL COMPLETION 08/19/06 COANTLH WAVER SFTY NOTE DELETED 04/05/03 JDW/KK PERF CORRECTIONS 07/19/07 BSE/PJC PULL PXN @ 8078' (07/09107) 11/21/05 WTS/PJC XXP PLUG CORRECTION @ 8054' 01/15/08 SEW/SV SET PX PLUG (01/09/08) 01/05/06 EZUPJC UPDATE WAVER SFTY NOTE 01114/06 KSB/PAG PULLED TTP 07/04/06 GJF/PAG SET PXN PLUG PERFORATION SUMMARY REF LOG: DA-BHCA ON 05/21/82 ANGLE AT TOP PERF: 15 @ 9156' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 9090 - 9116 S 04/06/89 3-1/8" 4 9120 - 9123 S 04/06/89 3-3/8" 4 9123 - 9147 C 04/13/89 2-7/8" 4 9156 - 9166 S 04/06/89 2" 4 9164 - 9174 C 05/24/00 3-3/8" 4 9184 - 9198 C 04/13/89 ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3301 2 5601 3 6962 4 7920 o2iz~/oa ~~~~~~~~~~~ NO. 4599 Alaska Data 8 Consulting Services ~ Company: State of Alaska 2525 Gambell Street, Suite 400 _ ~ ~~i't ~~ i~y'~ ~~~(! Attnk Christine Mahnkenomm Anchorage, AK 99503-2838 &V' E} ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Polaris,Lisburne Wall .Inh $ Inn r1n .,ti.,., nos., of n..l..- nn W-216 40016312 OH MWD/LWD EDIT - 2 d- 01/07/08 2 1 LGI-04 11970706 RST ~_p q 12/31!07 1 1 W-45 40016146 OH MWD/LWD EDIT '~-) '~ ( 12!18/07 2 1 15-046 12005202 CH EDIT PDC GR (SCMT) ~- ~ 12/28107 1 C-16B 11209604 MCNL ~~(o-ps' p f C 05/19/06 1 1 B-18 11962779 RST 'd 01/05/08 1 1 ~r+v~ r~v,"~v~~~~,.iv a. ,~~.vl_I~ 1 DI JIVI~IIYV MI~V RGI VRIY119V VIYC liVfr CNlirl 1 V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 _ - 900 E. Benson Blvd. ~, Anchorage, Alaska 99508 Date Delivered: 'i ~~_ ~:~ ~ ~ R j t)" ~~ ~.._.. Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 ~ Anchorage, AK 99503-28 8 ~ ATTN: Beth ~q / V Received by: • r "q.. '-U 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: ALAS.OIL AND ~:~T¿6~s~~;A~ON COMM.N ngC 0 4 2006 REPORT OF SUNDRY WELL OPERATIONS Aløsktt gill Oil Cons. Commission o Stimulate 0 Other 0 o WaiverD Time Extension 0 o Re-enter Suspended Well 0 5. Permit to Drill Number: 182-0020 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development ¡yo Stratigraphic air 3. Address: Exploratory Service 6. API Number: 50-029-20702-00-00 P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 73.8 KB PBU B-18 ADLO-028310 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool 8. Property Designation: Total Depth measured true vertical 9410 9239 feet feet Plugs (measured) None Junk (measured) fill @ 9278' MD Effective Depth measured 9278 feet true vertical 9111 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Insulated 29' - 139' 29' - 139' Surface 2666' 13-3/8" 72# L-80 30' - 2696' 30' - 2695' 5380 2670 Intermediate 8556' 9-5/8" 47# L-80 31' - 8585' 31' - 8445' 6870 4760 Liner 1325' 7" 26# L-80 8080' - 9405' 7962' - 9234' 7240 5410 Perforation depth: Measured depth: 9090' - 9198' True Vertical depth: 8930' - 9034' - - - - Packers and SSSV (type and measured depth) 5-1/2" 17# 4-1/2" 12.6# 9-5/8"X5-1/2" BOT PKR o o o L-80 L-80 Surface - 7993' 7993' - 8136' 7993' o o o Tubing: (size, grade, and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: , . ~~~1'~\\' ."{i~.. .. !àìÞ-l~~C.·'" ~"'\o;:I(I-'); \': , .. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 644 Shut in Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 6525 1083 0 o 0 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil I~ Gas WAG Tubing pressure 1179 o 13. Service x Contact Gary Preble WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Data Engineer Signature Phone 564-4944 Date 11/30/2006 ,; "-" ._-~" Submit Original Only ORIGINAl . . B-18 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY *** WELL S/I ON ARRIVAL *** (surface csg repair) RIG UP UNIT *** CONTINUE TO 11/23//06 *** 11/23/2006 *** CONTINUE FROM 11/22/06 *** (surface csg. repair) PULL PXN PLUG FROM 8078'SLM (SET 07/04/06). SET PX PLUG BODY / WITH 4 EA. 3/16 EO. PORTS @ 8042' SLM. RAN CHECK SET/SHEARED. SET PRONG @ 8036' SLM (1.80 BODY, 1.75, FN, 96" OAL. TESTED PLUG TO 3000 PSI W/LRS. DRAW TBG DOWN TO 300 PSI PRIOR TO DEPARTURE. ***LEFT WELL S/I*** PAD OP NOTIFIED. 11/23/2006 T/I/O= 20/20/20. Temp.= SI. No AL. TBG & IA FL. (S/L). TBG FL @ 300'. (7 bbls). IA FL @ 310'. (14 bbls). FLUIDS PUMPED BBLS I 16 DIESEL 16 TOTAL LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 March 1996 RE: Transmittal of Data ECC ~: 1317.03 Sent by: HAND CARRY Data: LDWG Dear Sir/Madam, Reference: BP B-18 PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: i LDWG TAPE+LIS Run ~ i Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 to (907) 563-7803 Received by: Date: RECEIVED Alaska Oil & Gas Cons. Gommissk)n Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 12 March 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 CN FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF Run # 1 Run $ 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 1317.03 1531.03 5748.03 5942.03 6431.04 6619.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: FAX to (907) 563-7803 Date: ~aska Please sign and return t~ Petrotechnical Data Oente~ BP Exploration (Alaska) Tho 900 East Benson Boulevard Anchorage, Alaska 99508 Received -- ALASKA OiL & ~a~ ~vm~.u~¥ATIO.l COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 4 August 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 7F-71 .-12 (43-31-1-14) 1 PLS STATIC FINAL BL 1 PLS STATIC RF SEPIA ~' 2, - o % s-18 i PLS STATIC FINAL BL i PLS STATIC RF SEPIA 7-~" '~ 2 M-32 (41-01-11-12) i PLS STATIC FINAL BL 1 PLS STATIC RF SEPIA 'tV ' 73 .-25 (33-7-11-13) 1 PL/STATIC FINAL BL 1 Pi/STATIC RF SEPIA I PLS STATIC FINAL BL i PLS STATIC RF SEPIA ~ d>-- 3 g'' B-04 (23-29-11-14) i PLS STATIC FINAL BL i PiS STATIC RF SEPIA f ~-rPV w-31 (31-17-11-12) 1 PLS STATIC FINAL BL i PLS STATIC RF SEPIA ECC No. Run # 1 5791.03 Run # 1 Run # 1 1317.02 Run # 1 Run # 1 5790.01 Run # 1 Run # 1 6238.02 Run # 1 Run # 1 4146.02 Run # 1 Run # 1 5807.01 Run # I Run # 1 5659.02 Run # 1 Please sign and return to: Atlas Wireline Services .. 5600 B Street Suite 201 . Anchorage, AK 99518 ~ ./~odney;. Paul,on . Received b~--~~//z/ ~/ b~te: RECEIVED AU(; 08 1994 Alaska Oi~ ~ ~-_.s Ce,-.s. C~r~'imJa~lo~ Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 2 August 1994 RE: ~\ Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ ~ t% ~ # DESCRIPTION Please sign and return to: Atlas Wir~line S~rvices 5600 B Street Suite 201 ECC No. Run # 1 1423.06 Run # 1 5806.02 Run # 1 5922.02 Run # 1 1317.01 Run # 1 6245.00 An At Received ~or~ge, AK 99518 ~°~~Paul s°nDat~: Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) Ino 900 East Benson Boulevard Anchorage, Alaska 99908 P~eeived by ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 2 August 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. .07 - Run ~E-08 (22-32-12-14) Run # 1 ~ J~-lS" Run ~ 1 Please sign and return to: Atlas Wireline Services ~0~ 5600 B Street %~ Suite 201 ~C~ 0~ Anchorage, AK 99518 '~8 ~/~ F3ne 1 CN/GR LDWG TAPE+LIST 1 CN/GR LDWG TAPE+LIST 1 CN/GR LDWG TAPE+LIST 1 CN/GR LDWG TAPE+LIST 1 DIFL LDWG TAPE+LISTR 1423.06 5806.02 5922.02 1317.01 6245.00 Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) Ine 900 East Benson Boulevard Anchorage, Alaska 99~08 Received b~' ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 20 July 1994 RE:, Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL $Z-05 s-19 -02- s-18 5~--- [\7-- B-23 B-22 (32-32-11-14) B-15 (21-13-11-14) DESCRIPTION ~f~N/GR FINAL BL CN~GR FINAL RF S~PIA ,~-r~'CCL PATCHST FINL. BL CCL PATCHST RF SEPIA ECC No. Run # 1 5806.02 Run # 1 Run # 1 ~317.01 Run # 1 Run # 1 5808.03 Run # 1 Run # I 1423.06 Run # 1 Run # 1 5798.09 Run # 1 Received by: Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by Date: Date STATE OF ALASKA COMMI( 'N ~ ,CA OIL AND GAS CONSERVATION 0 R i G I 'I~A L REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed:' Operation shutdown , Pull tubing Stimulate X Plugging Alter casing Repair well 2. Name of Operator BP Exploration (Alaska)/nc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development .Z._ Exploratory Stratigraphm Service 4. Location of well at surface 344' SNL, 1892' WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 403' NSL, 1589' WEL, SEC. 30, T11N, R14E, UPM At effective depth 470'NSL, 1461' WEL, SEC. 30, T11N, R14E, UPM At total depth 485' NSL, 1431' WEL, SEC. 30, T11N, R14E, UPM 12. Present well condition summary Total depth: measured 9410feet true vertical BKB 9239feet Effective depth: measured 9278feet true vertical BKB 911~feet Casing Length Size Structural -- Conductor 110 20 x 30 Surface 2667 13 3/8 Intermediate 8556 9 5/8 Production -- Liner 1325 7 Perforation depth: measured 9123'-9147', 9184'-9198' Plugs (measured) Junk (measured) Cemented 8 c.y. 3720 c.f. 1285 c.f. 390 c.f. Perforate Other ..... 6. Datum elevation (DF or KB) KBE= 73.75 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-18 (34-30-11-14) PBU 9. Permit number/approval number 82-2/ 10. APl number 50- 029-207o2 11. Field/Pool Prudhoe 0il Pool fill at 9278' MD BKB (04/89) Measured de~h True vertical de~h BKB 139 139 2696 2696 8585 8445 8080-9405 7962-9234 Sqzd: 9090~9116~ 9120~9123~ 9156~9166' true vertical subsea 8888'-8960' (two intervals) Tubing (size, grade, and measured depth) 5 1/2 L-80 to 7993' with 4 1/2" tailpipe to 8136' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 7993~ 5 1/2" SSSV at 2020' 13. Stimulation or cement squeeze summary 11~/91 HCL ACID Treatment Intervals treated (measured) 9184'- 9198' 189 BBL Production Water Treatment description including volumes used and final pressure 47BBL MEOH 28 BBL 15% HCL SEP - 8 1992 · ~,,,~ ~uJl & (~as Cons. C0mmiss 14. Prior to well operation Subsequent to operation Re0resentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 990 5309 13 0 1410 5054 34 0 Tubing Pressure 2o59 1905 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 ce,rtify that the foregoipg is true. a, nd correct to the best of my knowledge. Signed _ ./-~ ,d../~ Title Senior TechnicalAssistant I Form 10-404'Rev 06/15/88 / Date SUBMIT I1~" DfJ PLI~.,ATE BP EXPLORATION BP Exc c'at~on (Alasxal Inc 900 F. as' Benson Bou~evarcl PO Box ~96612 ~c~c-~:e Alaska 995"9-6612 (907) 56;-5111 DATE: 10/30/91 T~ 82965 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907), 564-4004. ~-~ ~ 10/11/91 ~1 ] -18 -- iO/i ./9:L ~.~? S-05~ 09/29/91 ~1 , A-01 ~' 09/20/91 10900.00-11039.00 HLS 5 " 8950.00- 9231.00 HLS 2 " 9400.00- 9660.00 HLS 2 " 9124.00- 9535.00 HLS 5 " 9979.00-10221.00 HLS 5 " 8686.00- 9024.00 HLS CL P ROD-F PROD-F STATIC STATIC ROTASCAN 2 " ROTASCAN 5 5 ~-0~ ~ T~CER CHEC~ 5 A-01 ~ T~CER CHECK %'A-01~-/' 09/20/91 " A-0' '- 10/05/91 8700.00- 9025.00 HLS 8700.00- 9013.00 HLS 09/'20/91' ~i 'F'U',' 8600J00 9500;00 09/20/91 ~1 8700.00- 9010.00 HLS 09/20/91 $1 8600.00- 9040,.00 HLS Information Control ;Tel! Records Adrian J. Martin BP EXPLORATION BP Exploration (Alaska) Inc 900 East Benson Boulevard PO Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 02/08/90 Transmittal: 80896 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINkL LOGS Enclosed is your copy of the material listed below. If questions, please contact BP Well Records at (907) 564-4445. you have any B-18 LEAK DET. 01/26/90 #1 400-9200 Camco Y-17 GAS LIFT 01/26/90 #1 Surface-10472 Camco Y-18 INJ 01/24/90 #1 10890-11285 Camco 2"/5" 2"/5" 5" Distribution: kRCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS ARCHIVES------ BP E~PLORATION BP Ex01oratlon (Alaska) Inc. 900 East 8enson 8oulevarcl PO Box 196612 Anct~orage. Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 01/29/90 Transmittal: 80826 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material questions, please contact BP Well Records listed below. If at (907) 564-4445. ,~ you have any B-04 PROD-F 01/12/90 B-18 PROD-F 01/15/90 C-24 PROD-F 01/13/90 G-Il PROD-F 01/14/90 Z-01 PROD-F 01/15/90 Z-10 PROD-F 01/13/90 #1 10350-10650 #1 8950-9230 #1 10150-10450 #1 11200-11550 #1 10450-10720 13450-13890 Camco 5" Camco Camco 5" Camco Camco 5" Camco 5" Distribution: ARCO CHEVRON E~XON GEOSCIE~CES MOBIL PHILLIPS ARCHIVES ,. R£¢EIVEO lC~ JAN ~ 1 .~90 Alas~,'a. 0il ~ S~s Cons,, comm~ Anchorage BP EXPLORATION IGINAL BP Exploration (Alaska) Inc 900 East Benson Boulevard PO Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 14, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well B-18 (34-03-11-14) 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 performing a cement squeeze and reperforation of the well. Yours very truly, J A Bragg ~U ~roduction Engineering JAM:JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File REPORT OF SUNDRY WELL OPERATIONS Stimulate ~ Plugging Alter casing ....... Repair well 5. Type of Well: Development X Exploratory . Stral~graphic Service 9410feet Plugs (measured) 9239feet 9278feet Junk (measured) 9111 feet 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 344' SNL, 1892' WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 403' NSL, 1589' WEL, SEC. 30, T11N, R14E, UPM At effective depth 470'NSL, 1461' WEL, SEC. 30, T11N, R14E, UPM At total depth 485' NSL, 1431' WEL, SEC. 30, T11N, R14E, UPM 12. Present well condition summary Total depth: measured true vertical BKB Effective depth: measured true vertical BKB Size Cemented 20x30 8 c.y. 13 3/8 3720 c.f. 9 5/8 1285 c.f. 7 390 c.f. Casing Length Structural -- Conductor 110 Surface 2667 Intermediate 8556 Production -- Liner 1325 Perforation depth: measured 9123'-9147', 9184'-9198' true vertical subsea 8888'8960' (two intervals) Perforate Other X 6. Datum elevation (DF or KB) KBE ~ 73. 