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Home My WebLink About197-152Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/29/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250529 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 19RD 50133205790100 219188 5/10/2025 AK E-LINE GPT/CIBP/Perf HVB 13A 50231200320100 224160 3/16/2025 YELLOWJACKET SCBL IRU 241-01 50283201840000 221076 5/7/2025 AK E-LINE Plug/Perf KBU 22-06Y 50133206500000 215044 5/6/2025 AK E-LINE Perf KBU 22-06Y 50133206500000 215044 5/7/2025 AK E-LINE Perf KBU 24-06RD 50133204990100 206013 4/8/2025 YELLOWJACKET GPT-PLUG MPI 1-61 50029225200000 194142 5/10/2025 AK E-LINE Perf MPU E-42 50029236350000 219082 5/3/2025 AK E-LINE Patch MPU S-55 50029238130000 225006 5/13/2025 AK E-LINE CBL OP16-03 50029234420000 211017 4/25/2025 READ LeakDetect PAXTON 13 50133207330000 225021 4/29/2025 YELLOWJACKET SCBL PBU 01-12B 50029202690200 223090 4/8/2025 HALLIBURTON RBT PBU D-08B 50029203720200 225007 3/22/2025 BAKER MRPM PBU H-17B (REVISION)50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU J-25B 50029217410200 224134 3/10/2025 BAKER MRPM PBU K-19C (REVISION)50029225310300 224004 3/27/2025 BAKER MRPM PBU K-19C 50029225310300 224004 3/27/2025 HALLIBURTON RBT SRU 241-33B 50133206960000 221053 3/12/2025 YELLOWJACKET PERF Revision Explanation: Both wells had wrong side stack well name and API#/PTD on previous upload H-17b was marked as H-17A and K-19C was marked as K-19B. Well name now reflets correct sidetrack and has correct SPI# and PTD. T40489 T40490 T40491 T40492 T40492 T40493 T40494 T40495 T40496 T40497 T40498 T40499 T40500 T40501 T40502 T40503 T40503 T40504 PBU H-17B (REVISION)50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.29 14:33:01 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250508 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-26 50283201970000 224068 4/15/2025 AK E-LINE Perf BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf IRU 11-06 50283201300000 208184 4/14/2025 AK E-LINE CIBP PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF SRU 231-33 50133101630100 223008 4/13/2025 AK E-LINE CIBP PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON LDL END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON MFC40 MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT PBU 06-12B 50029204560200 211115 3/22/2025 HALLIBURTON RBT PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT PBU J-10B 50029204440200 215112 4/15/2025 HALLIBURTON RBT PBU M-207 50029238070000 224141 4/21/2025 HALLIBURTON IPROF PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF Please include current contact information if different from above. T40372 T40373 T40374 T40375 T40376 T40377 T40378 T40379 T40379 T40380 T40381 T40382 T40383 T40384 T40385 T40386 T40387 T40388 T40389 T40390 PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 12:42:44 -08'00' Joe Engel for Sean M By Grace Christianson at 1:21 pm, Jan 22, 2025 325-025 Digitally signed by Joseph Engel (2493) DN: cn=Joseph Engel (2493) Date: 2025.01.22 13:17:13 - 09'00' Joseph Engel (2493) SFD 1/24/2025JJL 1/28/25 DSR-1/22/25 Windowmillingwithservicecoilnotapprovedonthis10-403.SeeH-17BPTDforservicecoil windowmillingapproval.Whipstockmustbesealing. VarianceDVSHU20AAC25.112(i):Approvedforalternateabandonmentplugplacementonparent wellFRQWLQJHQWXSRQfullycementedlineronupcomingsidetrack. 10-407 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.01.28 15:57:27 -09'00'01/28/25 RBDMS JSB 012925 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: January 22, 2025 Re:H-17B Sundry Request Sundry approval is requested to set a whipstock and mill a window in the H-17A wellbore as part of the drilling and completion of the proposed H-17B CTD lateral. Proposed plan for H-17B Producer: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT (if needed). E-line will set a 4- 1/2" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or mill the window, for scheduling reasons, the rig will perform that work. See H-17B PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2" packer whipstock. A single string 3.80" window + 10' of formation will be milled (if not done pre-rig). The well will kick off drilling in Ivishak Zone 4 and lands in Zone 2. The lateral will continue in Zone 2 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” L-80 solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in February 2025) x Reference H-17A Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift 2. E-Line : Set 4-1/2" Packer Whipstock at 10,048’ MD at 0 degrees ROHS 3. Coil : Mill Window (if window not possible, mill with rig). See attached procedure. 4. Valve Shop : Pre-CTD Tree Work 5. Operations : Remove wellhouse and level pad. Rig Work: 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,435 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not done pre-rig). 3. Drill build section: 4.25" OH, ~138' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2,619' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” L-80 solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 37 bbls, 14.8 ppg Class G, 1.24 (ft3/sk), TOC at TOL*. 7. Freeze protect well to a min 2,200' TVD. 8. Close in tree, RDMO. * alternate plug placement 20 AAC 25.112(i) variance request Window milling with service coil not approved on this 10-403. See H-17B PTD for service coil window milling approval. ,p This completion will completelyyp p g( p isolate and abandon the parent Prudhoe Pool perfs. Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Set live GLVs and LTP* (if necessary) 3. Service Coil : RPM log and perforate (~250’) 4. Testing : Portable test separator flowback. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT H-17A JBR 04/09/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:7 4-1/2" joint. TPR FP-replaced for pass. Blinds FP-replace top seals for a pass. HCR choke FP-grease for a pass. HCR kill FP- function for pass. Manual kill Fail-rebuilt. R/T not witnessed. CMV 3 FP- replaced for pass. CH misc FP-superchoke flange leak- tighten for pass. Test time reflects when I was on location. Test Results TEST DATA Rig Rep:Sture/EvansOperator:Hilcorp North Slope, LLC Operator Rep:Lott/Yearout Rig Owner/Rig No.:Hilcorp Innovation PTD#:1971520 DATE:2/26/2024 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopSAM240226181551 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 20 MASP: 2450 Sundry No: 323-652 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 15 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 1 FPCH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 2-7/8"x5-1/2 FP #2 Rams 1 Blinds FP #3 Rams 1 7"NT #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 2 3-1/8"FP Kill Line Valves 2 3-1/8"F Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1500 200 PSI Attained P32 Full Pressure Attained P111 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2355 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P11 #1 Rams P9 #2 Rams P9 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1              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): 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 H-17A Tubing Swap RWO Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-152 50-029-20862-01-00 12450 Conductor Surface Intermediate Liner Liner 9039 80 2667 8270 1812 2642 12297 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 9030 31 - 111 30 - 2697 28 - 8298 8141 - 9953 9808 - 12450 31 - 111 30 - 2697 28 - 7092 6962 - 8549 8422 - 9039 12297, 12299 2670 4760 5410 7500 None 5380 6870 7240 8430 9913 - 12318 4-1/2" 12.6# L-80 26 - 9807 8514 - 9031 Structural 4-1/2" HES TNT Packer 9433, 8099 9433, 9628 8099, 8266 Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907.564.4763 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 0028284 26 - 8421 N/A N/A 219 675 59748 13591 32 40 1250 1550 1053 229 323-652 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker S3 Packer 9628, 8266 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 By Grace Christianson at 3:48 pm, Mar 22, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.03.22 14:49:28 -08'00' Torin Roschinger (4662) WCB 2024-07-11 RBDMS JSB 040224 DSR-3/29/24 ACTIVITY DATE SUMMARY 6/22/2023 T/I/O = 600/330/0. Temp = SI. PPPOT - IC Pressure IA to-2000 w/N2 (eval IAxOA). No AL, temp gas lift RU on campanion side no CNG hose currently RU. IA FL @ surface. Used 6 bottles of N2 to increase IAP from 330 to 650 in 1 hr. Job inconclusive change out to continue. Final WHP's = 600/650/0 PPPOT- IC: Stung into test port (300 psi). Bled void to 0 psi. Monitor for 10 min, no increase in pressure. Pressured void to 3500 psi for 30 min test, first 15 min lost 250 psi, second 15 min lost 100 psi (Inconclusive). Bled void to 0 psi. No Signs of N2, SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:30 6/22/2023 T/I/O = 640/640/0. Temp = SI. PPPOT-IC **PASS**, pressure up IAP (eval IAxOA). No AL. Used 8 bottles of N2 to increase IAP from 640 psi to 830 psi, TP increased with the IAP pund for pound. OAP unchanged throughout IAP increase. Left 830 psi on IA for further diagnostics. Final WHPs = 830/830/0. PPPOT-IC: Stung into test void, 0 psi. Monitor for 10 min, no change. Pressure void to 3500 psi for 30 min test. Lost 0 psi in 30 min. PASS. Bled void to 0 psi. SV, WV = C. SSV, MV = O. IA, OA = OTG. 17:30 6/23/2023 T/I/O = 790/810/0+. Temp = SI. Increase IAP to ~2000 psi (eval IAxOA). No AL. Heater installed and wellhouse door open. Used 15 bottles of N2 to increase IAP from 810 psi to 1130 psi in 20 min. TP increased 310 psi. Monitored for 30 min. Contacted Grease Crew to service the WV. TP decreased 10 psi. IAP & OAP unchanged. Final WHPs = 1090/1130/0+. SV, WV = C. SSV, MV = O. IA & OA = OTG. 17:00 6/27/2023 T/I/O = 1040/1070/0. Temp = SI. Post N2 WHPs (eval IAxOA). No AL. Heater installed in wellhouse w/ door open. TP decreased 50 psi & IAP decreased 60 psi since increase w/ N2 on 6-23-23. OAP unchanged. No signs on TxIA. SV, WV = C. SSV, MV = O. IA, OA = OTG. 14:50 6/29/2023 T/I/O = 1020/1060/0+. Temp = SI. PPPOT-IC Pressure IA to 2000 w/ GLT during test (eval IAxOA). AL disconnected at c spool. Heater functioning and wellhouse door open. IA FL near surface. Stung into IC void (800 psi). Increased IAP with N2 from 1060 psi to 1290 psi. TP increased 200 psi. IC void pressure