75 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-18 (34-30-11-14) PBU 9. Permit number/approva'l'number 82-2 / 9-151 10. APl number 5O- O29-207O2 11. Field/Pool Prudhoe Oil Pool fill at 9278' MD BKB (04/89) Measured depth True vertical depth BKB 139 139 2696 2696 8585 8445 8080-9405 7962-9234 Sqzd:9090~9116~ 9120~9123~ 9156~9166' Tubing (size, grade, and measured depth) 5 1/2 L-80 to 7993' with 4 1/2" tailpipe to 8136' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 7993';5 1/2" SSSV at 2020' 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 1190 11349 0 0 Subsequent to operation 6850 3822 220 0 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run ........ I Daily Report of Well Operations X Oil X Gas Suspended. Service Tubing Pressure 2419 272 17' I her~j:~l~/-'~- ~ that the f°~g~'~g is true and c°rrect t° the best of mY kn°wledge' Form ( ( WELL B.18 ¢34-30-11.14~ PBU CTU CEMENT SOUEEZE OPERATIONS A coiled tubing cement squeeze of existing perforations was performed as follows: 3/21/89 4/6/89 4/9/89 4/13/89 Performed perforation mud acid wash with ballsealers; flowed well. Rigged up coiled tubing unit and pressure tested to 4000 psi. Cement squeezed all perforations. Performed inflow test; squeeze good. Rigged up Halliburton and perforated the following intervals using 3 3/8" carrier guns at 4 spf: Reperf 9123' - 9147' MD BKB Add perf 9184' - 9198' MD BKB Returned well to production and tested. jam 8/4/89 BP EXPLORATION BP Exploration (Alaska) Inc. gOO East Benson Boulevard PO. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 TO HOUSTON ARCO CHEVRON EXXON MOBIL' ' PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES Date: 06-21-89 'T%: 80131 BP 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: B-18 CCL/PERF 04-13-89 #1 8030-9234 HLS 5" D-08 CCL/PERF 04-27-89 #1 9900-10466 HLS 5" F-03 CCL/PERF 04-20-89 #1 9500-11100 HLS 5" H-23 CCL/PERF 04-11-89 #1 9700-9950 HLS 5" N-4A CCL/PERF 04-10-89 #1 9830-10419 HLS 5" R-18 CCL 06-17-89 #1 9000-9968 Atlas 5" Y-10 CCL 06-15-89 #1 9382-9797 Atlas 5" Received: Date: RC V Alaska 0il & (~as Cons. Co 'ss'on Anchorage Information Control Well Records LR2-1 J. Dietz/S. McCurry BP EXPLORATION February 21, 1989 BP Exploration (Alaska) Inc 900 East Benson Boulevard PO 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 B-18 (34-30-11-14) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perform a cement squeeze and reperforation of the well. Yours very truly, Manager Production Engineering JAB:JAM Enclosures (9) cc: L. Burke (MB12-1) Well File Anchoraeje 1. Type of Request: STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Operation Shutdown ,, Re-enter suspended well ~ Plugging ~ Time extension Stimulate Pull tubing ~ Variance ,. Perforate Other X ~ 5. Type of Well: 6. Datum elevatiocr'(bF" or KB) KBE= 73.75 AMSL feet Abandon Suspend Alter caslng ~ 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 344' SNL, 1892' WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 403' NSL, 1589' WEL, SEC. 30, T11N, R14E, UPM At effective depth 477' NSL, 1447' WEL, SEC. 30, T11N, R14E, UPM At total depth 485'NSL, 1431' WEL, SEC. 30, T11N, R14E, UPM 12. Present well condition summary Total depth: measured true vertical BKB Development X Exploratory ~ Stral~graph~c Service 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-18 (34-30-11-14) PBU 9. Permit number 82-2 10. APl number 50- 029-20702 11. Field/Pool Prudhoe Oil Pool 9410 feet Plugs (measured) 9239 feet Effective depth: measured 9338 feet Junk (measured) true vertical BKB 9169 feet Casing Length Size Cemented Structural -- Conductor 110 20 x 30 8 c.y. Surface 2667 13 3/8 3720 c.f. Intermediate 8556 9 5/8 1285 c.f. Production -- Liner 1325 7 390 c.f. Perforation depth: measured 9090'-9116', 9120'-9147', 9156'-9166' Measured depth 139 2696 8585 8080-9405 True vertical depth BKB 139 2696 8445 7962-9234 true vertical subsea 8856'-8929' (three intervals) Tubing (size, grade, and measured depth) 5 1/2 L-80 to 7993' with 4 1/2" tailpipe to 8136' Packers and SSSV (type and measured depth) 9 5/8" BO Tpacker at 7993~ 5 1/2" SSS Vat 2020' 13. Attachments Description summary of proposal X Approved by order of the Commission Form 10-403 Rev 06/15/88 Detailed operations program Suspended~ BOP sketch X 15. Status of well classification as: Date ,~ ' [~(~'~' [ lapprOvalNO' ~-/"',.~'"'-// 14. Estimated date for commencing operation J February 1989 16. If proposal was verbally approved Oil X Gas ~ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SJ~ned ~/,,~Y[~ ~x~. ~~ Title Mana~Ter Production Engineering7 n/'/d~ons al °tif ~/~ FOR COMMISSION USE ONLY Co of approv : N y Commission so representative may witness Plug integrity__ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- ~/~'~ ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner r~,pproved Copy Date ~=,e SUBMIT IN ~RIPLICATE ( ( WELL B-18 (34-30-11-14~ PBU CTU CEMENT SOUEEZE PROPOSAL A coiled tubing cement squeeze of existing perforations is proposed as follows' 1. Perform pre-workover surveillance. 2. Rig up CTU and support equipment and pressure test BOP's to 4000 psi. 3. Perform perforation mud acid wash; flow well. 4. Cleanout wellborc to PBTD or to top of solid fill. 5. Fluid pack wellbore with produced water. 6. Pump cement and squeeze existing perforations. 7. Reverse out cement after squeeze is obtained. WOC for 24 hours, then test squeeze. If squeeze fails, immediately resqueeze and WOC. 8. If squeeze is successful, perforate the following intervals: Rcpcrf 9123' - 9147' MD BKB Add pcrf 9184' - 9198' MD BKB The intervals 9090' - 9116' and 9120'- 9123' will be left squeezed. All depths are referenced to BHCS 5/21/82. 9. Return well to production and test. jam ' ~,nchorage ( Coiled Tubing Blow-Out-Preventers /,~ Coiled Tubing INDEXED DALLAS ARCO CHEVRON E~XON TEXACO Date: 04/27/88 TO: MOBIL TI: 78759 PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD AL AS~\ PRODUC REFERENCE: SAPC CASED HOLE FINAL LOGS The following material ts being submitted herewith. Please acknowledge recelpt by $1gnlng a copy of this letter and returning It to this office: ~A-16 · ~ A-23 B-12 ~G-2 ~ H-23 R-9 '~ R-20 Injection Profile 04/15/88 #1 9400-9850 Camco 5" " " 04/13/88 #1 10550-10850 Camco 5" Production Profile 04/10-11/88 #1 11200-11600 Camco 5" GR/CCL 04/15/88 #1 8650-9025 Sch 5" Spinner 07/18/83 #1 9090-9147 Camco 5" GR 04/13/88 #1 9600-10228 Camco 5" CBT 04/21/88 #1 8995-10156 Sch 5" Spinner/Temp/Tracer 04/17/88 #1 9400-9900 Sch 5" Production Log 04/18/88 #1 9000-9500 Sch 5" Injection Profile 04/15/88 #1 11200-11850 Camco 5" Standard Alaska Produchon Company ~ I 900 Eos! Benson Boulevo~k P O Box 196612 Ancho~oge Alosko 99519 6612 1907) .%64 51 I I INDEXED DALLAS ARCO CHEVRON EXXON TEXACO Date: 1i/18/86 TO: MOBIL T~: 77525 PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD AL ASKA PRODUCT ION REFERENCE: SA]PC 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: B~18 Perf. Record 07/04/86 #1 8650-9250 $ch 5" B-20 Perf. IRecord 07/05/86 #1 9530-9854 Sch 5" G-30 CET 08/06/86 ~Jl 8762-9766 Sch 5" G-30 CBT 08/06/86 ~/1 8672-9743 Sch 5" G-32 CBT 08/27/86 t/1 8350-9550 Sch 5" J-1 Tubing Cutter Record 08/23/86 ~/1 8600-9100 Sch 5" J-19 GCT 07/12/86 #1 SURF-1390 Sch 5" J-19 GCT 07/12/86 ~J2 SUR~'-i 772 Sch 5" M-2 Perf. Record 07/01/86 f/l 10000-10334 Sch 5" M-2 Spinner Profile 07/09/86 #1 9695-10300 Sch 5" M-21 Perf. Record 07/04/86 #1 8370-9250 Sch 5" R-18 Perf. Record 07/06/86 #1 8990-10067 Sch 5" R-23 Perf. Record 07/03/86 f/1 11240-12174 Sch 5" S-19 GCT 07/21/86 I/1 SURF-1498 Sch 5" S-19 CBT 08/13/86 #1 9100-10110 Sch 5" S-20 CBT 08/30/86 ~/I 8710-9774 Sch 5" Y-24 GCT 07/15/86 ~/1 SURF-13450 Sch 5" Y-24 CBT _ ~ 07/15/86 fJl 12600-13488 Sch 5" ~la~kaOii & Gas I . '~sion ~ Anchorage Received Dote A un,I OI the o.g,nol .5toncJz~,d 0,1 Co,npony l~o,,,,cJed ,n Cle~,.Iond Oh,o .. Itl/() Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 Standard Alaska Productmn Company ( 900 East Benson Boulevak P O Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION July 10, 1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Well B-18 (34-30-11-14) 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. PFB:JAM~ Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 B-18 Well File Yours very truly, P. F. Barth, Supervisor Reservoir/Production Surveillance Unit I JUL ~. z~ kl~ska Oil & Gas Cons. Goings,lam Anchorage A un,t of the or,g~nal Standard Od Company Founded ,n Cleveland Oh,o, ,n 1870 REPORT OF SUNDRY WELL OPERATIONS I Operations performed Operation shutdown [] Stimulate [] Plugging ~ Perforate ~ Pull tubing ~ AIterCas~ng ~ 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 344' SNL, 1892' WEL, Sec. 31, TllN, R14E, UPM At top of productwe ~nterval 403' NSL, 1589' WEL, Sec. 30, TllN, R14E, UPM At effective depth 477' NSL, 1447' WEL, Sec. 30, TllN, R14E, UPM At total depth 485' NSL, 1431' WEL, Sec. 30, TllN, R14E, UPM 5 Datum elevation (DF or KB) KBE = 73.75 6 Unit or Property name Prudhoe Bay Unit 7. Well number B-18 (34-30-11-14) PBU 8 Approval number 195 9 APInumber 50-- 029-20702 10 Pool Prudhoe Oil Pool Feet 11 Present well condition summary Total depth measured true verhoal 9410 feet 9239 feet BKB Plugs (measured) Effective depth' measured true vertical 9338 9169 feet Junk (measured) feet BKB Casing Length Structural -- Conductor 65 ' Surface 2651 ' Intermediate 8540 ' Production __ Liner 1325 ' Perforahon depth, measured 9090' - 9166' Size Cemented 8 cu.yds. 3720 c.f. 1285 c.f. 20"x30" 13 3/8" 9 5/8" 1! 390 c.f. (three intervals) true vert,cal (subsea) 8856' - 8929' Tubing (s~ze, grade and measured depth) 5 1/2" L-80 to 7993' with 4 1/2" tailpipe to 8136' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 7993': 5 1/2" Otis SSSV at 2020' 12 Shmulahon or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Measured depth 110' 2696' 8585' 8080'-9405' True Verhcal depth BKB 110' 2696' 8445 ' 7962'-9234' , ,~r~a ~' Alaska Oit & Gas Cons. Comm'~ssiot~ AnCh0rag0 13 Prior to well operation Subsequent to operation Representative Daily Average Pr)duchon or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 3350 2050 0 Casing Pressure 0 0 8070 10895 0 ~bing Pressure 849 1079 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Supvr. Res./Prod. Surveillance I Form 10-404 Rev 12-1-85 Submit ~n Duplicate ( Well B-18 (34-30-11-14) PBU ADDITIONAL PERFORATING OPERATIONS 7/4/86: Installed and tested lubricator to 3500 psi. Rigged up Schlumberger and perforated the following additional interval using 2 7/8" Hyperdome guns at 4 spf: 9156' - 9166' MD (8919' - 8929' TVDss) Above depths are referenced to BHCS/GR, 5/22/82. Put well back on production and tested. jm 7/9/86 Standard Alaska Productmn Company 900 East Benson Bouleva~. P O Box 196612 Anchorage, Alaska 99519-6612 (907) 564 5111 June 17, 1986 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Well B-18 (34-30-11-14) 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. · PFB: JAM ~ Enclosures (9) cc: J. L. Haas (MB12-1) B-18 Well File Yours very truly, P. F. Barth, Supervisor Reservoir/Production Surveillance Unit I A un,t of the or,g,nal Standard O,I Company Founded ,n Cleveland Oh,o ,n 1870 RECEIVED JUN 2 o Ala:ka Oil & (~s Cons. STATE OF ALASKA ALASK/~' L AND GAS CONSERVATION COMMI~r 9N APPLICATION FOR SUNDRY APP IOVALS I Type of Request Abandon ~ Suspend ~ Operahon Shutdown F' Re-enter suspended well ~ Alter casing Z T~me extension ~ Change approved program- Plugging ~ Shmulate ~_ Pull tuWng ~" Amend order-_ Perforate ~ Other 2 Name of Operator 5 Datum elevation (DF or KB) STANDARD ALASKA PRODUCTTON COMPANY KB:E = 73.75 feet 3 Address 6 Und or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4 Location of well at surface 344' SNL, 1892' WEL, Sec. 31, TllN, R14E, UPM At top of produchve ~nterval (top Ivishak/Sadlerochit) 403' NSL, 1589' WEL, Sec. 30, TllN, R14E, UPM At effechve depth 477' NSL, 1447' WEL, Sec. 30, TllN, R14E, UPM At total depth 485' NSL, 1431' WEL, Sec. 30, TllN., R14E¢ UPM 11 Present well condition summary Total depth measured true vertical 7 Well number B-18 (34-30-11-14) PBU 8 Permit number 82 -2 9 APl number 50--029-20702 10. Pool Prudhoe Oil Pool 9410 feet Plugs (measured) 9239 feetBK. B Effective depth measured 9338 feet Junk (measured) true vertical 9169 feetBKB Casing Length S~ze Cemented Structural -- Conductor 65' 20"x30" 8 cu.yds. Surface 2651' 13 3/8" 3720 c.fo Intermediate 8540' 9 5/8" 1285 c.fo Production __ Measured depth 110' 2696' 8585' True Verhcal depth BKB 110' 2696' 8445' L~ner 1325' 7" 390 c.f. Perforation depth measured 9090' - 9147' (two intervals) true vertical (subsea) 8856' - 8911' ~b~ng(s~ze, grade and measured depth) 5 1/2" L-80 to 7993' with. 4 1/2" tailpipe to 8136' Packers and SSSV(type and measured depth) 9 5/8" BOT packer at 7993' 8080'-9405' ; 5 1/2" Otis "RQY" SSSV at 2020' 7962 '-9234' [C/IV D JUN 2 0 'Alaska 0il & Gas C0~]s. 12 Attachments Description summary of proposal :~ Detailed operahons program ~ BOP sketch 13 Estimated date for commencing operation June/July 1986 14. If proposal was verbally approved Name of approver Date approved 15..I hereby ce. rhfy that the f~ego~ng is true and correct to the best of my knowledge Sign'~ed /~ f. ~~ Titlesu~vr. Res./Prod. Surveillance i Date P. F. Barth Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug ~ntegnty [] BOP Test [] P,~.turned _ ,,,, Commissioner Approval No Approved by by order of the commission Date ~'~ ~-- ~' Form 10-403 Rev 12-1-85 Submit ~n triplicate Well B-18 (34-30-11-14) PBU ADDITIONAL PERFORATING PROPOSAL We propose to perforate the following additional interval in Well B-18 during June/July 1986 at 4 spf: 9156' - 9166' MD (8919' - 8929' TVDss) Ref. BHCS/GR, 5/22/82 A lubricator will be installed and tested to 3500 psi for all well work. The SSSV will be pulled prior to perforating and reset after the job at 2020'. jm JUN 2 o 6/17/86 ~'~'~,~ Oii& Gas Cons. Co,~ ........ ~ BASIC SYSTEM MAKEUP BOWEN PACKOFF HAND PUMP GREASE SEAL FLOWTUBE ~LOWLINE GREASE LINE FLOWLINE VALVE GREASE , )~/~ MANIFOLD RISER GREASE RESERVO{R BOP CEIV -D ( SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TO SFO/UNIT/STATE: GETTY (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) CENTRAL FILES(CC#'s-Transmittal Only) REFERENCE 31 1 1 "C" STREET ANCItOFiAG[ ALASKA '[FL[I'HONE 1907l 265 0000 MAIL PQUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 2-15-84 CC#: 75040 2~HIO CASED HOLE FINAL LOGS 5/T~ ~ol'ow,nc3 mater,al :s be,nc3 subm,tted herew,th Please acknowledc3e recefpt by s,c3n,ncj a copy of th~s letter and return,ncj it to th~s off~ce -- SPO/UNIT/STATE: D.S. A-11''/ TDT-M 10-19-83 - #2 9650-10639 Sch 5" D.S. B-18~ TDT-M 10-10-83 #1 8550-9319 Sch 5" D.S. B-22 ~ TD]7-M 10-12-83 #1 10200-11200 Sch 5" D.S. B-23~ TDT-M 10-08-83 #I 9150-10010 Sd~ 5" D.S. E-!3'-- TDT-M 10-07-83 #1 10300-11310 Sd~ 5" D.S. N-9/ TDT-M 10-11-83 #1 8800-9712 Sch 5" D.S. x-16'~ TDT-M 10-13-83 #1 10100-10878 Sd~ 5" D.S. X-17~ TDT-M 10-15-83 #1 9300-10352 Sch 5" D.S. A-11 ~ EPL 10-19-83 #- 9800-10640 Sch 5" (4/82) RECEIVED DATt' 19 Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 '°C'° STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 TO State of Alaska 11-17-83 CC#: 074826 REFERENCE: SOHIO MAGNETIC LIS TAPES AND LISTINGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- ~,, ACC # . .... / A-29 , ~ 68633~ -~- -10-4-83 ~ ~'m 1"~¢ / ~'/~/- ~~~. ~ ,, 68667~/ z0-?-83 ~ ~ - ,p ,... ' ~" / N-B ~ 68671~ 10-11-83 ~ ~ -- ---- /~17f'fl~~ _~ . .... /_.. ~/~3~-0~~~~/~17 7~' ~ ~-1~ O.~ '~68536~/. 9-2-83 ~ ~ 2 A-~ O.~ 68623 ~/ 9-27-83 ~ ~2 ~ ~ 3 RECEIVED DATE Devel~t Geology ~ ~ml~-~-"~eli Records Anchorag9 k~t SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 November 17, 1983 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: We1~'I$~34-30-11-14) PBU and B-20 (14-29-11-14)PB~ Enclosed, in duplicate, are Forms 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our subsequents to performing scale inhibitor squeeze treatments on these wells. GJP/J~H~/pj w Enclosures cc: J. D. Hartz Geology Well File #17 Yo v u y, D±str±¢t ?etroleum Eng±neer (~ STATE OF ALASKA C~ ALASKA OIL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] 2 Name of Operator Sohio Alaska Petroleum Company 3 Address Pouch 6-612, Anchorage, Alaska 99502 COMPLETED WELL OTHER [] 7 Permit No 82-2 8 APl Number 50- 029-20702 4 Location of Well At Surface: 344' SNL, 1892' WEL, Sec. 31, TllN, R14E, UPM 5 Elevation m feet (indicate KB, DF, etc ) KBE = 73.75' AMSL Lease Designation and Serial No ADL 28310 9 Unit or Lease Name Prudhoe Bay Unit 10 Well Number B-18 (34-30-11-14) PBU 11 F~eld and Pool Prudhoe Bay Prudhoe Oil Pool 12 Check Appropmate Box To Indicate Nature of Not~ce, Report, or )ther Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF' (Submit m Tmphcate) (Submit m Duplmate) Perforate [] Alter Casing [] Perforations [] Altering Camng [] Stem ulate [] Abandon [] St ~m ulat~on J~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulhng Tubing [] Pull Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Descmbe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) A 45 barrel scale inhibitor treatment was performed over the following intervals in early November, 1983. The well was shut-in for 24 hours after the treatment. The SSSV was removed prior to stimulation and reset after the job at 2020~. 9090'-9116' BKB (Ref. BHCA/GR, 5/22/82) 9120'-9147' BKB ( " ) ~i4 I hereby~c/e~t,f~[ that the~_ego,ng ,s true and correct to the best of my knowledge S~gned T~tle District Petroleum Engineer J The sp~a~,~3elow fe~.l~ommms~on use Conditions of Approval, ~f any Approved by By Order of COMMISSIONER the Commms~on Date Form 10-403 Rev 7-1-80 SubmIt "Intentions" ~n Tr~pl,cate and "Subsequent Reports" ~n Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL POUCH 6-612 ANCHORAGE, ALASKA 99502 November 4, 1983 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Gentlemen: Mr. C. V. Chatterton Wells ~-18~and B-20 PBU Enclosed, in triplicate~ are Forms 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our proposals to perform scale inhibitor squeeze treatments on these wells. G~~. J.~~sga ~ District Petroleum Engineer GJP:J~.'pjw Enclosures CC: J.D. Hartz Geology Well File #17 (' STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator 7 P~rc,t2No Sohio Alaska Petroleum Company ~ 3 A.¢dress_ 8 APl. Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20702 4 Location of Well At Surface: 344' SRL, 1892' WEL, Sec. 31, TllN, R14E, U!rM 5 Elevation m feet (m(J~cate KB DF, etc ) KBE = 73.75' AMSL' 12 6 zayre D~.~n and Serial No 9. Unit or Lease Name Prudhoe Bay Unit 10 Well Number B-18 (34-30-11-14) PBU 11 F~eld and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Tmpl~cate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~] Abandon [] Stimulation [] Abandonment [] Repmr Well [] Change Plans [] Repmrs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note Reportmult~plecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for eachcomplet~on) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) A 45 barrel scale inhibitor squeeze treatment will be performed over the following intervals during November/December, 19_83, The well will be shut-in for 24 hours after the treatment. The S$SV will be removed prior to stimulation and reset after the job at 2020'. 9090'-9116' BKB (Re.f. BHCA/GR, 5/22/82) 9120'-9147' BKB ( " ) 14 I f mg ~s true and correct to the best of my knowledge S,gne~,~/ '~O~./,~ ~ ~ ¢~ T,tle District Petrole~ Engineer The ~ bel;w ,~r ~mm,ss,on use~ Condlnons of Approval, if any Date Approved by. Approved Cop~ Rr,~turned By Order of COMMISSIONER the Corniness,on Date Form 10-403 Rev 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SF0 AB. CO CHEVRON 31 1 1 "C" STREET ANCHORAGE. ALASKA TELEPHONE 19071 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 TO SFO/UNIT/STATE: (-Marathon) CENTRAL EXXON GETTY MOBIL PHILLIPS STATE BPAE (Transmittal Only) _ FILES (CC#'s - Transmittal Only) 8/16/83 Date: Trans.#: - CC#: 74652 REFERENCE: FINAL DATA - PRESSURE SURVEY DATA~ Ilowing material is being submitted herewith. Please acknowledge receipt by signing a this letter and returning it to this office:-- B-18// Pressure Survey & BHPD 7/18/83 Camco B-19J' " " " " 7/26/83 Otis B-20j " " " " 7/28/83 Otis B-21/ " " " " 7/30/83 Otis B-22~ " " " " 7/17/83 Otis B-23~ " " " " 7/16/83 Camco D-16j Stat£c Report 7/27/83 Camco D-21 " " 8/01/83 Camco D-22j " " 8/08/83 Camco D-23 j " " 8/04/83 Camco M-5j~ Pressure Survey 8/03/83 Otis X-7Y Pressure Survey & BHPD 7/24/83 GO ~/82) RECEIVED DATE ,, mmi$$[j~evelopment Geology A~aS;i:n,l & Gas~;ons, Go ~ell Records TP1-5 -" A,~ch0m~e SOHIO ALASKA PETROLEUM COMPANY S?O ARCO - CHEVRON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE 19071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 ~o SFO/UNIT/STATE: (-Marathon) EXXON GETTY MOBIL PHILLIPS 7/26/83 Date: Trans. #: - 74603 CC#: STATE BPAE (Transmittal Only) _ CENTRAL FILES (CC#'s - Transmittal Only)_ REFERENCE: SO~LI~FINAL DATA - PRESSURE SURVEY DATA /cTohfollowing submitted herewtth. Please acknowledge receipt by signing a material being y of this letter and returning ~t to this office:-- A-29f BHPD & Pressure Analysis 6/01/83 , Camco B-18'-~ Pressure Survey 7/07/83 Otis B_19L~ ,, " 7/05/83 Otis B-20" " " 7/09/83 Otis B-21~ HP Pressure Analysis 7/11/83 Camco B-22 .- ~ " " " 7/03/83 Camco B_23~J ,, " " 6/25/83 Camco D-6~ Pressure Survey 7/12/83 Otis G-3 J"~ " " 7/12/83 GO Q-3~ HP Pressure Analysis 7/07/83 Camco R-10 / HP Pressure Analysis 7/08/83 GO R-16/ BHPD & Pressure BU Survey 6/6-7/83 Dres X-3--~ BHPD & Pressure Analysis 6/20/83 Camco X-9 / BHPD & Pressure Survey 6/04/83 GO X-16/ BHPD & Pressure Survey 5/18/83 Otis X-17z Pressure Survey 5/11/83 Otis X-17 BHPD 5/24/83 Otis X-17 Pressure Survey 5/22/83 Otis Y-2~ BHPD & HP Pressure Analysis 5/15/83 Camco Y-6/ Pressure Data 7/07/83 GO :4/82) RECEIVED DATE Victoria Aldridge Development Geology Well Records TP 1-5 SOHIO ALASKA PETROLEUM COMPANY 3111 ' C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL POUCH 6-612 ANCHORAGE, ALASKA 99502 July 20, 1983 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well B-18 (34-30-11-14) Enclosed, in duplicate, are the following forms for the above-named well. le e e GJP/J~H/pjw Enclosures cc: Form 10-407, Completion Report; Form 10-403, Sundry Notice and Reports on Wells; Form 10-404, Monthly Report of Drilling and Workovers. ly, 'G J~ P isga ~ Distrzct Petroleum Engineer J. D. Hartz Geology Well File #17 ECEIVED Anchorage 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 Company 82-2 / 3. Address .......... 8 APl I~lumber ..... Pouch 6-612, Anchorage, Alaska 99502 50_029-20702 4 Location of well" at surface 9 Unit or Lease Name 344' SNL, 1892' WEL, Sec. 31, TllN, R14E, OPM (corrected) Pcudhoe Bay Unit At Top Produc,ng Interval top of Sag R. SST. ~o W~lI Number - 388' NSL, 1618' WEL, Sec. 30, TllN, R14E, OPM B-18 ..(34-30-11-14) PBU ,, At Total Depth 11 Fmld and Pool 485' NSL, 1431' WEL, Sec. 30, TllN, R14E, OPM Prudhoe Bay 5 Elevation ~n feet (ind~cate KB, DF, otc ) 6. Lease Designation and Serial No Prudhoe ~il Pool KBE = 73.75' AMSL ADL 28310 12 Date Spud;led 13 Date T D Reached 14 Date Comp. Susp or ~'l~'and ('i5 Water Dep~:h. ,f offshore 16 No of comPiet;0ns 5/11/82 5/21/82 5/25/82 ,I .. feet MSL .... Pile 17"TotaiDepth(MD+~vO) 18 PI~'g Back Depth (MD+TvD) 19 D,rectl0naISurve¥ I 20 Depth where SSSV set I 21 ThlcknessofPermafro'~t '" 9410'ND 9239' ~WCD 9338'ND 9169'~'v'D YES ~ NO [] 2020 [ feet MD ~ ~ 22. Type Electric or O~her Logs Run .DIL/BHCS/GR/SP, CBL/VDL/CC~/GR, Gyroscopic survey ........ - .... 23 CASING, LINER AND CEMENTING RECORD 'S'ETTING DEP'I~H MI} ............ CASiNGSIZE,WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" x '~0"Insula'te~lC~au~.~l -~,,~f.~c,. ...... 110"' 3~" 8 cu.yds, con. crete 13 3/8" 72# L-S0 S,lrf_~ .... 269~6' 17 ]/O"i ~gn ~=~11 ~" ~'~=~--e=eJkt"' II . .. 9 5/8" 47# .... L~80 Surfac~ 8585.' 1~' 174~ [i55,, cu. Zt.. Class G. . .. 130 cu. ft. Arcticset[ I 7" 26~ L-80 808(~' .i g4{3_K' 8 1/2" 390 ~%Aeft- Class G ~/iR~ 24. Perforat,ons open to Production (MD+TvD of ToP"and Bottom and 25 ' TUBING RECORD ,nterv.l. s,ze and number) ~ ~lrDss SiZE '" E~EPTH SET' {~'D) .~KER SET (MD) .... - 5 1/2" .......8136i ..... ' .... ' ' 71~'93' ....... Prudhoe Oil Pool top: 9090' 8856, ............... Bottom: 9147' 8911' 26 .... AC'ID, FRA'CTURE,'CEMENT SQUEEZE, ET(~ ......... DEPTH INT'E'RVAL (MD) 'AMOUNT ~&'I~IN6 bF MATERIAL USED 9090' - 9116 ' BEB (8856 ' - 8881 ' T'v'Dss) .................... _' 9120' - 9147' BKB (8885' - 8911' ~%~DSS) ............................. 27 PRODUCTION TEST Date F,rst Product,on Meth°d of Operat,on iFl°wmg, gas hft, etc.) June 29, 1983 . I Flowing -Date o~'T'Bst HOURS Tested PRODUCTION FOR~ OIL-BBL GAs-M~F WATER-BBL CHOKE S ' Z EI GAS-OIL RATIo iTEST PERIOD I~ , . Fllo~ TublIIng Casing P;essure II cALCuLATED OIL-I~BL GAS'McF WA~EIR-BBL 'lOlL ~RAVITY-API '(corri ................... Press. 24-HOUR RATE 28 ............. corE DATA ....................... Brief description of hthology, porosity, fractures, apparent dips an'~l presence of oil, gas or ware r submit core chips. .oneQECE ¥ED Atas~a 0d & Gas Coas~ ~ornrn~$ior~ A~chorage ...................... Form 10-407 Submit m duplicate Rev 7-1-80 CONTINUED ON REVERSE SIDE 29 30 GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all flu,ds recovered and gravity, MEAS DEPTH TRUE VERT DEPTH GOR, and t~me of each phase BKB Subsea Sag River SST. 8630' 8414' Shublik 8660, 8443, :. Ivishak 8740 ' 8519 ' 31 LIST OF ATTACHME~ITS None / ~-~, 3:2 I hereby cert~f~ that ~he foregolng~ true and correct to the best c~f my knowledge / ,' - ~ ' .- -) S,g.~/ / '¢..L.L.~ (~¼lt~2~% TmeDistr. petroleum Date -9 f G.' J. Pli,Sga ~/ ,:nglneer I NST R UCTI ONS 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 ~n other spaces on this form and in any attachments. Item 16 and 24: If th~s 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 ~nterval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas L~ft, Rod Pump, Hydraulic Pump, Submersible, Water In- iectlon, Ga~ Iniect~o~, .q.F,,. ~_~. OtSer-explain STATE OF ALASKA ALASKA ( _ AND GAS CONSERVATION C([ MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] '1 2. Name of Operator 7 Permit No. Sohio Alaska Petroleum Compar,~ 82-2 3. Address 8. APl Number Pot.cb 6-61£, ;~,r~ct~c~g~ ~3_~l~a _c,.c'50;' S0_029-20702 4. Location of Well At Surface: 344' SNL, 1892' WEL, Sec. 31, TllN, R14E 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number B-18 (34-30-11-14) 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. KBE = 73.75' AMSL J ADL 28310 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool PBU NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit ~n Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] . Perforations r-~ 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 w~th 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 were perforated June 29, 1983, using Dresser Atlas 3 1/8" carrier guns at 4 s.p.f. A lubricator was installed and tested to 3500 psi on all well work. 9090' - 9116' BKB (Ref. BHCA/GR, 5/22/82) 9120' - 9147' BKB ( " ) An SSSV was set and tested in the ball valve nipple at 2020'. 14. I hereby ~e~~egolng is true and corr~t to the best of my knowledge. / / S.gn~/~~J ~~ TltleDiStriCt Petroleum Engineer Date 7/~/~ · / ' Condmons of A~val, ~f any By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Tnphcate and "Subsequent Reports" in Duplicate ALASKA OIL AND GAS CONSERVATION C MMISSION --- MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS J I Drdlmg well ~ Workover operauon r-I 2 Name of operator 7 Permit No Sohio Alaska Petroleum Company 82-2 3 Address 8 APl Number Pouch 6-612, Anchorage, Alaska 99502 50_029-20702 9 Umt or Lease Name Prudhoe Bay Unit 4 Location of Well at surface 344' SNL, 1892' WEL, Sec. 31, TllN, R14E, UPM 5 Elevation m feet (~ndtcate KB. DF. etc ) KBE = 73.75' AMSL 6 Lease Des,gnat,on and Serial No ADL 28310 For the Month of July ,19 83 10 Well No B-18 (34-30-11-14) PBU 11 F,eld and Pool Prudhoe Bay Prudhoe Oil Pool 12 Depth at end of month, footage drdled, f~sh,ng jobs. d~rect~onal drdhng problems, spud date. remarks 13 Castng or hner run and quantities of cement, results of pressur9 tests 14 Coring resume and brtef descrtpt~on 15 Logs run and depth where run 1 6 DST data, perforating data, shows of H2S, mtscellaneous data See Attached 17 I here ha g ,s true and correct to the best of my knowledge SIGNED// '" f TITLE Distr. Petroleum ~.ngineeroATE . NOTE--Freport on t~,s~orm ts requged for each calendar rn°n~h, regardless 0,' the s~atus of operat',ons, and must be f,le~V~m du'(cate w,,h the Alaska Od and Gas ConserVa~T0n Commtsston by the 15th of the succeeding month, unless otherwise d~rected Form 10-404 Submit ~n du0hcate Rev 7-1-80 PERFOPATING DATA - Well B-18 (34-30-11-14) PBU June 26, 1983: Pressure ~ested tubing and inner annulus. June 29, 1983: Rigged up Dresser Atlas and perforated the following intervals using 3 1/8" carrier guns at 4 spf: 9090' - 9116' BKB (Ref. BHCA/GR, 5/22/82) 9120' - 9147' BKB (Ref. BHCA,GR, 5/22/82) Put well on production. July 5, 1983: Shut well in to prepare for static pressure survey. July 7, 1983: Ran static pressure/temperature survey at 8800' TVDss. July 8, 1983: Set and tested SSSV in ball valve nipple at 2020'. Well on production. SOHIO ALASKA PETROLEUM COMPANY Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 3111 'C STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL POUCH 6-612 ANCHORAGE, ALASKA 99502 May 9, 1983 Attention: Mr. C. V. Chatterton Wells B~18 t~rough B-23 and B-25, C-18 through C-28, and D-16 through D-23 (excluding D-19) Gentlemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wells. This contains our proposal to perforate these wells. GJP:JLH:pjw Enclosures CC: J. D. Hartz Geology Well File #17 ._Dist~ Petroleum Engineer RECE VEO MAY }L 2 983 O~ & Gas Cons. 6ommiss!o~ Anchorage STATE OF ALASKA ALASKA O~ AND GAS CONSERVATION CC( ~llSSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] COMPLETED WELL [] OTHER [] 2 Name of Operator 7 Permit No. Sohio Alaska Petroleum Company 82-2 3 Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20702 4. Location of Well At Surface: 344' SNL, 1892' WEL, Sec. 31, TllN, R14E, UPM 5 Elevation in feet (indicate KB. DF. etc.) KBE = 73.75' AMSL 6. Lease Deslqnatton and Serial No ADL 28310 9. Umt or Lease Name Prudhoe Bay Unit 10. Well Number B-18 (34-30-11-14) PBU 11. F~eldandPool Prudhoe Bay Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit tn Trtphcate) (Submit ,n Duplicate) Perforate I-~ Alter Casing [] - Perforat,ons [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pull,ng Tubing [] (Note. Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and g,ve pertinent dates, mclud,ng estimated date of starting proposed work, for Abandonment see 20 AAC 25 105-170) The following intervals will be perforated during June/July, 1983, using 3 1/8" carrier guns at 4 spf. A lubricator will be installed and tested to 3500 psi for all well work. 9090' - 9116' BKB (Ref. BHCA/GR, 5/22/82) 9120' - 9147' BKB ( " ) 9156' - 9166' BKB ( " ) An SSSV will be set and tested in the ball valve nipple at 2020'. *Contingent interval, to be perforated if well will not sustain flow. RECEIVED MAY 1 2 1983 er~~th~'~~e ~[tyo~m No./~C-~ D~t~ Alaska 0il & Gas Cons. Commission S~.~t W o'k G~o~te~ ~~~ Anchorage 14 I h going ~s true and corr~t ~o the best of my knowledge, · ~e ~e~o~ ~r C~,~,on u~ Condmons of Ap~, ~f an~ ORIGINAL $1Gfl£9 8Y LOTl;',1E C. SMITH Approved by COMMISSlONER Approved Copy Returned .5'../3 . By Order of the Commission Form 10-403 Rev 7-1430 Submit "Intentions" in Tnphcate and "Subsequent Reports" ,n Duphcate ( SOHIO ALASKA PETROLEUM COMPANY OFFICE CORRESPONDENCE TO. Bill Vail Ale/1 DATE 3-10-83 FROM Anne Jones cc NO Well ~cords, DeveloFment Geology SUBJECT YOUR REF Magnetic Tape listing Enclosed is a copy of the program verification listing for well B-18. Our apologies for not sending this to you. Anne Jones Well Records Development Geology AK3407-1 (7/81) s/s AK1009 OS SOHIO ALASI;,", PETROLEUM CO;'.":PAr~Y ARCO lO. EXXON PHILLIPS CENTRAL FILES(CC#' s-Transmittal Only_ 124109 3111 "C SIqEEI AI,'CHOI{AG[, ALASKA 1ELEPHONE 1907) 265-0000 MAIL' POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 1-12-83 Trans.#: 2005__ CC~: 56005 REFERENCE: MAGNETIC LIS TAPES & LISTINGS he following material is being submitted herewzth. Please acknowledge receIpt by signing a copy of this letter and returning it to this office:-- ~d * B-18 0.~ DIL/BHC/AL/Cg~C~ 5/22/82 t/- 1317 :ected * ~12 CH CN/q~ ~1/82 ti- 1341 Tape Pos.~~~ -- 02105 Dre~ 01817 Dr~s. lCi~tjng above means you should hav~ *SFO: . An Asterisk:(*) next to a ~'~/o}z e respective service co-~any. received the Tape(s)an ,~L~i~g($) directly Please confirm this. ~ R~CEZV[D ................ ~:;~'"~[~,~. /"~' ~ Development Geology ~ ;as Lj,"~ Well Reco rd s ..... - ............ "~t0~I SOHIO ALASI;A PF. TROLEUM CO;:~PANY SFO ARCO EXXON TO PHILLIPS CENTRAL FILES (CC#' s-Transmittal Only 3111 ' C SlqEET ;,fdCHORAG£. ALASKA TELEPHONE (907) 265-0000 MAIL' POUCH 6-61 2 ANCHORAGE, ALASKA 99502 Date: 1-12-83 Trans.#: 3005 CC#: 56005 ]orrected * B-18 Copy) Corrected * J-12 Copy) REFERENCE: /~~IO ~GNETIC LIS TAPES & LISTINGS ,~e following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- Tape Pos. OH DIL/BHC/AL/CD/CN, 5/22/82 #- 1317 02105 Dres. CH CN/GR 6/11/82 #- 1341 01817 Dres. a/82) *SFO: · , received the Tape(s) an~tj, ng(~)~.rectly Please confirm this. RECEIVED .......... An Asterisk:(*) next to a listing above means you should have from the respective service company. Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 C' STREET ANCHORAGE ALASKA TELEPHONE (907) 276 5111 MAIL POUCH 6-612 ANCHORAGE, ALASKA 99502 July 8, 1982 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well B-18 (34-30-11-14) PBU Enclosed find final well logs for the above-named well. These were not available at the time Form 10-407, Well Completion Report, was sent to you on June 25, 1982 Very truly yours, District Drilling Engineer RHR:MM:yr Enclosures cc: Well File #17 Geology SOHIO ALASKA PETROLEUM COMPANY SFO ARCO' CHEVRON EXXON . 3i 11 "C" STREET ANCHORAGE. ALASKA TELEPHONE 19071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 zo: SFO/UNIT/ GETTY . STATE: MARATHON MOBIL PHILLIPS *STATE OF AK BPAE (Transmittal Only) .EFEREN~NTRAL FILES(CC#'s-Transmittal Only) Date:7-7-82 Trans.#: 1703 CC#: 49703 * Date to State Via Drilling: 7-7-82 (surveys- 6-24-82) The SOHIO OPEN HOLE ,FINAL LOGS following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- S FO / UNIT / STATE: ,. B-18 Dres DIFL #1 5-22-82 5" B-18 Dres BHC #1 5-21~82 5" B-18 Dres CDL/GR #1 5-22-82 5" B-18 Dres CDL/CNLog/GR #1 5-22-82 5" B-18 Dres GR #1 5-22-82 5" & 2" & 2" & 2" & 2" & 2" STATE ONLY/ p'/~('~/~_~ _DIRECTIONAL SURVEYS: ~ 5-14-82 to / Magnetic Single Shot ?irectional Survey J Date= 5-23-82 Job#: 0582-023 ( Gyroscopic Directional Survey j Date: 5-29-82 Jobt/: Boss-16039 - "--- ,, , --D'%/ ,v- - ! u--~-'- ~UL - 8 1~o~ Development Geology o^Tc Mz~k.~ 0it & ~s O~n~. Commission Well Records knchorage ( SOHIO ALASI~P, PETROLEUM CO;':"..PANY SFO ARCO EXXON PHI LLI P S CENTRAL FILES(CCtt's-Transmittal Only 31 1 I "C ' STqEET ANCHORAGE, ALASKA TELEPHONE {907) 265-0000 MAIL POUCH 6-612 ANCHORAGE, ALASKA 99502 Da te: 6-30-R2 . Trans.t!: 1690 CC//: 49690 ',/82) REFERENCE: SOHIO MAGNETIC LIS TAPES & LISTINGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- , Ta~e Pos. j-5/ 6/12/82 OH-DIL/BHC/FDC/CNL/GR 65227 01804 6/10/82 CH-CNL 64216 01805 5/31/82 CH-CNL 65173 01806 5/29/82 CH-CNL 65200 01807 5/24/82 OH-DIL/BHC/FDC/CNL/GR 65205 01808 5/30/82 CH-CNL 65172 01809 6/11/82 CH-CNL 65215 01810 · 6/12/82 CH-CNL 65217 01811 6/11/82 CH-CIqL 65220 01812 6/10/82 CH-CNL 65221 01813 6/11/82 CH-CNL 65222 01814 5/18/82 CH-CN Multispaced ECC '1307 01815 5/22/82 OH-DIFL/CDL/BHC/CN ECC 1317 01816 6/11/82 CH-CN Multispaced 'ECC 1341 01817 *SFO & EXXON: An Asterisk:(*) next to a listing above means you should have received the Tape(s) and Listing(s~[~'.e~T~.~rom the respective service company· / ~~1/~, ~9 We~Z Records DATE ,~,c~,~ ~ ~; "' .~-~ , -'- , ' b~,i~o. L '."r'~;~0q / ,/ 1, SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 June 25, 1982 Alaska Oil & Gas Conservation Corm%ission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: Well B-18 (34-30-11-14) P.B.U. Enclosed in duplicate is Form 10-407, Completion Report, for the above-named well together with the Well History and Directional Surveys. Well logs printing/processing has been delayed and they will be forwarded under separate cover when received. This well has been completed as a non-perforated oil well. Very truly yours, RHR:jm encs Well File 917 Geology District Drilling Engineer 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 Company 82-2 3 Address 8 APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20702 4 Location of well at surface 9 Umt or Lease Name 344' SNL, 1892' WEL, Sec. 31, TllN, R14E, UPM (c~. Prudhoe Bay Unit At Top Produc.ng Interval top of Sag R. SST.LU~^i~U~l 10 Well Number VERIFIEDI 388' NSL, 1618' WEL, Sec. 30, TllN, R14E, UPM~ . B-18 (34-30-11-14) At Total Depth Sur[ ~_--~----t 11 F~eld and Pool 485' NSL, 1431' WEL, Sec. 30 TllN, R14E, UPM B.H~_J~---J Prudhoe Bay 1 ' 5 Elevation ~n feet (md~cate KB, DF, etc ) 6 Lease Demgnat~on and Semal ~o Prudhoe Oil Pool F~E = 73.75' A~S~, ADT, 28310 12 Date Spudded 13 Date T D Reached 14 Date Comp , Susp or Aband I 15 Water Depth, ~f offshore 116 No of Completions 5/11/82 5/21/82 5/25/82I feet MSLI one 17 TotalDepth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 DirectlonalSurvey I 20 Depth where SSSV set I 21 Thickness of Permafrost 9410'MD 9239'TVD 9338'MD 9169'TVD YES~ NO[]I 2020 feetMDI 2095' 22 Type Electmc or Other Logs Run DIL/BHCS/GR/SP, CBL/VDL/CCL/GR, Gyroscopic survey 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20"x30" Insulated ConductorSurface 110' 36" 8 cu.yds, concrete · . 13 3/8" 72# L-80 Surface 2696' 17 1/2" 3720 cu.ft. Arcticset II , 9 5/8" 47# L-80 Surface 8585' 12 1/4" 1155 cu. ft. Class G; 130 cu.ft. Arcticset I 7" 26# L-80 8080' 9405' 8 1/2" 390 cu.ft. Class G ~/18% salt 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 5 1/2"" 8136' 7993' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27 PRODUCTION TEST , Date F~rst Production I Method of Operation (Flowing, gas I~ft, etc ) I , ,Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-el L RATIO TEST PERIOD II~ , ~ Flow Tub~.,ng Casing Pressure CALCULATED .k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 24-HOUR RATE .... 