and OAP unchanged. Monitored for 30 min. TP decreased 10 psi. IAP decreased 30 psi. IC void and OAP unchanged. Final WHPs = 1210/1260/0+. SV, WV = C. SSV, MV = O. IA & OA = OTG. 12:30 11/20/2023 T/I/O = 720/770/0. Temp = SI. Depress IA FL (Eval IAxOA). No AL. TBG FL @ surface, IA FL @ near surface (40'), OA FL @ near surface (54'). Stacked out IAP to 1920 psi w/ gas from H-24, TP increased to 1830 psi. Monitored pressure for 30 min, TP & IAP equalized, OAP unchanged. Opened WV, flow line pressured up to 1720 psi with no flow. Pit valve indicates open but unable to function. Installed heater and blanket around pit valve. OAP increased 8 psi in 3 hrs. Bled TBG & IAP to 420/500 psi (gas). Unable to get flow through flow line. FWHP's = 420/500/5 SV, WV, SSV = C. MV = O. IA & OA = OTG. 3:00. Daily Report of Well Operations PBU H-17A Daily Report of Well Operations PBU H-17A 11/24/2023 T/I/O = 488/520/5, Temp = SI. Push IA FL below OA shoe (Eval IAxOA). IA FL @ near surface, OA FL @ near surface. 4 1/2" PX plug set @ 9774'. RU 3/4" CNG from H-24 GLT to AL spool on H-17. Stacked out IAP to 1970 psi, TP tracked. Monitored for 10 min, TP equalized w/ IAP. Opened WV to displace fluid in IA until target depth reached (2700'). OAP increased 30 psi. SI WV to monitor OAP for 1 hr. IA FL unchanged, OAP increased an additional 5 psi, IAP and TP unchanged. FWHP's = 350/1183/40. SV, WV, SSV = C. MV = O. IA & OA = OTG. 19:00. 12/4/2023 T/I/O = 1080/1270/100. Temp = SI. T & IA FL (Fullbore). No AL. T FL @ 3160' (49 bbls). IA FL inconclusive. LRS in control of vavles upon departure. 21:30 12/4/2023 T/I/O= 225/1170/94 (DRLG SCREEN (MAINT)) Fluid packed IA with 175 bbls of Crude while taking returns up the TBG, and down the FL. Bled IAP (gas cap) down FL. Pumped 70 bbls crude down IA Pressured up to 1183/1273/102 had DHD shoot fluid level. TBG @ 3160' and IA Inconclusive. Continue bleeding down on TBG. ***Job Continued 12-5-23*** 12/5/2023 ***Job Continued from 12/4/23*** (DRLG SCREEN) Lube and bleed TBG and IA. Pumped 77 bbls today (Pumped total 147 bbls crude down IA). Combo MIT-TxIA (PASSED). Pumped 20 bbls to reach test pressure 2750 psi. 15 min loss: TBG-66 psi, IA-66 psi. 30 min loss: TBG-29 psi, IA-30 psi. FP FL 9 bbls 60/40 and 27 bbs crude. Upon Departure Secure well SV,WV, SSV= Closed MV=Open IA,OA=OTG. Left well in dso control. 12/10/2023 T/I/O = SSV/300/0+. Temp = SI. PPPOT-T **PASSED** (pre RWO). AL disconnected @ C spool. Functioned and torqued all tbg hanger LDS to 550 ft-lbs, marked three LDS that were stuck. PPPOT-T: Stung into test port (1100 psi) and bled void to 0 psi. Monitored for 10 mins, void pressure unchanged. Increased void pressure to 5000 psi for a 30 min test. Lost 100 psi in the 1st 15 mins and 50 psi in the 2nd 15 mins for a PASS. Bled void to 0 psi. SV, WV, SSV = C. MV = O. IA & OA = OTG. 17:30 2/10/2024 ***WELL S/I ON ARRIVAL*** PULL 3.81'' PX PLUG @ 9770' SLM/ 9774' MD RAN 20' x 3.70" DMY WHIPSTOCK DRIFT TO 10,110' SLM/ 10,107' MD ***CONT WSR ON 02-11-2024*** 2/11/2024 ***CONT WSR FROM 02-10-2024*** LOG CALIPER FROM 10,100' SLM/ 10,007 MD TO SURFACE(good data) SET 3.81'' PX-PLUG IN X-NIP @ 9774'MD WELLS GROUP EHS TOPICS w/ WSL T-BIRD PERFORMED PASSING C-MIT(see log) ***WELL LEFT S/I ON DEPARTURE*** 2/11/2024 T/I/O= 510/340/0 TFS Unit #4 Assist Slickline Pumped a total of 48 BBLS Crude and 3 BBLS of 60/40. ***CMIT PASSED*** Pumped 32 BBLS of Crude to Reach a MAP of 2750 psi for a CMIT TxIA. Starting Pressures = T/I/O = 2750/2750/0. 1st 15 min the TxIA lost 37/26 psi. 2nd 15 min TxIA lost 8/9 psi. Total loss in 30 min test = 45/35 psi. FWHP = 720/740/0 2/12/2024 T/I/O = SSV/150/0. Temp = SI. Function T-LDS (pre RWO). No AL. Freed up 3 stuck LDS @ the 3:30 - 4:30 positions. Did not PPPOT-T or torque LDS. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:15 Combo MIT-TxIA (PASSED). Daily Report of Well Operations PBU H-17A 2/12/2024 *** WELL S/I ON ARRIVAL*** OBJECTIVE WELLTEC TBG CUT RIG UP YJ ELINE. PT PCE 300 PSI LOW / 3000 PSI HIGH RIH W/ WELLTEC 2 3/8" MECHANICAL CUTTER CUT 4 1/2" TBG @ 9586' MID OF THE FULL JOINT ABOVE PKR PRE CUT T/I/OA 800/680/0 PSI, POST CUT T/I/O/= 350/100/0 AT SURFACE TATTLE TAIL SHOWED BLADES WENT OUT TO 4.55" RDMO YELLOWJACKET ELINE JOB COMPLETE ***WELL S/I ON DEPARTURE**** 2/12/2024 TFS unit 4 Circ out. T/IA/OA= 100/0/0 Standby for Fluid FWHP= 100/0/0 JOB Continues on 02-13-23 2/12/2024 T/I/O= 663/689/0 TFS Unit 4 Assist E-Line (Injectivity Test) Pumped a total of 3 BBLS 60/40 and 30 BBLS of Crude to Establish that the Tubing and IA could recieve 5 BPM. Pumped down the TBG up the IA through the Cirq Skid to the Open top. Started Pumping at .5 BPM to 2 BPM to 3 BPM and 4 BPM before hitting 5 BPM with 1700 psi on the TBG and 475 psi on the IA going to the open top . E-Line in control of Well upon Departure. FWHP=220/160/0 2/13/2024 TFS Unit #4 H-17 Circ out Pump 15 bbls Neat for separating SW/DSL and Freeze Protect surface lines Pump 720 bbls SW for Circ out Pump 5 BBLS Neat and 176 bbls DSL for IA/TBG Freeze Protect. U-Tube Complete for DSL Freeze Protect from IA to TBG. Flags and tags are hung Pad Op notified of departure FWHP = 590/650/0 