28 CORE 'DATA -Brief descmptlon of I~thology, porosity, fractures, apparent dips and presence of od, gas or water Submit core chips None RECEIVED JUN 2 5 982 A!3$ka. Oil & Gas Cons. Commismon Anchorage Form 10-407 Submit ~n duplicate Rev 7-1-80 CONTINUED ON REVERSE SIDE __ 29 30 GEOLOGIC MARKERS FORMATION TESTS NAME Include mterval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT DEPTH GOR. and tlme of each phase BKB Subsea Sag River SST. 8630' i' 8414' Shub lik 8660 ' 8443 ' Ivishak 8740 ' ' 8519 ' 31 LIST OF ATTACHMENTS Well History, Well L_ogs, Directional Surveys S:2t2/~,~ I hereby cert~f~ that the foregomg ~s true and correct to the best of my knowledge S,gned T,tle District Drilling Date ~-- b~ < ~ R. H. Reiiey Engineer INSTRUCTIONS General This form ~s designed for submitting a complete and correct well completion report and log cn all types of lands and leases in Alaska. Item 1 Classification of Serwce Wells: Gas injection, water injection, steam ~njection, a~r injection, salt water disposal, water supply for injection, observation, injection for in-s~tu combustion. Item 5 Indicate which elevation ~s used as reference (where not otherwise shown) for depth measurements g~ven ~n other spaces on th,s form and in any attachments. Item 16 and 24. If th~s well ~s completed for separate production from more than one interval (multiple completion), so state ~n item 16, and in item 24 show the producing intervals for only the interval reported in ~tem 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such ~nterval Item 21 Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23 Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27 Method of Operation Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- WELL B-18 (34-30-11-14) PBU WELL HISTORY Spudded well at 2100 hours, May 11, 1982. Drilled 17 1/2" hole to 2700'. Ran 68 its. 13 3/8" 72# L-80 Buttress casing to 2696'. Cemented with 3720 cu.ft. Arcticset II cement. Installed and tested BOPE. Cleaned out to 2652'; tested casing to 3000 psi, okay. Drilled out to 2737'; ran leak-off test to 0.84 psi/ft, gradient. Directionally drilled 12 1/4" hole to 8600'. Ran 222 its. 9 5/8" 47# L-80 Buttress casing to 8585'. Cemented in two stages: First stage with 1155 cu.ft. Class G cement; second stage through D.V. packer at 2607' with 130 cu.ft. Arcticset I cement preceded by Arctic Pack. Cleaned out D.V.; tested casing to 3000 psi, okay. Cleaned out float equipment and directionally drilled 8 1/2" hole to 9410'. Ran open hole logs. Ran 33 jts. 7" 26# L-80 IJ4S liner to 9405'. Cemented with 390 cu.ft. Class G cement with 18% salt. Cleaned out to 9338'; tested casing to 3000 psi, okay. Changed well over to NaC1; ran CBL. Ran 180 jts. 5 1/2" 17# L-80 A/B mod. Buttress IPC tubing to 8136'. Landed tubing with ball valve at 2020'. Installed and tested tree. Displaced tubing to diesel. Set packer at 7993'. Tested tubing to 3500 psi, okay. Released rig at 0730 hours, May 25, 1982. RECEIVED AI~ska Oil & Gas Cons. Cu,.m;smorj Anchorage SOHIO ALASKA PETROLEUM PAD- B (:34' :.'50- II- 14) B'I8 Controlled Drilling Consultants LES HENDERSON 349-3114 7608 Highlander Drive Anchorage, Alaska 99502 (907) 349-3114 May 24, 1982 Mr. Brian Rose Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, AK 99502 RE~ Magnetic Single Shot Survey Job No. 0582-023 Well B-18 (34-30-11-14) Prudhoe Bay Field North Slope, Alaska Date of Survey: 5-14-82 to 5-23-82 Dear Mr. Rose: Please find enclosed the "Original" and six (6) copies of our Magnetic Single Shot Survey on the above well. The method used in calculating this survey was Radius of Curvature. The depth of the survey was 5716 to 8530. Thank you for giving us this opportunity to be of Service. Yours very truly, Controlled Drilling Les Henderson Directional Supervisor COHPLETION REPORT SOHIO A L A S K A "-F~i~SL E-U M ......... MAGNETIC SINGLE SHOT SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION RECORD OF SURVEY 21 MAY 82 WELL B-18(34-30-11-14) KB. ELEV. 73.75 TRUE HEA$;-D~.~TVE~TZC~L - DEPTH ANGLE DEPTH D M 0 0 0 , O0 -73,75 SEA DIREC DEG. N , OOE 6668 21 30 6975 21 0 .... 7'410 '-1-~'-'" 0 79'4~I 16 O 82~;2 1 ~ 3 0 85:3'0 17-:30 6629,9i 6556, 16 6916,03: 6842,28 783t.i4 7757.39 8129,72 8 055.97 5716. O0 5642.25 N · OOE "56q5~;~ --5'~';~I7 ..... N -4.00E 5946,34 5572.59 N 3, OOE N 3.0OE N-5. OOE N 6.00E N 5,50E Ht-i; OOE N27. O OE N41, OOE N~. O OE BOTTOM HOLE CLOSURE 809,11 FEET AT N TOTAL COORDINATES ,00 S .00 W ,00 9,03 23,88 61 I20,40 2.46,54 357,25 5O4.43 654.89 726.86 78 O. 57 S .00 W N .32 E N J.22 E N 3.15 E N 7.32 E N 19.47 E N .30.61 E N 51.95 E N 1 03.76 E N 1.52.31 E N 2i.3.01 E 15 15 49 E CLOSURES DISTANCE ANGLE D M .OO S 90 0 S 0 W .00 S 90 0 0 W 9.03 N i 59 59 E 23.91 N 2 55 59 E 120.63 N 3 28 45 E 247.31 N 4 30 52 E 358.56 N 4 53 52 E 507.09 N 5 52 49 E 663,06 N 9 0 1I E 742.65 N 1t 50 4 E 809.11 H 15' 15 49 E DOG LEG SEVERITY DEG/!OOFT ,000 .000 5.070 5.337 2.229 1.888 ,619 .164 .479 .610 .397 .~06 DISTANCE ,00 23.36 118.0~' 242,97 352,71 65: 74 t. 32 S 09. fl- SINGLE SHOT SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE MEASURED VERTICAL SUB MD-TVD DEP TH ......... DEP TH SEA -'-D-i~-~-ERENCE VERTICAL CORRECTION TOTAL COORDINATEB 174 ........ i~: .......... fd'O - 0 274 274, 200 0 374 374. 3O0 0 4~4 -- ~7-4-, 400 - 0 574 574. 500 0 674 674. ~00 0 874 874. 800 0 974 974~ 900 0 i-074 ........ TO-dO4, 1000 - 0 1174 1174. 1100 0 1274 t274. 1200 0 0 1474 1474, t400 1574 1574, i500 1774 t774. 1700 1874 1874. 1800 2074 2074. 2000 2t74 2174. 21 O0 2274 227-4. 2374 2374. 2300 2474 2474. 2400 2674 26?4, 2774 2774. 2700 2974 2974. 2900 30?4 3074. 3000 317~ ~74-.- 3100 3274 3274. 3200 3374 3374. 3300 ~4-/~ -- 3474. --~3~-00 3574 3574. 3500 .00 S .00 $ ,00 S ,00 S .00 $ .00 ~ .00 S .00 S ,00 S .00 S ,00 S .00 S ,00 S .00 $ .00 $ .00 S .00 S ,00 ~ .00 S ,00 S ,00 S ,00 S ,00 S .00 S .OO $ ,00 S ,00 S ,00 S ,00 S .00 S .00 8 .00 S .00 S ,00 $ .00 S .00 W ,00 W .00 W ,00 W ,00 W ,00 W ,00 W .00 W .00 W .00 W ,00 W ,00 W .00 W .00 W .00 td ~00 Ed .00 W .OO W .00 W .00 W ,00 W ,00 W ,00 W ,00 W .00 W .00 W .00 W .00 W ,00 W ,00 W ,00 W .00 W .00 W .00 W ,00 W SOHIO WELL B-I8 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN TRUE NEASURED VERTICAL SUB HD-TVD DEPTH " DEPT~ -~BA DfFFERENCE SINGLE SHOT SURVEY 100 FEET OF VERT I OAL CORRECTION SUB SEA DEPTH, TOTAL COORDINATES 21 MAY 82 3674 - 3674, ---3600 3774 3774, 3700 3874 3874. .3800 4074 4074. 4000 4174 4174, 4~00 4374 4374, 4300 4474 4474, 4400 4674 4674, 4600 4774 4774. 4700 4974 4974, 4900 5074 ~OF4, 5000 ~7~ '5'174'. --S f 00 52?4 5274, 5200 5374 53~4 , 5300 5S74 5S74. 5S00 5674 5674. 5600 ~74~ S~, 5874 58?4, 5~00 5976 5974, 5900 6~83 6174. 6t O0 6288 6274, 6200 650~ 6474. 6400 6608 6574, 6500 6822 ~F?4, 6700 ~9~0 6874. 6800 -7037 ...... 697 4, ~ ~-00 7144 7074, 7000 0 0 ,00 0 0 ,00 0 0 .00 0 0 ,00 0 0 .00 0 0 ,00 '- 0 0 ,00 0 0 ,00 0 0 .OOS 0 0 ,00 0 0 .00 0 0 ,00 0 0 .00 0 0 .00 0 0 .00 0 0 .00 0 0 ,00 0 0 ,00 ~' 0 0 .00 0 0 .00 0 0 .00 0 0 1.48 0 0 11.06 2 2 29.85 5 3 54,33 9 4 82.92 t4 5 115.25 20 6 150,45 27 7 186,96 33 6 2,24,75 - 4! 8 263.69 48 7 302.54 55 7 341,06 63 8 37'.3.1[ .3 69 6 416,18 .00 I~ .00 W .00 W .00 W .00 W .00 W ,00 W .00 W .00 W ,00 W .00 W .00 W ,00 W .00 W .00 W ,00 W .00 W ,00 W ,00 W ,O0 W ,00 W ,02 E ,45 E 1.54 E '2.82 E 4,47 E 6.89 E 10.02. E 1.3,46 E ~7.22 E 2t.26 E 25,23 E 29,0:5 E 32.87 E 37,39 E SOHIO WELL B-iS SINGLE SHOT SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH ..... DEPTH SEA-~D-I~-~ERENCE CORRECT I ON 7462 7374, 7300 7672 7574, 7500 7777 7674, 7600 7985 7874, 7800 eoee ?'~z4, zeoo ~4 ............. ~ 074'; ~-~'0 8298 8~ 74. 81 O0 8402 8274, 8200 OF SUB SEA DEPTH. TOTAL COORDINATES 452, 16 N 487,05 N 520,80 N 553.07 N 583,75 N 612.75 N 640, 03 N 665,72 N 690,44 N 714, I3 N 736,57 N 757, SO N 42., 66 E 48,64 E 55,37 E 63,50 E 73,11 E 84.07 E 96,26 E 1 09,52 E 124,57 E 14'I .77 E 161.12 E 183.01 E 207,3:8 E 2t MAY 82 SOHIO WELL B-18 8INGLE SHOT SURVEY INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, HEASURED D-i~P--T-~ TRUE VERT i CAL SUB TOTAL COORDINATES 1 000 ! 000, 926° . O0 ::3 ~rO-OD- ....... -20-00. !9-247, , O0 $ 3000 3000. 2926, ,00 8 4000 4000, 3926, ,00 S 6000 5997, 5923. 35.19 N 7000 6939. 6866, 366,14 N .00 ,00 .00 .00 .00 1,82 31.49 t11.50 June 1, 1982 Mr. Gary Plisga Sohio Alaska Petroleum Conl0any Pouch 6-612 Anchorage, Alaska 99502 Re: Our Boss Gyroscopic Survey Job No. Boss-16039 Well: B-18 (SEC31 TllN R14E) Prudboe Bay Field North Slope, Alaska Survey D~te: May 29, 1982 Operator: Marvin Milam Mr. Plisga: Please finc enclosed the "Original" and sixteen (16) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager KB/pr Enclosures F'¢~GE t Ii~A]'E OV -Z, UF<VEY MAY jJLI':,':, I,~,¥11~.]'~ L I-Ir'l i[. '31JRVIEY ,_lOl:~ IxlLIHB~LR :BOS:S-:t I'.I:LLY L~LI'£,IIZNC; ELEV. 7_::. 75 FT. OPE [-,:A-F OF;:--M 1 LI:~P1 1 I '. ,'=,'; t~. c30 0. O0 0.1 '-~ E -0.64 (.). '3 :_:: I£ - J . ::,:": 0. '=,' F:, E. -'_::. 1 4 1. E:/1- E. -4·40 -' (:)J- E. SC'I-t I 0 ALA _:;~. APE YR _,LE,.. P, C. AVIF'r-~I'.t; r-i--} ::: ( 5_, E C' ':: .",. ] ~ I(t ~-,; 1,1 E ~ .... r'fTiJj IHChr': E~ '¢ ALASI A WELL '-~ '""" v (~IL:.~ L.U~IFANY ,JUNIE J, L'~U.'_' VERTJ Ch'~L SECTICd~i CAI_C'ULh TED ALUNG,..~_,_,"' '-""_,,_.,=r.~"~" F'AGE .2 DATE 01-- SURVEY MAY~:Y,-"- lO~q-'- ,_._ BOS, S C, YROSCOF'iC SLIRVEY ,_lOB NUMBER BOSS--160.39 I.'ELLY BU'_:,t~ING ELEV. = Ot:'E~-~ TiSI (;-:~i I LAM 73.75 FT. T u 7 ~L RI.:C I'ANGULAI7 ~.' OuRI] ]: NATES NORTi-I/:::F~LI 1'~1 EAST/NE.:,] VERTICP~ SECT I 0,. ,) t'-) 0. "-:0 C'. 14 O. O. 25 0.34 (] ,, -39.08 -39.56 -40.07 .... -40.72 "l.t/ E ~'.o. ?1 E 20.2') -42. _ -4 3.24 -44, 27 20. O0 k. I'-). 67 E I9.40 E -44.93 -45 ~ 1 -46.22 l'y. 0::: E I8.7,:.' E ,18.4'.? E j,-, .=,::: 19,17 E 19. '~0 E 2u.22 E :'o. 76 L ,_'1. 17 E ..... :-'i-:-F(':, E -46.98 - 47.55 -47. '--/4 - 48.44 -49.03 -49.58 -50 · 04 -- 50.06 -4:3. ::,6 ....... i -r_- ',-," L -4~,. -.'5 ANC:I IORAGI.: AL h'.,I.A "' _ ..... Tt (;::l ,' T t C, l:_ ,z ':F CIN CAL C 11LA T ILO ;:L' Ii'II, I- I..C': Ur ': - DATE ~'lF. ::,[_IF(VEY_ HAY ,~.~,"-"- F'AGE CIJlbtt-'l_l]","l'[ 1CIN [:ATE II: I ' :, ,. ,.:NI. : i':':': "' BOSS GYld)'.:,LOF'IL SLIRVEY ,Jl]D NLIPIBL.]F( GOS'_',- 160'--:'0 ~.ELL',' [C.I':,H.TNG ELEV· = OF'ERA FOR-M.[ LAM 7:' 75 Fl' ~l · ,, Th:I.IF, '-,I IL'-:,EA L ('~!_tl ~".E,t..F l'",-, -,: 1171. :'t VI_R: TF:"L tYlEr( F r ' "' ,,_ '-, L ~ :,_ t k~i- L I NAT [ Lh',l ~;-F' TI ~ F:EF"TH Er[j: 'Fl I DI-G t-I I N ::. OI IR'7,1. [ u'3~:-LEG '1 01 Al_ LI £1d_C i ,I :iN '?L VL'I? LTY F,'[.'CThNGULAk< C I u_iRLI INA FES ::Il.-Gl <[- I~'z, LIE b/t Uo NL'IR'FI ~/:E, OLI'[ H EA:z;T/WEF:T VERT I C A. · :,E -.T I Oiq -39.5 I -°2-,. 02 -13· O1 ,:., 4 T, :,_,. 13 64.45 97.02 I31,29 0, '" L/-, .-:, L-':'] l,l 4 c-,. 15 L-.' C',"'7 200..::': hi 5O.5D E O. 73 :'...',4,. '., ' lq 5,1.40 L£ 165. 1 ':/9. o 1 -'33. 16 4:]: "44 N 5:R (.).. E 27 ... _. ::~)7 7/., N 61 '- '= . ,, _ ,. :;] ._1 E 342..:-:6 t'4 66. J3 E L:/ 37o.0'v hi z(').'?3 E 0 ,, I ,, 2::: 4(")'-?. / N /-' .... ,4 E. ,{:_] '4J.5t. N :3i:. :':/1. E 0. 0 · 76 4.72..37: N 91 . .~':'" E '.,'4 50 J · 7'3 N ',:~'y..30 E Zl ,I- ~' "" .-':,~.~. 04 N ] 07. '::~ E 3'-74. ':'/U 426. --:9 457 · 14 4P/ ::--.'3 ':Z, 515.71 E E F L t.'_,'/ .L:,'_,/.OL: {I 1 LT.'Sly E 1,, 16, q:::::.6,7 N 1,:';.17 E l. ::7 60L,. ':'.3 l:..l i 4._' · 49 E 1.06 62'P. 73 N 157. ,'::5 E i.'30 651.60 I',l 17'3. o4 E 1 ,, .S'6 67 ;.:. ',-'/'? N .1 93 · 22 E L ~ 6 7 ' '; C: 'q 4.04 72. U4 5'P'). 72 6...6. :::6 654.04 :B 2, 10 71 (') "= · -2 _t 7.3'°. 32 7,"55. ,'-,4 -/,.%,t'~ F'AGF.: 4 982 [ I,;t. 1!- ':-'11,~ _ . _ ";IS A':,UI,'~ 'L]VIER FtC6L VERI rc , f ~. r hll. [ t NAT J l.'li',l Ii £ RlZr F f Olu '-ri t Lff-_F' T1 ~ DEI-"I-I-~, tiE" r_~ t"l ! I',1 IIE. GF,'F.t. '-=, _ . ,IAB hll.IM E415 I:( f:ITLLY l=.:LIC, l-I] big E"LE~, = c, pb R?\-~ i.;)i C I",f~ Lnl,1 73.7.5 FT. I.,.~G Ir:o, , ,I,:VI=R [ ]- 'r' DEb/ 1.00 7 U] F~l.. t (rzc F/1Nc~IJLAI ( E OrjI (IJ I NAT Et:; N 0 R T H / ':; 0 U TH12 ri c_, r / t4 E'_=; T VERTICAu SEL'T I ON 317, c,., E i:4,:-'. 62 E 3o6.68 E ::'.-'/0. 08 E ,I1.,". ~11. 813.69 8o6, 84 ..~.~ ~46.83 948, 99 ~t'_-~iR/Z¢¢I,I~';1L DF'E,I-'L,.~C. EP, I£11? ='-,i;' ,"' i,r~ I AF ~lr ,~'l-ll "'; l:l..f',. ,,[ fi[Pl, l:{y~,l- rfl~- ,.ri'_i !.ii-it'l 1U,'l r-'RqC~;.,J~¢:'-, "',rTr~ t'r~";Ci, C. rr,~-'I]-IE U'E.E Cfi" 'rl ll:,,l=lZ ,[.~1}1[ J-xE:';:['Cilt,h'-"-',L RADII I:=; uk L'LIRVATLU:RE METHOD, IC,~.,/1L,,L AL F 'JI'iF'IJT;4 F1F!N Lh '~'I l- ,_il J I~I~_ L . L' ,; ,.'q -' DA1% I)F '£,[tlRVEY MAY 29, ,JOB I~lLIhlUI IR P. ELLY BU.':,I-I1NC~ ELEV, = CIF'EI:Ri-I I-OR -M I LAM PAGE 1 7B. 75 FT. t')~,~, ....... r r:,. f OF ?u A':I q-'r:O._._..,, rt~'l''~..:, PI U -.-T VEl Li I F'FERENC, E VI-- R r I I."AL C'ORWEL'} .I. ON c). 00 0. , , , ~ .. " ........ I I'~F]N':':IONF~L R,d,II I':, FJl- L'I. IRVATLIFCE METHOD. DATE F~r'_ ,,_,~v'~:. t MAY .~..", [:'AGE 7i:. 75 FT. INTERF:'FfL..,.':'~T,-r3 VOLL'Z'-b FOR EVi:'N ! 1 v EIR 1' I ~' Al_ F.C~RR[.IZ. f 1 O1'4 O, t')L~ O. 0:] O, O0 1 I ,_t[INI.Z J. ? ~ o5; "' DATE OI .... L, LIRVEY MAY 29~ ,_ FiB i',II_IMBLR BO':";'-],- 1/_:-,F) '..:'? I:ELLY BLI':',1111'.113 ELEV. "= t:: E:.l(,fl] [,.IR-MILAM F'AGE 7 7,:-:. 75 FT. %1 t!:',. · ,F ,"s ]'~ i't Al ~ ~7-i-:T 1-7 NO!-~711/':;OLI] t I 1Z,:~", 1 /ld[ :5 1 D [ I::FI£R-~-JxlCI~ ',.,'Eli r IF'AL C F[RI:,tEC'T 10iq '5. :'.'", E 0.2::3 0.01 0.01 O. 02 O. 04 O. 05 O. 05 O. 05 }. I ~., [: O, 5'., O. O!5 7.,/,7 I' 0.5'? 0.04 -'. L:',:I f. 0 ,,/:," O. (..z, DATE OF :£:URVEY MAY ~--~ dOD Nt.I ~,- , ' -,o MF c..R BlISS- I/_-,0,:,~ k'ISLI_Y BIj'_:,I~ING ELEV. = Cff':'E RA TOI';~-M I L ~1"! PAGE 7:3.75 FT. IN]LI;,'POLNFED VALLIES FOR EVEN 10o !:FF:'F IJt Stl ""' ' B-.:,.E A DEF'TI~t I RLtE r{;I.l.tT:--'{,l_ ~"1, Jill] "I_ hi ,h'].; lr:'rt~ V/£I'R"F~ F'~L L,'EF,'] TI',]I ~.q!--"I t'61'h}l.!~ '"'' iL' ;i];lrl [l'hi ""'1,1D 1'~,'O Il.. 7,, - - - tTM /'TFt -" ~.IFPT-T~ !;ISI "1 j'l ..... x-h~]il~Tii/::,~-d-L~ J'l i ..... 1~]~1-i-7~L:-S F I, ITFF'ERENC. E vr:'l~:l' I r NL L OI'~NECT I ON 0. O0 O. 6? O. 70 0.70 o. O0 O. O0 0. O0 6:00 0.00 0.0i O. 7.1 C). 7 I u. 72 0.7:' O. / -'. ' 0 O. } :: O. 72 O. 73 O. 74 O. 75 O. O0 0.01 0.00 O. O0 0.00 O. O0 0. O. O0 O. O0 O. O1 0.01 O. O0 ' ,:'IqT,.~ Pt A'.:.,~'A F'r:T!--,,'CrI_EUP! [C'I"PAr ', 'BF'EF'RY- E:UN WELL L:[LIt<V[ Y ]NG F.OMF'ANY CI'rFiF'L!I,',TI L]~'I L'A t'r: , tLINE .1.., DATE OF =,LRVEY MAY ,JOB NUMBER BO'5'B- 1/_-,0 :-.:'.-? k'I-iLL. Y I3LI'_:;[~I:NG ELEV. = OF'ER(I I CIR-Iq ] LAM PAGE 1 '.~82 7:::. 75 FT. fit Cf: ;.~,'%. 4 Ii r, ,..4 ~,1. I ',-" .:,L B-.:,EA D[LF'TH ".LE :, FOR £EVITl,,I tOq f EIZT ~]1:- ,'-I ,"' f'l!' D.F i']'! F ] -<U[:.. ' ,I tU-' VFER T I L"AI_ UI:RT r ,: ,'-',t_ -- -'-D<'=7 q7 ............ j:!:]'"YN fRI-_-C Ti] l',,tl:,Lil_r"lf:( F Oc~!?D l i'h l'l [."., NUI,'I H/'- '~ ,:,IL U] H LAG, I/WI/5] M!]..- TVD IL~ I F F EF~ENC:.E V£:R F I C AL C. OR~(ECT 1 ON 0 .. 0 0 0. t) 7 O. 77 1.98 -' O5 4.05 5.36 o. /8 7.64 7. /.48 7. t7 .Z,, :1.:"; 6,.54 /,. -, 5.16 ",t-fi, I '[ Fi ~'-IL~C,I',¢'~ F'FT::dld~E1JM, [2 Fd I'J iF' RJ4L,.') C CIhil::'t.lT Ii I t C!lq L]£~ FL: ,Jl. li,,il'i I, t 5:;32 DATE OF -' I ' - 29, ::,L RVEY MAY ,.IOI3 NLIMBE[< .~F'-'- [ --I'=l :l- 1 t' (~ i!I '? ..LLI_Y BU'_:,~t.[NG ELEV, = UFEI-~A]UR MILAM 73.75 FT. :rhiTFlkr, JLA . _ I ' ..... ',,~I .... ~!:..., F~3F.' E~.;r{N I0,} Fr:[T 01:' :3UB-SEA EEFTH I ~,~- q':,; ~I dZL' ..... UFFTI r ] Rl. lr :,,'F F,' T £ C ,'~L VERT I CAL CORRECT I ON '7 6 7 ~:"; 7' 'q-~-r 'rqt' :' 'j 7r:]7 .:-,'. 75 7500 ,. O0 7773, '75 7 s"o C',, 0 L' 71--171-I -~= 'TI:.F'(] ,-', ~ / .~1 ~ - · i e -- · - ,: - 7.3.75 81%3 2,t '.d6 E i36.67 ,-'7C',0:' F J4t.62 ,0o. Z d 4 .0']. _ N l'J '~>' 75i - ~< ........... ]Ti-&V: --,=,:., (~,~ 757 -"~ N '"'"'-' 87 . ..... :, ~ :,.. o. g 15c) 52 .,, ~t'~ 77,}. 15"; 1'.1 '::4'F;. AO E ~ 54.62 ,, ':" ~ ,'::: 3.6,6 N ::/4. -"5 F J ~2.L:. 4 4 . '3t' 7':'/,. '1'1 N 3'~C:. ,I. 3 E 1. ~1. ' . J. I .0'3 :::q'--'~ 0 :: N '~1] "t':O E 165" :5,t o,.,,-, 46 N 46~ OA E t71 4] 4.73 4.4:3 4. '"1 4.10 '3.04 '-' ':;9 4.43 4.97 5.1.2: 4.95 4./.:,2 4.2,°, 4.10 3.6,7 3.4 8 '3.53 2.29 - ~_i']~JY"Tq - c i NEdR t NTIZIRFu3L. A]l FJN ¢. r F,'~ fi-1 RFIO [UC, OF f URVATLIRE) F'O I NTC, ,( Sohio Alaska% croleun Company Our Boss Gyroscopic Survey Job No. Boss-16039 Well: B-18 (SEC31 TllN R14E) Prudhoe Bay Field North Slope, Alaska Survey Date: May 29, 1982 Operator: Marvin Milam Scale: 1"= 250' TRUE NORTH · oo Surface Location (344SNL 1892WFL) 25QI. QO l_250. O0 9410 HORIZONTAL PROJECTION Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ~ bp~ratOr,~WelI Name and Number Reports and Materials to be received by: ~..' ~ Date Required Date Received Remarks · .... Ccmpletion Report ... Yes Well History Yes ~_~,~, ~ .... Core ~scription , ~.~ ~ ~.~ .......... ~, - ~/~ Registered Su=ey Plat ~/~c~ / -- m, , Inclination Sudsy 4~.'~ ...Drill Stm Test Returns /t d/;'*~ = .............. ~ ~/ ,, , /~Pr~u~ion Test Re. rte ~_ MEMORAt DUM Stat! of Alaska ALASKA_OIL AND GAS CONSERVATION COMMISSION TO Chatterton _DATE May 24, 1982 Chai~ '-' FILE NO 108A/$ THRU: Commissioner FROM Bobby Foster%~ Petroleum Inspector TELEPHONE NO SUBJECT Witness BOPE Test on Sohio's B-18 Sec. 31, TllN, R14E, UM Permit #82-2 Thursday., May 13, 1982 - I traveled this date to Prudhoe Bay' and witnessed the BOPE test on Sohio's B-18. As the attached BOPE inspection report shows there ~ere two failures. These failures ~ere repaired and tested while I was on location. In mammary I witnessed the BOPE test on $ohio's B-18. 02-00 lA(Rev.10/79) O&G ~4 (" STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector '~pera Well Date ' '" Well Representative ~~ Permit Location: Sec Drilling Contractor Location, General Well Sign General Housekeeping Reserve pit Rig nOPE Stack Annular Preventer / Pipe Rams c~ Blind Rams / / Choke Line Valves H.C.R. Valve / Kill Line Valves 4 Check Valve / Test Pres sure .:5% ° o /y~casing Set @~ 46. , ft. Rig ~~Representative.~g ~-/'/P~-.-5~/ ACCUMULATOR SYSTEM Test Results: Failures Full Charge Pres sure ~~O psig Pressure After Closure /d-t]~.~) pslg 200 psig Above Precharge Attained: - mind.sec Full Charge Pressure Attained: ~ mit /~sec N2,=~Q,~o°~ ~.Q ;~O) D~O%,~3~psig Controls: Master ~~ Remote ~3 Blinds switch cover Kelly and Floor Safety Valves Upper Kelly / Test Pressure ~~ Lower Kelly / Test Pressure ~~ Ball Type / Test Pressure ~/ ~ Inside BOP ] Test Pressure ~./ ~ Choke Manifold ~ Test Pressure ~OO No. valves /7 No. flanges ~ ~ Adjustable Chokes ~ Hydrauically operated choke / _ _ Test Time ~ hrs. Repair or Replacement of failed equipment to be made within ---, days and Inspector/Commission office notified. Distribution orig.' - AO&GCC cc - Operator cc - Supervisor I n s M~o R, H. Reiley District Drilling Engineer Sohio Alaska Petroleum Company Pouch 8-612 Anchorage, Alaska 99501 Re~ Prudhoe Bay Unit B-IS 8ohio Alaska Petroleum Company Pex~ni t No. 8~t*~ Sur, Loc.~ 347*8~, 1895*WEL, flee 31, TIIN, R14E, UPM, ~tt~ole ~e.: 889aNaL, 168S*~, See 30, TI1N, RI4E, Dear M~. Reiley~ Bnclosed is the approved application for permit to drill the above re~ferenced wel 1. Well samples and a mud log are not required, A continuous direotional sul*vey, is required as per 20 AAC ~lS.0$0(b)($). If available, a tape containing the digitised log information shall be outmaitted on all logo fo]~ copying except experimental '10gs, velocity ~rvey$ and dtpmeter surveys. 'Ma~y rivers in Alaska and their drainage systems have been c essified as important for the spawning or siltation of anadl~omous fish. Operations in these areas are subject to AS 16.$0,870 and the resmlations promulgated thereunder (Title S, Alaska Administrative Code). Prior to commencing operations you my be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 48, ~apter ~J, Article ? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter ?0) and by the Federal Water Pollution Control Act, as amended, Prtot~ to ~ ¢ Mr. R. H, lbiley Prudhoe Bay Unit B-18 January ?, 19a~ commencing operations you may be contacted by a representative of the D~partment of Environmental Conservation, To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudd®d, We would also like to be notified so that $ repre- sentative of the Coam~iesion my be present to witness testing of blowout preventer equipment before surface casing shoe is drtl led. In the event of suspension or abandomnent, please give this office adequate advance notification so that we nay have a wi rheas preoont o Very truly yours, Harry W. Kugl · Cmmmisaloner of j~ pRDP~a OE TH~ Alash Oil a Gao ~nse~ation ~ission Eno 1 o sure ocs Department of Fish & Game, Habitat Section w/o anal. Department of Environmental Conservation w/o/encl. SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL POUCH 6-612 ANCHORAGE, ALASKA 99502 January 5, 1982 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well B-18 (34-30-11-14) Enclosed are the following documents, in triplicate, for the above-named well together with our check for $100.00 to cover the permit filing fee. 1. Application for Permit to Drill, 2. Proposed Drilling Program Outline, 3. Blowout Prevention Equipment Diagram & Diverter Diagrams, 4. Surveyor's plat showing well location, 5. Directional Map. If you have any questions, please contact either R. H. Reiley at 263-5183 or K. W. Kolthoff at 263-5176. RHR:ja Enclosures cc: Well File #17 Yours very truly, District Drilling Engineer RECEIVED 19g ! Alaska Oil & Gas Cons. Commiss~or~ Anchorage SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL POUCH 6-612 ANCHORAGE, ALASKA 99502 January 5, 1982 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well B-18 (34-30-11-14) In accordance with Prudhoe Bay Field Rules and Sohio Alaska Petroleum Company's policy for drilling the first well on a pad expansion, a 20" hydril and diverter system will be used when drilling the surface hole on PBU Well B-18 (34-30-11-14). B-18 will be the first well drilled on this pad in 1982. A permit has already been submitted for B-lA (22-31-11-14), requesting that the surface hole be drilled without a diverter. If shallow gas is not encountered during the surface hole of B-18, a waiver for installation of a diverter will be requested for the remaining B-pad expansion wells, including B-lA; other- wise we will submit a revised drilling permit to include a diverter on Well B-lA. Yours very truly, R. H. Re iley District Drilling Engineer RHR: ja PERMIT TO DRILL 20 AAC 25 005 la Type of work DRILL [] lb Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2 Name of operator Sohio Alaska Petroleum Company 3 Address Pouch 6-612, Anchorage,_Alaska 99502 4 Location of well at surface 9 Umt or lease name 347' SNL, 1895' WEL, Sec. 31, TllN, R14E, UPM Prudhoe Bay Unit At top of proposed producing interval (target) 10 Well number 700' NSL, 1700' WEL, Sec. 30, TllN, R14E, UPM B-18 (34-30-11-14) At total depth 11 F~eld and pool 889' NSL, 1665' WEL, Sec. 30, TllN, R14E, UPM Prudhoe Bay 5 Elevation m feet (indicate KB, DF etc ) I 6 Lease designation and serial no Prudhoe Oil Pool Est. KBE = 75' AMSLI ADL 28310 12 Bond information (see ~0 AAC 25 025) Type Blanket Surety and/or number Safeco Ins. 2975387 Amount $200,000.00 13 D~stance and d~rect~on from nearest town 14 D~stance to nearest property or lease line 15 D~stance to nearest drdlmg or completed. NW of Deadhorse 10mdes east of ADL 28286 3296feet well B-6 1500feet i6 Proposed depth (MD & TVD) 17 Number of acres m lease 18 Approximate spud date 9558'MD 9305'TVD feet 2491 April 5, 1982 '"i9 If dev,ated (see 20 AAC 25 050) J20 Ant,c,pated pressures 3330 pslg@ .... Surface KICK OFF POINT 6000 feet MAXIMUM HOLE ANGLE 24 oI (see 20 AAC 25 035 (c) (2) 4390 ps,g@ RRI10 ft T/,J~(TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 36" 20x30 Insulat'.ed Conductor 80' Surface ll0'J 110' 8 cu.yds, Concrete 17 1/2 13 3/8 72# L-80 Butt. 2680' Surface 2680'I 2680' 3720 cu.ft. Permafros' 12 1/4 9 5/8 47# L-80 Butt. 8559' Surface 8559'1 8392' 1155 cu.ft. Class G; ~ 130 cu.ft. Permafros~ 8 1/2 7 26# 5-80 IJ4S 1499' 8059' I~ 7936' 9558' iI 9305' 365 cu. ft. Class G 22 Describe proposed program W/18% salt See attached proposed drilling program outline. RECEIVED 6 lqfl2 Alaska 0il & Gas Cons. Commission Anchorage ~;3/}l.b~reby ~ertffy that~st of my knowledge ,fr. SIGNED mlTLEDistrict Drilling EngineeDAmE The space below for Commission use R. H. Reiley~ CONDITIONS OF APPROVAL Samples required Mud Icg required D~rect~onal Survey requ,red J APl number J o_o Permit number Approval date " ~;q'-"~" 01/07/82 I SEE COVER LETTER FOR OTHER REQUIREMENTS ,,. · _T~r.,..~. 7, 1982 ' /' - / by order of the Commission ~S II C Form 10-401 Submit in trlphcate Rev 7-1-80 ( PROPOSED DRILLING AND COMPLETION PROGRAM WELL B-18 (34-30-11-14) Dry bucket 36" hole to 80' below ground level and cement 20" x 30" insulated conductor to surface using 8 cu.yds, concrete. Install diverter and drill 17 1/2" hole to 2700' and cement 13 3/8" 72# L-80 Buttress casing to surface using 3720 cu.ft. Permafrost II cement. Blowout prevention equipment consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer from 13 3/8" casing point to T.D. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12 1/4" hole to 8392' TVD. Run 9 5/8" 47# L-80 But- tress casing to 8392' TVD and cement first stage with 1155 cu.ft. Class G cement. Cement second stage through D.V. packer collar at 2600' with 130 cu.ft. Permafrost C cement. 9 5/8" casing will be hung at surface; the 9 5/8" x 13 3/8" annulus will be Arctic Packed. Drill 8 1/2" hole to T.D. at 9305' TVD. Cement 7" liner to 500' inside 9 5/8" casing shoe with 365 cu.ft. Class G cement with 18% salt. Run 5 1/2" 17# L-80 IJ4S IPC tubing with 12 gas lift mandrels and a production packer assembly at 7890' TVD. A subsurface safety valve with dual control lines will be placed at 2120'. 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. JAN- 6 ~Jaska 0il & Sas Cons, Anchorage .B,.O.B STACK C:.ONFI,GUF~.T, ION 1:5 5/8" TRIPLE RAM STACK 5000 PSI WP DRILLING .iI ANNULAR PREVENTER PIPE RAMS BLIND RAMS CHECK KILL GATE LINE GATE DRILLING SPOOL 4" CHOKE LINE GATE HYDR. ASST. GATE PIPE RAMS RECEIVED JAN- 6 1982 Alaska Oil & Gas Cons. Commissio~ Anchorage FLOWLINE [- DRILLING RISER ;ROUND LEVEL -- I IH II ! 10-3/4" EYDRAHAIC 12" 20" 2000 PSI WP ANNULAR PREVENTOR DRILLING SPOOL 20" CONDUCTOR PIPE DIVERTER SYSTEM DETAIL DRILL. DEPT. MARCH 1980 lit i _'1 NOTE: DIVERTER LINE HAS TWO DIRECTION DISCHARGE CAPABILITY AFTER LEAVING RIG SUB-BASES. SgR~ACE HOLE Di~,'E]~i~_R SYST-~d Two lines venting 90° apart -- 10 3/4" manual butterfly valves 1. All pipe connections 150~ ANSI Flanges or welded connections. Manual 10 3/4" butterfly valves, safety wired i]~ open pisit]on at diverter line tee. ~ 10 3/4" 55,~ Buttress 10 3/4" Hydraulic operated Butt~er fly valve ' · 20" Diverter Spool w/10 3/4" Side Out/et. JAN- 6 ],982 ~aska Oil & Gas Cons. Commission. Anchorage ! =0 i 40n;c~lOi~ 20 , =0 ,. 40 I '0 :' =° i ~° i 4° I , '; B-~9 ~ .... ~ CP~opose~ [ 7 ~PrOposed) ~ , 1700' ! ~ T :' ....]- - , ~ , ~:~ ' I LAT, · 70° 1~'14.05": .... ~ ........ ~ ....... ~ ~ ..... t LO~I~= ~0' S2.~~ - SCALE I "= I/2 MILE ~RTIFICATE OF SURVEYOR FLARE PIT T. IIN. T. ION. SUMP i.