2/14/2024 T/I/O = 30/0/0. Set 4" H BPV. 2/17/2024 T/I/O = BPV/0/0. Pulled 4' CIW 'H' BPV. Bleed to 0 PSI. Wellhead Tech set 4" CTS plug. FWP = 0/0/0 2/23/2024 RDMO L-295, Mobilize Gen and Pit Mods and stage on H-Pad Trucks back on L-Pad @ 21:30 Stage Pipe Shed and Catwalk at entrance Move Sub off L-295 Move remaining Mods from L-Pad to Z-Pad access road. 2/24/2024 Cont. to move remaining mods to H-pad arriving at 03:00 Spot Sub over H-17A and level rig. Spotted in remaining moduals and R/U working through Rig acceptance check list. Took on 290 BBLS of SW and R/U to rock diesel out of well. 2/25/2024 Rig accepted at 00:00 hrs Blow air through tigger tank hard line. Prime pumps through bleeder Pump 45 BBLS of SW down I/A, Pump 212 BBL down the TBG out the I/A (Rock out Diesel) Install BPV, N/D tree and adaptor N/U and testing BOPE- Test Witnessed by AOGCC Rep Austin McLeod 2/26/2024 C/O choke valve #3 Cont. testing BOPE with AOGCC Rep Austin McLeod M/U landing jt and BOLDS. Unseated hanger with 133K thats with 34K block wt. Circulate soap pill STS POOH with 4.5" TBG and Jewelry T/3247' Rig accepted at 00:00 hrs RIH W / WELLTEC 2 3/8" MECHANICAL CUTTER CUT 4 1/2" TBG @ 9586' MID OF THE FULL JOINT ABOVE PKR gj Unseated hanger with 133K thats with 34K block wt Daily Report of Well Operations PBU H-17A 2/26/2024 Pull 4" H BPV, stand by for rig to pump, set 4" H BPV, nipple down tubing head adapter, cut & cap (2) 1/4" control lines just above top of hanger, set CTS plug, make up 4-1/2" TDS test sub to hanger lift threads 10 RH, test 3500 psi/10 min., good test, bleed off, rig down test equip., function all upper LDS one at a time, 4-1/8" out (clear bowl), retorque to 500 ft/lbs, stand by for rig to nipple up & test BOP, pull CTS plug & BPV, make up landing joint ~10 RH, back out upper lock down screws, pull hanger to rig floor, lay down hanger & landing joint, stand by for tubing swap, 2/27/2024 Cont. to POOH with 4.5" TBG/Jewelry, Load pipe shed and work TBG. Organize pipe shed for completion run. 2/28/2024 Assist I-Rig w/ Freeze Protect (CTD) SU/RU and PT ***Job Cont to 2-29-24 WS*** 2/28/2024 Make up new hanger to string, run in hole, run in lock down screws, stand by for rig to circulate, set 4" H BPV, stand by for BOP nipple down, set CTS plug, install new BX- 160, make up tubing head adapter to tubing head, torque up connection, test 500 psi/5 min., 5000 psi/10 min., good tests, bleed off, rig down test equipment, stand by for tree test, pull CTS plug, attempt to pull BPV, but there was pressure under it, call well support to lubricate plug out, rig down, move out. 2/28/2024 Run 4 1/2 JFE-bear gas lift completion, Space out to land hanger, Displace to inhibited seawater 2/29/2024 ***Job Cont from 2-28-24 WSR*** Assist I-Rig (CTD) Pumped 180* bbls 70* DSL down IA taking returns from Tbg to OTT. Rig in control of well per LRS departure. 2/29/2024 T/I/O = 0/0/0. I-Rig Completion, Pulled 4" CTS 4-1 BPV through Dryhole tree, Rig Circulated well. Set 4" "H" BPV #109 through dry hole tree with lubricator. ***Job Complete***. Final WHP's BPV/0/0. 2/29/2024 Displace well with inhibited seawater, Land hanger, drop ball and rod. Set PKR w/3000 psi final set Pressure. Hold 3000 psi for 30 minutes and test TBG. Bleed Tbg to 1000 psi. PT IA to 2600 psi for 30 min. Dump Tbg pressure, shear GLM SOV. N/D BOP. N/U tree and test void. R/U lubricator and Pull TWC 3/1/2024 T/I/O=BPV/0/0. Post I-Rig Tie in. Removed 4" Gray swab valve, and NU 4" CIW Upper tree assembly. Replaced single lateral and installed 6" TPV and porduction piping. Torqued flanges to spec. Set wellhouse and floor. RU lubricator to tree with "H" pulling tool. Pressure tested tree against MV to 500 / 5000 psi . Passed. Pulled 4" "H" BPV #109 @125". RD lubricator and PT tree cap to 500 psi. Pass. ***Job Complete*** 3/2/2024 ***WELL S/I UPON ARRIVAL*** (ctd) PULLED BALL & ROD ASSY FROM RHC BODY @ 9510' MD. PULLED RK-DGLV FROM ST#3 @ 6088' MD. PULLED RKP-SHEAR VLV FROM ST#4 @ 3519' MD. SET RK-LGLV(16/64",1500#) IN ST#4 @ 3519' MD. SET RK-OGLV(20/64") IN ST#3 @ 6088' MD. PULLED B&R AND RHC FROM 9,510' MD RAN 9' x 3.0" PUMP BAILER FROM 9,734' SLM TO 9,738' SLM (recovered 2gal of fill/rig treats) ***CONT WSR ON 3/3/24*** () @ PULLED B&R AND RHC FROM 9,510' MD Land hanger, drop ball and rod. Set PKRg w/3000 psi final set Pressure. Hold 3000 psi for 30 minutes and test TBG. Bleed Tbg to 1000 psi.g PT IA to 2600 psi for 30 min. Dump Tbg pressure, shear GLM SOV. () PULLED BALL & ROD ASSY FROM RHC BODY @ 9510' MD. @ PULLED RKP-SHEAR VLV FROM ST#4 @ 3519' MD ( pull CTS plug &)yg g BPV, make up landing joint ~10 RH, back out upper lock down screws, pull hanger togj rig floor, lay down hanger & landing joint, stand by for tubing swap gg Run 4 1/2 JFE-bear gas lift completion, Space out to land hanger, Displace to inhibited seawater Daily Report of Well Operations PBU H-17A 3/3/2024 ***CONT WSR FROM 3/2/24*** (ctd) RAN 9' x 3.0" PUMP BAILERS FROM 9,738' SLM TO 9,740' SLM (recovered 2 3/4gal) PULLED P-PRONG FROM PX-PLUG BODY @ 9,740' SLM RAN MULTIPLE BAILERS FROM 9,740' SLM TO 9,744' SLM (recovered 2 1/4gal) ***CONT WSR ON 3/4/24*** 3/4/2024 ***CONT WSR FROM 3/3/24*** (ctd) RAN PUMP & HYDROSTATIC BAILERS TO PLUG BODY @ 9774' MD.