$o- 11-14) - $o. I/- PAD, DETAIL SCALE t"= 300' I hereby certify that lam properly registered to practice land surveying in the State of Alaska and that this plat represents a location survey of the wellpad shown and the wells thereon. This survey was made by mede under my supervision and all dimensions and other details are correct. Bottom hole locations are furnished by others. bec. Date Sheet 3 of 3 REVISE B-18 8 B- 19 BHL RECEIVED JAN- 6 ]9~,2 Naska Oil E Gas Cons. Commi: Anchorage (~L~I /S/82 PAD "B" EXTENSION Located in rveyed for SOHIO ALASKA PETROLEUM CO. Surveye, ~Jon F.M. LINDSEY I~ ASSOC. LAND & HYDROGRAPHIC SURVEYO'RS 2502West Northern Lights Boulevard Box 4-081 Anchorage B-18 INTERSECTION~ SCALE: 1 "= 100 : 4358' TVD BKB B-~18: 7071' TVD BKB ~OP ~700" goP 28oo' CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. 1, ~, ~. ITEM APPROVE DATE (1) Fee ~/__ /-~l, (2) /2 thru 8) (3) Admin ~,-~ ~g thru 11) (4) _Casg (12 thru 20) (5) BOPE (21 thru 24) (6) Add: 9~ 10. 11. YES NO 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line ................. 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... 12. Is conductor string provided ........................................ 13. Is enough cement used to circulate on conductor and surface ....... 14. Will cement tie in surface and intermediate or production strings 15. Will cement cover all known productive horizons .................. 16. Will surface casing protect fresh water zones ................. 17. Will all casing give adequate safety in collapse, tension and b~rst. 18. Is this well to be kicked off from an existing wellbore ..... // ...... 19. Is old wellbore abandonment procedure included on 10-403 ..;~ ....... 20. Is adequate well bore separation proposed ............. ../ ......... / 21. Is a diverter system required ........................ / ............. 22. Are necessary diagrams of diverter and BOP equipment/~ttached ...... 23. Does BOPE have sufficient pressure rating - Test to/ .......... psig . 24. Does the choke manifold comply w/API RP-53 (Feb.7~.777]]777i'. ...... 25. Additional requirements ...................... /~ ..................... Additional Remarks: REMARKS Geology: ~q~ineering: HWK LCS BEW WVA JKT RAD JAL~~_ rev: 03/10/81 INITIAL [ GEO. UNIT ON/OFF POOL CLASS STATUSI AREA NO. SHORE CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee //~~F'~ ?~_~ wgl.. (2) Loc ~2~ thru 8) 2. Is well to be located in a defined pool .............. 3. Is well located proper distance from property 4. Is well located proper distance from other wells . i ' °'.''. 5. Is suff±cient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party 8. (3) Admin ~/~ ~-'~% 9. ythru 11) 10. 11. (4) Casg ~ .I/~/~Z (12 thru 20) (5) BOPE ~ //~/M2- (21 thrd 24) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 1. Is the permit fee attached ........................................ (6) Add: YES NO Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings .. Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached . .. Does BOPE have sufficient pressure rating - Test to 3-~)O ~si'~ .~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. REMARKS Additional Remarks: Geolog. ~.' Engin~_$~e~_e in~.- ~ , WVA ~_ JKT ~ RAD----- JAL .~~ rev: 03/10/81 INITIAL l GEO. UNIT ION/OFF POOL CLASS STATUS AREA NO. SHORE Well History. File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify 'finding information, information of this nature is accumulated at the end of the file under APPEN. DIXi No special'effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * RECEIVED * * .............................. JUL 1 ~ 1998 ~ ............................ . * ....... SCHLUMBERGER ....... t ............................ _~ask~ Oi~ & (~as Cons. Commission .............................. ~omge COMPANY NAME : BP EXPLORATION WELL NAME : B-18 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292070200 REFERENCE NO : 98333 % 8-JUL-1998 11:09 PAGE: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/07/ 8 ORIGIN : FLIC REEL NAME : 98333 CONTINUATION # : PREVIOUS REEL : COMF~EN~f : BP EXPLORATION, B-18, PRUDHOE BAY, API# 50-029-20702-00 **** TAPE HEADER **** SERVICE NAME '. EDIT DATE : 98/07/ 8 ORIGIN : FLIC TAPE NAME : 98333 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : BP EXPLORATION, B-18, PRUDHOE BAY, API# 50-029-20702-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: B- 18 API NUMBER: 500292070200 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 8-JUL-98 JOB NUMBER: 98333 LOGGING ENGINEER: S.DECKERT OPERATOR WITNESS: A. COLEFiAN SURFACE LOCATION SECTI ON: 31 TOWNSHIP: 1 IN RANGE: 14E FNL: 344 FSL: FEL: 1892 FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: 73.75 DERRICK FLOOR: 72.75 GROUND LEVEL: 45.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8.500 7. 000 9405.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) % 8-JUL-1998 11.09 PAGE: 2 LIS Tape Verification Llstlng Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. 88888.0 9180.0 9168.5 9150.5 9119.5 9118.5 9089.0 9088.0 9080.5 9076.5 8960.5 8958.0 8955.0 8945 5 8934 5 8920 0 8915 5 8908 5 8898 5 8896.5 8893 5 8892 5 8878 5 8853 5 8845 0 8839 5 8829 0 8819.0 8806.5 8805.5 8794.0 8785.0 8778.5 8777.5 8767.0 8753.5 8746.0 8738.5 8718.5 8707.0 8696.5 8689.0 8686 0 8679 5 8664.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GR CH TDTP .............. 88887.5 88887.5 9179.5 9179.5 9168.0 9150.0 9150.0 9119.0 9088.5 9119.0 9088.5 9081.0 9081.0 9077.0 9077.0 8962.0 8962.0 8959.5 8959.5 8956.0 8956.0 8946.0 8946.0 8935.5 8935.5 8921.0 8921.0 8917.0 8917.0 8910.0 8910.0 8900.0 8900.0 8898.0 8898.0 8895.0 8895.0 8880.5 8880.5 8855.5 8855.5 8847.0 8847.0 8841.5 8841.5 8831.5 8831.5 8821.0 8821.0 8808.0 8795.5 8787.0 8780.5 8769.5 8756.0 8749.5 8741.0 8720.0 8709.0 8698.5 8691.0 8687.0 8681.5 8666.0 8808.0 8795.5 8787.0 8780.5 8769.5 8756.0 8749.5 8741.0 8720.0 8709.0 8698.5 8691.0 8687.0 8681.5 8666.0 % 8-JUL-1998 11:09 PAGE: 3 LIS Tape Verification L~st~ng Schlumberger Alaska Computing Center 8659.5 8661.5 8659.0 8661.5 8653.0 8655.0 8655.0 8634.0 8635.5 8635.5 8630.5 8632.5 8632.5 8618.5 8620.0 8620.0 8613.0 8616.0 8616.0 8600.5 8602.5 8602.5 100.0 102.0 102.0 $ REMARKS: CONTAINED HEREIN IS THE TDTP DATA ACQUIRED ON BP EXPLORATION WELL B-18 ON 22-FEB-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT TDTP PASS #1 GRCH TO THE BASELINE GAM~A RAY PROVIDED BY THE CLIENT; AND TDTP PASS #1 SIGM TO THE BASELINE GAF~IA RAY. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and cl~pped curves for each pass in separate files. PASSNUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUiVlF~ARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9205.0 8595.0 TDTP 9230.0 8595.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE' PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~OL6~ $~D ~£~£ 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~0£6~ $~D ~£ 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~OL6~ S~D ~£0£ OND£ 0000000000 89 ~ r r r 0 O0 000 O0 rOL6£rr S~D ~£0£ ~O£ 0000000000 89 ~ r r r 0 O0 000 O0 rOL6Srr SWD 0000000000 89 ~ r r r 0 oo 000 oo roL6srr s~o d£~£ 0000000000 89 ~ r r r 0 O0 000 O0 rOL6£r[ SdD d£0£ 0000000000 89 ~ r r r 0 O0 000 O0 roz6£rr OD ~£0£ 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~0£6~ 8£0£ 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~OL6~rr OD ~£0£ H~I£ 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~0£6~ OD ~£0£ DDI£ 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 [OL6~rr OD 8£O£NIq~S 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 rOL6~r[ OD ~£0£ 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 [OL6Srr S-OW ~£0£ IH~£ 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~0£6~ OD ~£0£ ~I£ 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~0£6~ £~ (X~H) ~OOD W~q~ WI4~S ~I41'IN OOW SS~"ID ~X£ DOq # ~O~IO OI SS~DO~8 ~ ~ZIS gWON ~I40N ~I~ I~ IS~ IW~ I~ ~DIA~S ~INO A~S ~Ia~N ....................................................................................... 0 99 0 ~ 99 9~ 89 99 0 99 89 ~ 99 .r.~q ~9 6 £ '0 89 8 £9 £I. 9 99 I 99 88 6£ 0 99 0 99 i~tl'YIVA ~JOOD Hd~H ~dA,L ~ CHOD~ NOI£VDIWIDSWS £VI4~0~ V£VO ~ V£VG £V~HOX 'V£VG SIH~ 0£ C~I~WWV ~H~L~ S~IHS ESVd 0£ SSVd ON 'r# SSVW W£C~ HO~ V£VC C~£D~qIOD I{Ld~G GA~V ~ddI~D SH~ SNIVJ~NOD ~qI~ SII-I~ ~ :~DVd 60:rr 866r-~flp-8 ~ LIS Tape Verification L~stlng Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... TSCF TDTP CPS 1159701 INND TDTP CPS 1159701 INFD TDTP CPS 1159701 GRCH TDTP GAPI 1159701 TENS TDTP LB 1159701 CCL TDTP V 1159701 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9229 SBHN. TDTP 71 SDSI. TDTP 0 TCAF. TDTP 11797 TSCF. TDTP 2627 TENS. TDTP 1373 DEPT. 8597 SBHN. TDTP 52 SDSI. TDTP 1 TCAF. TDTP 5295 TSCF. TDTP 350 TENS. TDTP 1271 500 SIGM. TDTP 13. 298 TPHI. TDTP 29. 632 SBHF. TDTP 405 SIGC. TDTP O. 339 SIBH. TDTP 104. 013 TRAT. TDTP 310 BACK. TDTP 142.123 FBAC. TDTP 40. 538 TCAN. TDTP 336 TCND. TDTP 19973. 621 TCFD. TDTP 6609. 628 TSCN. TDTP 555 INND. TDTP 2100. 846 INFD. TDTP 321.223 GRCH. TDTP 000 CCL. TDTP 0. 000 · 000 SIGM. TDTP 44. 770 TPHI. TDTP 62. 809 SBHF. TDTP · 028 SIGC. TDTP 0.162 SIBH. TDTP 64.217 TRAT. TDTP · 356 BACK TDTP 145.776 FBAC. TDTP 30. 674 TCAN. TDTP · 913 TCND. TDTP 14413. 396 TCFD. TDTP 3459. 853 TSCN. TDTP · 727 INND. TDTP 1650. 815 INFD. TDTP 307.289 GRCH. TDTP · 000 CCL. TDTP O. 000 58. 613 1. 803 27177. 762 6053· 150 - 999· 250 47. 029 1. 752 21194. 004 1277· 794 51.3 61 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE 8-JUL-1998 11:09 PAGE: 6 % LIS Tape Verification Llstlng Schlumberger Alaska Computing Center FILE HEADER FILE AU3M~ER: 2 EDITED CURVES Depth shifted and cl~pped curves for each pass in separate flies. PASS NUMBER: 2 DEPTH INCREF~ENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9205.0 8595.0 TDTP 9230.0 8595.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: i BASELINE DEPTH .............. 88888.0 9213.5 9179.5 9178.5 9168.0 9151.5 9150.0 9139.0 9136.0 9133.5 9119.0 9118.5 9109.0 9088.5 9076.5 9073.5 9054.5 9035.5 9017.5 9014.0 9013.0 8989.5 8980.0 8963.5 8960.5 8960.0 8954.5 8944.5 8936.5 8934.5 8932.0 8920.0 8919.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88888.5 88888.5 9214.0 9180.0 9179.0 9168.0 9152.0 9150.0 9139.0 9136.5 9134.0 9119.5 9119.5 9110.0 9089.0 9089.0 9077.0 9074.5 9055.5 9035.5 9017.0 9015.0 9013 0 8991.0 8981.5 8965.5 8965.5 8962.0 8961.5 8956.0 8946.5 8938.0 8938.0 8936.0 8933.5 8933.0 8921.5 8921.0 8-JUL-1998 11:09 PAGE: 7 LIS Tape Verification Llst~ng Schlumberger Alaska Computing Center 8915.0 8917.5 8908.5 8910.5 8908.0 8910.0 8899.0 8900.5 8896.0 8898.5 8894.0 8895.5 8892.5 8895.0 8879.5 8881.0 8875.0 8878.0 8852.5 8855.0 8854.5 8850.0 8853.5 8845.0 8847.0 8844.0 8846.5 8840.0 8842.0 8839.0 8841.5 8830.5 8832.5 8829.5 8832.0 8819.0 8821.5 8818.5 8821.0 8806.5 8808.5 8806.0 8809.0 8794.0 8796.5 8785.0 8787.5 8784.5 8787.5 8778.0 8780.5 8766.5 8769.5 8769.5 8753.0 8756.0 8745.5 8749.5 8738.5 8741.0 8737.0 8740.0 8736.0 8739.0 8728.0 8730.5 8723.0 8723.5 8718.5 8722.5 8715.0 8717.0 8711.0 8713.5 8706.5 8709.0 8704.0 8706.0 8696.5 8698.5 8691.5 8694.5 8686.0 8687.5 8685.0 8685.5 8679.5 868O 0 8664.0 8666.0 8660.0 8662.5 8658.5 8661.5 8633.5 8635.5 8631.0 8634.0 8630.0 8632.5 8619.5 8622.0 8617.0 8617.5 100.0 102.5 100.5 $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA 8-JUL-1998 11:09 PAGE: 8 LIS Tape Verification L~st~ng Schlumberger Alaska Computing Center FOR TDTP PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT TDTP PASS #2 GRCH TO TDTP PASS #1 GRCH; AND TDTP PASS #2 SIGM TO TDTP PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 8-JUL-1998 11.09 PAGE: 9 LIS Tape Verification L~st~ng Schlumberger Alaska Computing Center NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... TSCN TDTP CPS 1159701 TSCF TDTP CPS 1159701 INND TDTP CPS 1159701 INFD TDTP CPS 1159701 GRCH TDTP GAPI 1159701 TENS TDTP LB 1159701 CCL TDTP V 1159701 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9230.500 SIGM. TDTP 13.014 TPHI.TDTP 27.355 SBHF. TDTP SBHN. TDTP 65.970 SIGC. TDTP O. 745 SIBH. TDTP 89. 896 TRAT. TDTP SDSI. TDTP 1 . 135 BACK. TDTP 122. 672 FBAC. TDTP 29. 030 TCAN. TDTP TCAF. TDTP 2618.514 TCND. TDTP 3993. 955 TCFD. TDTP 1378. 649 TSCN. TDTP TSCF. TDTP 585.918 INND. TDTP 341.146 INFD. TDTP 74 . 832 GRCH. TDTP TENS. TDTP 1354. 000 CCL. TDTP O. 014 DEPT. 8595. 500 SIGM. TDTP 42. 482 TPHI. TDTP 61. 704 SBHF. TDTP SBHN. TDTP 54.309 SIGC. TDTP 2.379 SIBH. TDTP 69.390 TRAT. TDTP SDSI. TDTP 3. 156 BACK. TDTP 86. 999 FBAC. TDTP 20. 226 TCAN. TDTP TCAF. TDTP 1320.610 TCND TDTP 3234.134 TCFD. TDTP 771.285 TSCN. TDTP TSCF. TDTP 78. 881 INND. TDTP 314. 686 INFD. TDTP 57. 850 GRCH. TDTP TENS. TDTP 1255. 000 CCL. TDTP 0. 000 61 945 1.752 5856.940 1310.547 -999.250 44.271 1 713 5273 311 301. 341 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Llst~ng Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE: 10 FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass ~n separate f~les. PASS NUMBER: 3 DEPTH INCREFIENT: 0 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9205 0 8575.0 TDTP 9230.0 8575.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 9212.0 9199.0 9179.5 9179.0 9152.0 9150.0 9147.0 9139.0 9119.0 9118.5 9106.0 9088.5 9087.5 9082.5 9076 5 9076.0 9073.5 8990.5 8990.0 8971.0 8968.5 8964.0 8963.5 8960.0 8958.0 8957.5 8955.0 8954 5 8937.0 8933.5 8932.0 8931.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. 88888.0 88888.0 9212.0 9199.0 9180.0 9179.0 9151.5 9150.0 9147.0 9139.0 9119.0 9119.5 9107.0 9088.5 9088.5 9083.0 9077.5 9077.0 9074.0 8991.5 8991.0 8973.0 8970.5 8965.5 8965.0 8962.0 8960.0 8959.0 8956.0 8955.5 8938.0 8938.0 8935.5 8933.0 8932.5 LIS Tape Verl£~catlon Llst~ng Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE: 11 8920.0 8921.0 8921.5 8908.5 8910.0 8899.0 8900.5 8898 5 8900.0 8893.0 8895.5 8895.0 8876.5 8878.5 8873.0 8875.0 8852.5 8855.0 8852.0 8854.5 8845.0 8847.5 8844.0 8846.5 8840.0 8841.5 8837.5 8839.0 8829.5 8832.5 8829.0 8832.0 8826.0 8828.5 8819.0 8821.0 8818.5 8821.0 8806.5 8808.0 8805.5 8808.5 8785.0 8787.5 8784.5 8786.5 8782.5 8784.5 8767.0 8770.0 8769.5 8753.5 8756.0 8750.5 8753.5 8747.5 8750.5 8745.5 8749.5 8738.5 8741.0 8734.5 8737.5 8734.0 8737.5 8728.0 8730.5 8717.5 8719.5 8706.5 8709.0 8696.5 8698.5 8691.5 8694.5 8685.5 8687.5 8679.5 8681.5 8678.5 8680.5 8664.0 8666.0 8659.5 8661.5 8658.5 8661.5 8649.5 8651.5 8644.0 8644.5 8633.5 8635.5 8631.0 8633.5 8630.5 8632.5 8623.0 8624.0 8617 . 0 8619.5 8615.5 8617.5 8599.5 8602 5 100.0 103.0 102.0 $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA LIS Tape Verification Llstlng Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE: 12 FOR TDTP PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT TDTP PASS #3 GRCH TO TDTP PASS #1 GRCH; AND TDTP PASS #3 SIGM TO TDTP PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELi~,~ CODE (HEX) DEPT FT 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 SBHNTDTP CU 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1159701 O0 000 O0 0 3 I 1 4 68 0000000000 BACK TDTP CPS 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 TCANTDTP CPS 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verlflcatlon L~st~ng Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE: 13 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TSCN TDTP CPS 1159701 TSCF TDTP CPS 1159701 INND TDTP CPS 1159701 INFD TDTP CPS 1159701 GRCH TDTP GAPI 1159701 TENS TDTP LB 1159701 CCL TDTP V 1159701 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9230. 000 SIGM. TDTP 15.114 TPHI. TDTP 25. 354 SBHF. TDTP SBHN. TDTP 64. 464 SIGC. TDTP O. 372 SIBH. TDTP 88.169 TRAT. TDTP SDSI. TDTP 1. 953 BACK. TDTP 85. 000 FBAC. TDTP 20. 696 TCAN. TDTP TCAF. TDTP 1523. 490 TCND. TDTP 2406. 870 TCFD. TDTP 839. 569 TSCN. TDTP TSCF. TDTP 340.216 INND. TDTP 216.253 INFD. TDTP 45.371 GRCH. TDTP TENS TDTP 1342. 000 CCL. TDTP O . 000 DEPT. 8577. 000 SIGM. TDTP 45. 929 TPHI. TDTP 76.076 SBHF. TDTP SBHN. TDTP 57. 820 SIGC. TDTP 0 . 000 SIBH. TDTP 77. 357 TRAT. TDTP SDSI. TDTP 3. 077 BACK. TDTP 72.181 FBAC. TDTP 17. 527 TCAN. TDTP TCAF. TDTP 1292. 828 TCND. TDTP 3941 . 749 TCFD. TDTP 850. 986 TSCN. TDTP TSCF. TDTP 75 954 INND. TDTP 400.816 INFD. TDTP 71 . 658 GRCH. TDTP TENS. TDTP 1251. 000 CCL. TDTP O . 000 53. 935 1.617 3220.254 719. 127 -999.250 55 117 1 896 5762.291 314.832 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE · 1024 FILE TYPE : LO LAST FILE : · 8-JUL-1998 11:09 PAGE: 14 LIS Tape Verification Lxstlng Schlumberger Alaska Computing Center FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edlted static baseline passes for all other curves. DEPTH INCRE~iENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, TDTP REMARKS: THE ARITH~ETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNPNAV CU 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SIGC PNAV CU 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 TCAFPNAV CPS 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 TCND PNAV CPS 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD PNAV CPS 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 INNDPNAV CPS 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1159701 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9229.500 SIGM. PNAV 13.572 TPHI.PNAV 27.379 SBHF. PNAV 57.817 SBHN. PNAV 67.650 SIGC. PNAV 0.524 SIBH. PNAV 95.223 TRAT PNAV 1.727 SDSI.PNAV 1.035 BACK. TDTP 142.123 FBAC. TDTP 40.538 TCAN. PNAV 12139 125 TCAF. PNAV 5332.497 TCND.PNAV 8814.443 TCFD.PNAV 2948.617 TSCN. PNAV 2706.278 TSCF. PNAV 1188. 830 INND PNAV 882. 598 INFD. PNAV 145. 156 GRCH. TDTP -999. 250 DEPT. 8597.000 SIGM. PNAV 44.195 TPHI. PNAV 52.353 SBHF PNAV 44.512 SBHN. PNAV 46.903 SIGC.PNAV 0.343 SIBH. PNAV 52.595 TRAT. PNAV 1. 735 SDSI.PNAV 2.874 BACK. TDTP 145.776 FBAC. TDTP 30.674 TCAN. PNAV 11146.568 TCAF. PNAV 2801.067 TCND.PNAV 7453.593 TCFD.PNAV 1781.578 TSCN PNAV 682.336 TSCF. PNAV 184. 559 INND. PNAV 781. 098 INFD. PNAV 146. 271 GRCH TDTP 51 361 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Llst~ng Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE: 16 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate f~les; raw background pass in last flle PASS NUMBER: 1 DEPTH INCREMENT: 0. 5000 FILE SUM~i~Y VENDOR TOOL CODE START DEPTH TDTP 9258.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAI~IA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : STOP DEPTH 8579 5 22-FEB-98 8C0-609 1839 22-FEB-98 9242.0 9241.0 8600.0 9229.0 1800 0 NO TOOL NUMBER ........... CGRS-A TDT-P 8.500 9405.0 SEA WATER LIS Tape Verification Llstlng Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE: 17 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO DRESSER BHCS DATED 5-21-82. PUMPED TOTAL OF 315 BBLS. THIS FILE CONTAINS THERAW TDTP DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification L~st~ng Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE: 18 ** SET TYPE - CHAN ** NAlWiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELTO4 CODE (HEX) O0 000 O0 0 5 1 1 4 68 0000000000 DEPT FT 1159701 SIGM PS1 CU 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PS1 CU 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNPS1 CU 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PS1 CU 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PS1 CU 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPS1 CPS 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF PS1 CPS 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 TCNDPS1 CPS 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD PS1 CPS 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PS1 CPS 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PS1 CPS 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 INND PS1 CPS 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 INFD PS1 CPS 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1159701 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9258.000 SIGM. PS1 -999.250 TPHI.PS1 -999.250 SBHF. PS1 SBHN. PS1 -999.250 SIGC PS1 -999.250 SIBH. PS1 -999.250 TRAT. PS1 SDSI.PS1 -999.250 BACK. PSI -999 250 FBAC.PS1 -999.250 TCAN. PS1 TCAF. PS1 -999.250 TCND.PS1 -999.250 TCFDPS1 -999 250 TSCN. PS1 TSCF. PS1 -999.250 INND.PS1 -999.250 INFD.PS1 -999.250 TENS.PSI GR.PS1 135.606 CCL.PS1 -0.029 DEPT. 8579.500 SIGM. PS1 44.371 TPHI PS1 67.233 SBHF. PS1 SBHNPS1 52.697 SIGC. PS1 0.920 SIBH. PS1 65.735 TRAT. PS1 SDSI.PS1 1.670 BACK. PSi 141 057 FBAC.PS1 33.727 TCAN. PS1 TCAF. PS1 5169.242 TCND. PS1 13879.533 TCFD PS1 3224.997 TSCN. PS1 TSCF. PS1 316.885 INND. PS1 1625.508 INFD.PS1 279.248 TENS.PSi GR.PS1 50.053 CCL.PS1 -999 250 -999.250 -999 250 -999 250 -999.250 1028.000 46.640 1.825 20786 914 1241.090 1276.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE: 19 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate flies; raw background pass in last flle PASS NUMBER: 2 DEPTH INCREMENT. 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 9261.0 8583 0 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 22-FEB-98 8C0-609 1839 22-FEB-98 9242.0 9241.0 8600.0 9229.0 1800.0 NO TOOL NUMBER ........... CGRS-A TDT- P 8.500 LIS Tape Verification L~st~ng Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE: 2O DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 9405.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G) .. SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO DRESSER BHCS DATED 5-21-82. PUMPED TOTAL OF 315 BBLS. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PA GE: 21 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... DEPT FT 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPS2 CU 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PS2 CPS 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 TCNDPS2 CPS 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS2 CPS 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 INNDPS2 CPS 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1159701 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9261.000 SIGM. PS2 -999.250 TPHI.PS2 -999.250 SBHF. PS2 SBHN. PS2 -999.250 SIGC. PS2 -999.250 SIBH. PS2 -999 250 TRAT. PS2 SDSI.PS2 -999.250 BACK. PS2 -999.250 FBAC. PS2 -999.250 TCANPS2 TCAF PS2 -999.250 TCND. PS2 -999.250 TCFD. PS2 -999.250 TSCN. PS2 TSCF. PS2 -999.250 INND.PS2 -999.250 INFD.PS2 -999.250 TENS.PS2 GR.PS2 54.242 CCL.PS2 -0.010 -999.250 -999.250 -999.250 -999.250 886.000 LIS Tape Verification Llstlng Schlumberger Alaska Computlng Center 8-JUL-1998 11:09 PAGE: 22 DEPT. 8583.000 SIGM. PS2 SBHN. PS2 53.568 SIGC.PS2 SDSI.PS2 4.304 BACK. PS2 TCAF. PS2 1348.851 TCND.PS2 TSCF PS2 85.093 INND.PS2 GR.PS2 54.969 CCL.PS2 41.891 TPHI.PS2 1.983 SIBH. PS2 88.411 FBAC. PS2 3191.308 TCFD.PS2 317.200 INFD.PS2 -999.250 61.793 SBHF. PS2 67.709 TRAT. PS2 19.757 TCAN. PS2 786.533 TSCN. PS2 56.947 TENS.PS2 49.235 1.736 5245.747 315.154 1242.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass ~n separate f~les; raw background pass in last f~le PASS NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SUFmlARY VENDOR TOOL CODE START DEPTH ........................... TDTP 92 61.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : STOP DEPTH .......... 8558.0 22-FEB-98 8C0-609 1839 22-FEB-98 9242.0 9241 0 8600.0 9229 0 LIS Tape Verlfacatlon Llstlng Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE. 23 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS-A TDT- P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 9405.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) · 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): R~fARKS: CORRELATED TO DRESSER BHCS DATED 5-21-82. PUMPED TOTAL OF 315 BBLS. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #3. $ LIS FORMAT DATA 0000000000 £9 ~ ~ ~ L 0 O0 000 O0 ~0£6~ A ESd ~OO 0000000000 ~9 ~ ~ T L 0 O0 000 O0 TOL6£~T 0000000000 89 ~ T ~ £ 0 O0 000 O0 ~OL6~ 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~0£6£~ S~D ES~ ~I 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~0~6~ $~D E$~ ~I 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~0£6~ 0000000000 89 ~ r ~ L 0 O0 000 O0 rOL6S~ 0000000000 89 ~ ~ ~ L 0 00 000 00 ~OL6g~ SdD 0000000000 89 ~ ~ ~ L 0 00 000 00 ~OL6g~ SdD ESdG_ND~ 0000000000 89 ~ ~ ~ L 0 00 000 00 rOL6g~ SdD gSd 0000000000 89 ~ ~ ~ L 0 00 000 00 ~OL6g~I SdD ESdNVD£ 0000000000 89 ~ ~ ~ L 0 O0 000 O0 IOL6g~ SdD 0000000000 89 ~ ~ ~ L 0 O0 000 O0 ~OL6g~r SdD 0000000000 89 ~ ~ ~ L 0 O0 000 O0 ~OL6g~ ~D ESd ISC$ 0000000000 89 ~ ~ ~ L 0 O0 000 O0 ~OL6g~ 0000000000 89 ~ ~ ~ L 0 O0 000 O0 ~OL6g~ ~D gSd HHIS 0000000000 89 ~ r r L 0 O0 000 O0 roL6grr ~D ged DDIS 0000000000 89 ~ r r L 0 O0 000 O0 roL6grr ~O ~£d NHgS 0000000000 89 ~ r r L 0 O0 000 O0 roL6~rr ~O gSW ~HgS 0000000000 89 ~ r r L 0 O0 000 O0 roL6~rr Od ~£~ IHd£ 0000000000 89 ~ r r L o OO 000 OO roz65rr OD t£~ ~DIS 0000000000 89 ~ r r L 0 oo 000 O0 roL6grr (X~H) SCOD ~g~H dI4VS ~WON COW SSV~ID HdA.r. DOq # HSCHO CI SS~DOHW ~rd~H ~ZIS SWIIN gW[1N ~I~t IWV IWV IdV IWV ~DIAH~S .r. INO AHSS ~I4VN ....................................................................................... r 99 0 r 99 9r 89 99 0 99 89 rr 99 rr £~ g9 6 £'0 89 8 £9 L fL 9 99 r 99 0 99 0 99 r ~O~I~A ~COD HdiF~ ~dIuL ~,, GHOD~H NOI£VDI~ID~dS £VWHO~t V.r. VG ~ :HDVd 60:rr £66r-qflO-8 LIS Tape Verification L~stlng Schlumberger Alaska Computing Center 8-JUL-1998 11:09 PAGE: 25 ** DATA ** DEPT. 9261.000 SIGM. PS3 SBHN. PS3 -999.250 SIGC. PS3 SDSI.PS3 -999.250 BACK. PS3 TCAF. PS3 -999.250 TCND.PS3 TSCF. PS3 -999.250 INND.PS3 GR.PS3 0.000 CCL.PS3 DEPT. 8558.000 SIGM. PS3 SBHN. PS3 61.499 SIGC. PS3 SDSI.PS3 3.510 BACK. PS3 TCAF. PS3 1348.006 TCND.PS3 TSCF. PS3 71.218 INND.PS3 GR.PS3 47.786 CCL.PS3 -999.250 TPHI.PS3 -999.250 SIBH. PS3 -999.250 FBAC. PS3 -999.250 TCFD.PS3 -999.250 INFD.PS3 0.000 47.239 TPHI.PS3 0.000 SIBH. PS3 75.825 FBAC. PS3 3720.446 TCFD PS3 395.820 INFD.PS3 -999.250 -999.250 SBHF. PS3 -999.250 TRAT. PS3 -999.250 TCAN. PS3 -999.250 TSCN. PS3 -999.250 TENS.PS3 75.115 SBHF. PS3 85.701 TRAT. PS3 15.650 TCAN. PS3 848.124 TSCN. PS3 68.657 TENS.PS3 -999.250 -999.250 - 999. 250 -999 250 1010. 000 53 561 1. 823 5593.506 295. 233 1269. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/07/ 8 ORIGIN : FLIC TAPE NAME : 98333 CONTINUATION # : 1 PREVIOUS TAPE : COM~ENT : BP EXPLORATION, B-18, PRUDHOE BAY, API# 50-029-20702-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE ' 98/07/ 8 ORIGIN : FLIC REEL NAME : 98333 CONTINUATION # : PREVIOUS REEL COMMENT : BP EXPLORATION, B-18, PRUDHOE BAY, API# 50-029-20702-00 elOH peseo ~ID/NO 966 ~ - qo~ei/~l - 60 :~ un~l /, ,,,'/ eOe~oqow uo!ss!u~uoo 'suoo s~O ~, ID 966l 6 0 BdV ":~V~i ~lOH(lfllid O3AI:::IO_::I~I 0 '6~98 S'8~98 S'6~98 g'8~98 0 '0~98 0'/-I98 0 'SI98 0 'II98 S'8098 S'~098 0 'I098 0'8658 0'~Sg8 HDHD ......... HJ~HG GH/~/IHSNI1 ~NH~U~AIflOH ......... 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