(recovered 1/2 gallon of fill) PULLED 4-1/2" PX PLUG BODY FROM X-NIPPLE @ 9774' MD. DRIFTED TBG W/ 20' x 3.70" DUMMY WHIPSTOCK TO 10,100' SLM.(see log) ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** g) PULLED P-PRONG FROM PX-PLUG BODY @ 9,740' SLM 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Monday, March 4, 2024 7:56 AM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Oliver Sternicki; Torin Roschinger; PB Wells Integrity Subject:OPERABLE: Producer H-17A (PTD #1971520) MITs passed after RWO Follow Up Flag:Follow up Flag Status:Completed Mr. Regg, A tubing swap was completed on 02/28/24. A subsequent MIT‐T passed to 2,940 psi and MIT‐IA passed to 2,600 psi. The passing MITs confirm two competent well barriers and the well is now classified back to OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: PB Wells Integrity Sent: Friday, January 21, 2022 11:05 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: Producer H‐17A (PTD #1971520) CMIT‐TxIA Passed Mr. Regg, Producer H‐17A (PTD #1971520) has been secured with a TTP and passing CMIT‐TxIA on 01/18/22. The well will remain shut in and secured until tubing integrity is restored. The well is now classified as NOT OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, January 7, 2022 11:19 AM To: Regg, James B (CED) <jim.regg@alaska.gov> CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. PBU H-17APTD 19871520 2 Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer H‐17A (PTD #1971520) IA casing pressure above MOASP, failed TIFL Mr. Regg, Producer H‐17A (PTD #1971520) was reported to have IA casing pressure above MOASP on 01/06/22 after the well was shut‐in. The pressure was 2450 psi. On 01/07/22 DHD performed a failing TIFL. The failing TIFL indicates a failure in the primary well barrier. The well is now classified as UNDER EVALUATION and is on the 28‐day clock for diagnostics. Plan forward: 1. Slickline: Set DGLVs. Set TTP. Perform MIT‐T and CMIT‐TxIA Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 3 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Junke, Kayla M (OGC) From:McLellan, Bryan J (OGC) Sent:Monday, February 12, 2024 11:22 AM To:Aras Worthington; Rixse, Melvin G (OGC) Cc:Abbie Barker; Torin Roschinger Subject:RE: H-17A RWO Rig Change PTD #197-152, Sundry #323-652 Aras, The below‐proposed change to sundry 323‐652, for the work to be completed with the Innovation rig instead of a different rig, is approved. Since the Innovation rig has been continuously in operation, the BOP pressure test, including the initial test, shall be to 3000 psi, 2500 psi Annular test. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Monday, February 12, 2024 9:18 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: H‐17A RWO Rig Change PTD #197‐152, Sundry #323‐652 Bryan, As per our phone conversation we would like to have the Innovation rig execute two rig workovers between drill wells including this one (approved Sundry attached). There are no changes to the approved sundry other than the rig name and BOP stack. The Innovation BOP stack schematic is shown below. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Thanks and Best Regards, Aras The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: 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 perfs require a spacing exception due to property boundaries?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 ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU H-17A Tubing Swap RWO Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-152 50-029-20862-01-00 341J ADL 0028284 12450 Conductor Surface Intermediate Liner Liner 9039 80 2667 8270 1812 2642 12297 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 9030 31 - 111 30 - 2697 28 - 8298 8141 - 9953 9808 - 12450 2450 31 - 111 30 - 2697 28 - 7092 6962 - 8549 8422 - 9039 12297, 12299 2670 4760 5410 7500 9774 5380 6870 7240 8430 9913 - 12318 4-1/2" 12.6# L-80 26 - 98078514 - 9031 Structural 4-1/2" Baker S-3 Perm Packer No SSSV Installed 9628, 8266 Date: Aras Worthington for Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 PRUDHOE BAY 2/15/2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: 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 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:31 am, Dec 08, 2023 Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2023.12.07 16:19:10 - 09'00' Aras Worthington (4643) 323-652 DSR-12/8/23MGR08DEC23 10-404 2450 * Initial BOPE to 5000 psi. Annular to 2500 psi. * Subsequent BOPE test to 3000 psi. Annular to 2500 psi. SFD 1/12/2024JLC 1/12/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.01.16 13:05:58 -09'00'01/16/24 RBDMS JSB 011724 RWO PBU H-17A PTD:197-152 Well Name:PBU H-17A API Number:50-029-20862-01 Current Status:Shut-In – Non-Operable Rig:Nordic 2 Estimated Start Date:2/15/2024 Estimated Duration:5days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker First Call Engineer:Aras Worthington Contact:907-440-7692 Current Bottom Hole Pressure:3,330 psi @ 8,800’ TVD (7.3 ppge, based on last SIWHP) Max. Anticipated Surface Pressure:2,450 psi (Based on last SIWHP) Last SI WHP:2,450 psi (1/16/2022) Min ID:3.725” @ 9,795’ XN-Nipple Max Angle:93 Deg @ 10,732’ MD Brief Well Summary: H-17A produces from the Ivishak formation. The well failed integrity testing in 2022 indicating it has TxIA communication. A LDL confirmed there are tubing leaks at 5,125’ MD & 5,874’ MD. The LLR from IA to Tubing is 0.8 bpm @ ~1500 psi differential pressure. The well passed a CMIT-TxIA to 2,644 psi on 12/05/23 proving the production casing and packer have integrity. Objective: Pull the existing 4-1/2” tubing. Run new L-80 4-1/2” completion with stacker packer. Achieve a passing MIT-IA & MIT-T. The well is slated for a CTD sidetrack after the RWO but may be produced from its current perforations in the interim. Well Completion Information: Wellhead: McEvoy 13-5/8” x 4-1/2” hanger. Existing Production Packer: Baker S-3, 7” x 4-1/2” SSSV: 4-1/2” HXO BVN, max OD = 5.75”, OAL = 2.68’, 1/4” control line. GLMs: ST 1 KBG-2LS, 1”, max OD = 5.985”, OAL = 7.56’ ST 2, KBG-2LS, 1”, max OD = 5.985”, OAL = 7.55’ ST 3, MMG-M, 1.5”, max OD = 7.031”, OAL = 8.61’ ST 4, MMG-M, 1.5”, max OD = 7.031”, OAL = 8.61’ Pre RWO work: Wellhead: 1. PPPOT-T to 5000 psi, PPPOT-IC to 3500 psi. a. IC packoff was re-energized with plastic packing 8/15/19 and passed PT in 2021. 2. Function all LDS. E-line/Fullbore: 3. Cut tubing in the middle of the first full joint above the packer (~9,586 ’ MD). 4. Circulate well with 8.4 ppg KCl or seawater @ max rate down tubing and out IA to displace all crude from the well. LLR TxIA through the leaks is 0.8 bpm/1500 psi. 5. Freeze-protect TxIA. DHD: 6. Bleed WHP to 0 psi. RWO PBU H-17A PTD:197-152 Valve Shop: 7. Set and test TWC. 8. Nipple down tree and tubing head adaptor. Inspect landing threads. 9. NU BOPE configuration top down: Annular, 2-7/8”x5” VBRs, blinds and integral flow cross. RWO Procedure: 10. MIRU Workover Rig. 11. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). a. Record accumulator pre-charge pressures and chart tests. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 2-7/8”x 5” VBRs with 4-1/2” test joint. e. Test the annular with 4-1/2” test joint. f. Submit a completed 10-424 form to the AOGCC within 5 days of BOPE test. 12. RU and pull TWC. RU lubricator if pressure is expected. 13. Rock out diesel freeze-protect. 14. MU landing joint or spear, BOLDS and pull hanger to the floor. a. Lifting thread is 4-1/2” TDS. b. Expected PU weightin 8.4ppg = 105k-lbs. 15. Pull 4-1/2” tubing to floor, circulate bottoms up. 16. RU control line spooler for control line and balance lines. 17. Lay down 4-1/2” completion. Tbg will not be salvaged (70% wall loss in 2012). 18. Run 4-1/2” gas lifted tubing string with stacker packer completion as detailed on tally attached. a. Torque turn connections. 19. Land Hanger and reverse in corrosion inhibited 8.4 ppg KCl or seawater. 20. Drop ball and rod and set packer. 21. Perform MIT-T to 2,500 psi. 22. Bleed off tubing pressure to 1000 psi and MIT-IA to 2,500 psi for 30 charted minutes. 23. Bleed tubing pressure down to shear the shear out valve in the top GLM. FP Tubing and IA with diesel to 2200’ MD. 24. Set TWC. 25. RDMO Workover Rig. Post-rig valve shop work 26. ND BOPE 27. NU tree and tubing head adapter. 28. Test both tree and tubing hanger void to 500psi low/5,000psi high. 29. Pull TWC. Post-rig Slickline Work 30. Pull Ball and rod and RHC profile. 31. Pull TTP. 32. RDMO & POP well. * Startup BOPE test to pressure rating of BOPE equipment ~5000 psi. Annular 2500 psi. RWO PBU H-17A PTD:197-152 Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Schematic 4. Existing Tbg tally 5. Draft Tally 6. Sundry Revision Change Form RWO PBU H-17A PTD:197-152 Wellbore Schematic RWO PBU H-17A PTD:197-152 Proposed Wellbore Schematic RWO PBU H-17A PTD:197-152 RWO BOPs RWO PBU H-17A PTD:197-152 Existing Tbg Tally RWO PBU H-17A PTD:197-152 Draft Tally Well: H-17A Approx Depth Description 4-1/2” Tbg Hanger 0' XO Pup Joint to 4-1/2" JFE Bear 4-1/2” L-80 JFE Bear Spaceout Pups (As Needed): 2 ft, 4ft, 6ft, 8ft etc. 4-1/2” L-80 JFE Bear Pup Joint - 4-1/2” JFE Bear b x p, ~10’ X Nip (ID=3.813”), 4-1/2” JFE Bear b x p 2200' MD Pup Joint - 4-1/2” JFE Bear b x p, ~10’ Pup Joint - 4-1/2” JFE Bear b x p, ~10’ 4-1/2" MMG GLM w 1.5" SOV , JFE Bear TBD Pup Joint - 4-1/2” VAM JFE b x p, ~10’ 4-1/2” L-80 JFE Bear Pup Joint - 4-1/2” JFE Bear b x p, ~10’ 4-1/2" MMG GLM, JFE Bear b x p TBD Pup Joint - 4-1/2” JFE Bear b x p, ~10’ 4-1/2” L-80 JFE Bear Pup Joint - 4-1/2” JFE Bear b x p, ~10’ 4-1/2" KBG-2 GLM, JFE Bear b x p TBD Pup Joint - 4-1/2” JFE Bear b x p, ~10’ 4-1/2” L-80 JFE Bear Pup Joint - 4-1/2” JFE Bear b x p, ~10’ 4-1/2" KBG-2 GLM, JFE Bear b x p TBD Pup Joint - 4-1/2” JFE Bear b x p, ~10’ 4-1/2” L-80 JFE Bear Pup Joint - 4-1/2” JFE Bear b x p, ~10’ X Nip (ID=3.813”), 4-1/2” JFE Bear b x p 9420' MD Pup Joint - 4-1/2” JFE Bear b x p, ~10’ Full Joint - 4-1/2" L-80 JFE Bear b x p, 40’ Pup Joint and XO - 4-1/2”JFE Bear b x VT p, ~10’ 7”x4-1/2” L-80 HES TNT Packer Vam Top bxp 9480' MD up Joint and XO - 4-1/2”VT b x JFE Bear p, ~10’ Full Joint - 4-1/2" L-80 JFE Bear b x p, 40’ Pup Joint - 4-1/2” JFE Bear b x p, ~10’ X Nip (ID=3.813”), L-80 4-1/2” Vam b x p (With RHC Body Installed)9540' MD Pup Joint - 4-1/2” JFE Bear b x p, ~10’ Full Joint - 4-1/2" L-80 JFE Bear b x p, 40’ Northern Solutions 7" x 4-1/2" Overshot 9590' MD RWO PBU H-17A PTD:197-152 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Producer H-17A (PTD #1971520) CMIT-TxIA Passed Date:Friday, January 21, 2022 11:40:15 AM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, January 21, 2022 11:05 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: Producer H-17A (PTD #1971520) CMIT-TxIA Passed Mr. Regg, Producer H-17A (PTD #1971520) has been secured with a TTP and passing CMIT-TxIA on 01/18/22. The well will remain shut in and secured until tubing integrity is restored. The well is now classified as NOT OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, January 7, 2022 11:19 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer H-17A (PTD #1971520) IA casing pressure above MOASP, failed TIFL Mr. Regg, Producer H-17A (PTD #1971520) was reported to have IA casing pressure above MOASP on 01/06/22 after the well was shut-in. The pressure was 2450 psi. On 01/07/22 DHD performed a failing TIFL. The failing TIFL indicates a failure in the primary well barrier. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. Slickline: Set DGLVs. Set TTP. Perform MIT-T and CMIT-TxIA Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS r u..0- "rnd Cp ED P.I!" C -,nen 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operetions7gh,"wn -. jy ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change A{1pro'Sed Nogram ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Pull WFT ISO Plug 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development m Exploratory ❑ 5. Permit to Drill Number 197-152 3. Address: P.O. Box 196612 Anchorage, AK 99519-0612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-20862-01-00 7. Designation (Lease Number): ADL 0028284 e. Well Name and Number: PBU H -17A 9. Lags (List logs and submit electronic and printeddata per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 12450 feet Plugs measured None feet true vertical 9039 feet Junk measured 12297. 12299 feet Effective Depth. measured 12297 feet Packer measured 9628 feet true vertical 9030 feet Packer true vertical 8266 feet Casing: Length. Size: MD: TVD. Burst: Collapse: Structural Conductor 80 20" x 30" 31 -111 31 -111 Surface 2667 13-3/8" 30-2697 30-2697 5380 2670 Intermediate 8270 9-5/8" 47# L-80 28-8298 28-7092 6870 4760 Liner 1812 7" 8141-9953 6962-8549 7240 5410 Liner 2643 4-1/2' 9807-12450 8421 -9039 8430 7500 Perforation Depth: Measured depth: 9913-12318 feet True vertical depth: 8514-9031 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 26-9807 26-8421 Packets and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 9628 8266 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation. 29 3915 42 0 171 Subsequent to operation: 320 13893 108 0 991 14.Attachments: (requlred per 20 MC 25.07025071, 625390) 15, Well Class after work: Daily Report of Well Operations m Exploratory ❑ Development p Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil ® Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name' Pew, Cale 154 {\j lkfjK &!%kuyZontactName: Peru Cale Authorized Title: Petroleum Engineer Contact Email: Cate.PeruQbp.com Authorized Signature: • ` 1e -y (�f Date: fZ3(f ( ('? Contact Phone: 11 907 564 4522 Form 10-404 Revised 04/2017 �eWt? IBMUG 0 71019 Submit Original Only Daily Report of Well Operations PBU H -17A ACTIVITVnATP ci innnneoV *`*WELL S/I ON ARRIVAL' (Profile Modification) DRIFTED TO TOP OF WFD ISO PLUG @ 9,988' SLM w/ 3.625" G -RING. 7/16/2019 **'WSR CONTINUED ON 7/17/19*** ***WSR CONTINUED FROM 7/16/19*** (Profile Modification) EQUALIZED & PULLED 4-1/2" WFD ISO PLUG FROM 9,988' SLM / 9998' MD. (Element intact) DRIFTED TO DEVIATION @ 10,666' SLM w/ 3.0" CENT, 2-1/2" S-BLR. 7/17/2019 ***JOB COMPLETE, WELL LEFT S/I*** TREE= 4-1/16" CM/ MD WEI-LHEAD_ NICEVOY SAFETY NOTES: WELL > 70" @ 10602'. INITIAL WELLBORE H-1 7A NOT SHOWN BELOW 9-5/8" MLLOUT. NOTE WLEG @ ACTUATOR= AIR TYPE 9807' MAY OR MAY NOT BE FULLY INSERTED INTO OKB. ELEV = 79.94' TI®ACK SLV. REF ELEV = 72.97' DATE BF. EUFV = 43.48' 3601 KOP= 3100' 2105' 4-1/2" HES HXO SSSV N, D = 3.813" Max Angle = 93" @ 10732' O DOLE Datum MD = 10386' 16 Datum TVD = 88W SS GAS LFT MANDRELS 13-3/8" CSG, 72#, L80, D = 12.347" 2705' 6070 44 ATAG-M SO BKR TI®ACK SLV, D = 7.250" 8141' ZO 2 9-5/8" X 7^ BKR ZXP PKR, D = 6.312^ 8148' 7419 X 7" BKR HMC 8154' KBG2LS LNR 9-5/8" MLLOUT WNDOW (FF17A) 8298' - 8348' LNR HGR D - 6.184" 9-5/8" CSG, 47#, L-80, 0 9817' 4-1/2" HES X NIP, ID = 3.813" Minimum ID = 3.725" @ 9795' 8199 9628 7X41/2"BKR S-3 PKR ID=3.875" 4-1120, HES XN NIPPLE BTM 9774' 4-1/2' HES XNIP, D = 3.813" 9795' 4-1/2" HES XN NIP, ID = 3-725" 4-1/1" TBG, 12.69, L-80 ST, 9807' .0152 bpf, D = 3.958" TIEBACK SLV, ID = 5.250" 9808' — 9807' 4-1/2" WLEG, ID = 3.958" 7"X5'BKR ZXP PKR,D=4.408^ 9814' 9803' ELMD TT LOGGED 09/23/97 7" X 5" BKR HMC HGR D = 4.408" 9822• 7" LNR 26#, L-80,.0383 bpf, ID = 6276^ 9853' PERFORATION SUMMARY REF LOG: OH CNL ON 09/04/97 ANGLE AT TOP PERF: 29" @ 9913' Note: Refer to Production DB for historical pert data 12299' 4-1/2^ BKR CBP MLL®& PUSH® SIZE SPF INTERVAL Opr✓S z SHOT SOZ (7/29113) 2-718" 6 9913-9939 O 11/25/18 2-7/8" 6 9935-9939 O 09/03/18 SAFETY NOTE A BKR CBP @ 11270' 2-7/8" 4 10465-10470 S 0410599 07/22/13 WAS MILLED OUT AND PUSHED TO BTM 2-7/8" 4 10789 -10814 S 03/20/04 07/22/13 @ 12297' CTMD ON 05/0101. EXERCISE 2-7/8" 4 10835 -10860 S 03/19/04 07/22/13 CAUTDNI 23/4" 6 10948-10963 O 05/31/16 2-7/8" 4 10980-11020 S 03/2798 07/22/13 2-3/4" 6 11099-11120 O 05131 /16 2-7/8" 4 11320-11500 S 1012697 07/22/13 2-718" 4 11530-11590 S 10/2697 07/22/13 2-7/8" 4 11650-11800 S 10/2697 07/22/13 2-3/4" 4 11750-11850 S 09/1197 07/22/13 2-7/8" 6 11915-11935 O 12/14/14 (ELMD)PBTD LOGGED 05/04/10) 12321' 2314" 4 11950-12090 S 09/1197 07/22/13 23/4" 4 12160 -12318 C 0911197 4-112" LNR 12.6#, L-80, .0152 bpf, D = 3.958• 12450' PRUDHOE BAY UNIT WELL: F417A PERMITNo:91971520 API No: 50-029-20862-01 SEC 21, T11N R13E, 810'SNL&1735 WEL BP Exploration (Alaska) ST MD TVD DEV TYPE VLV LATCH PORI DATE 4 3601 3577 22 MMG-M DOLE RK 16 08/02/13 3 6974 6070 44 ATAG-M SO Po( ZO 2 8671 7419 27 KBG2LS DM1' BTM 0 108/02/13 09/23/87 1 9549 8199 31 KBG2LS DMY BTM 0 09/23/97 DAIS REV BY COPMENIS DATE REV BY COMMENTS 1223/82 WITINAL COhPLETION 12/16/14 JDANJMD ADPERF (12/14/14) 09/11197 N2ES SIDETRACK tR-17 O6r01I16 ATCVJMD ADPERFS (05/31/16) 08/10113 RKTiPJC GLV C/O 08/02/13 09/05/18 BTWJMD SETPLUG&ADPERFS 09AD3/18 08/11/13 PJC TVD CORRECTDNS (PR ALSO) 09!19!18 DD/JMD ADDED OKB, REF, & BF ELEV 0829/13 JGL/JMD MLLCMT/MLL&PUSH CBP 0729!1 12/18/18 J ADPERFB 1125/18 06/17114 DC$/J MNDCORRECTX7N 0722119 RCB/JMCRA.L BO PLUG (07/17/19) STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate H Other Stimulate 0 Alter CasingID Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 197-152 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20862-01-00 7. Property Designation(Lease Number): ADL 0028284 8. Well Name and Number: PBU H-17A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: t RECEIVE Total Depth: measured 12450 feet Plugs measured feet true vertical 9039 feet Junk measured 12297/12299 feet JUN 2 8 2 016 Effective Depth: measured 12321 feet Packer measured 9629 feet L true vertical 9031 feet Packer true vertical 8267.31 feet t O../G CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"x 30" 32-111 32-111 Surface 2666 13-3/8"72#L-80 31-2697 31-2697 4930 2670 Intermediate 8270 9-5/8"47#L-80 29-8299 29-7093 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 27-9808 27-8423 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Ss {f Treatment descriptions including volumes used and final pressure: NED "t 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 209 4479 72 1240 257 I Subsequent to operation: 486 4646 162 1180 270 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations m Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil IZ1 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Wim--, Phone +1 907 564 4424 Date 6/28/16 - vrForm 10404 Revised 5/2015 ` ��/// RBDMS t (.1 Submit Original Only 77�, V .,�;; 2016 • Cf) o 0 0 0 0 ca cOtiv1c) LO C N Nr LU N- N- () ; o 0 0 0 0 i M N- M M m CD co N NI- V • m V (O N- 00 CO I� CO O O) M CD CD 40 M N CO O (C) O V N I- C70 CD CO CD CO N N- M M N O) V N (O OD C C r- CA C10 QD N CD (N 00 = N co O) O) v a CVS 1 1 1 1 1 1 a Q ti N O) r N ,- CD Nr O f- co M N Cb N _ = M CA MW M CD O O ° co ? OD 0 CO O J J C0 _= d M N *k J CO QD •U) fX QD c n C O Cb = N _ _ U N MN N A � V � QD L CV C)O) CO ON 'Cr CO C i- CO N CO CO I— J N OD "— N CD w C0 .(7) (30 W N U U Z w W w p0 O D Z Z U U) Z J J H • e 0 m CO CO O) CO CO M N- N- N- O CO N M co -CV N r CO O LO r N CD N CO N I- O Q, M Ln O 6 U) V' CO r N t M U) O LU M Q) N O O O O O O r r r r r N N O O7 0 0 0 0 0 0 0 0 0 0 0 0 0 m CO O 6) O) O7 6) C) 6) O) O O O O7 C) d7 0I- 0.a O I- M V N LO V M i0 t N LO O) CO CO LO r r Ln O I- O Ln O - O O O) N CO r CO fl- M Ln Ln 6 Ln Ln Ln O N M 4 M O) O 0 m N 0 0 0 0 0 0 r r .- r N N W O O7 O O O O O O O O O O O O O O > 0 M M M M M M M M M M M M M M o 0 I-> w w a � w 0 0 U w LU 0 CL.Luz 0 J 0 W N J Y U U 0 M 0 0 W Y Y i O t O M O O O O O O O O Ln 0 CO J U U W W rX 4.0 o. M O O N N O O) Ln O LO M O7 r J J J d d Ln Z W y V M CO O7 O O r Ln LO N- CO CO O O M Q Q Q W 0 - 0 C D O O O O r r r r r r r r r N N _0 0 _0 J LU LU 0 . . . . . . r r r c- . . . . . Z Z Z 0 J 0 J 0 J E m < < < = 00 00 d It d 000 m = mw 01_ 0 z -C w W w a H O Z 2 2 E O co co coon co Q1 0. = I- C o . LUCLna000m00000Lnoo O Mp, LU M M d- M O O N M Ln U O r Ln (p N V I- CO O O7 O O M Ln m N- CO O O r w 0 0 0 O O O r r r r r r r r r N cla0L 0 O E E_ c_nY 00 u) cC -' 1H I.1 E 2 2 O co co co co co a) CL a 0 U c .9 NNNLL_ NNLL_ NNNNNILNa. 76OOOa. 00a- OOOOOaOa Qcncncn < ww < cncncnc w < wm 0 t 0 a 0 I- m c'') C) M CO M M CO M M M M M M M =O 0 r r r r r ,- = = ,--- = r r 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W Z O N N N N N N N N N N N N N N N r Z u- < yw O w N N w- NNNrNN NNNNN = NO DaOUDWw yNNNMNNMNNNNN - NN Zw U wWWwW OI� r- r- LnI� r- LnI- r- I` NI` NN- N- Lor < 0 J H J J J J D Q' 0_ 0 m 0 D W --I J 3 Q O W w Q Q d U E. E :n u. v) D_ C< m E m z < < < < < < < < < < < < < < < N- I` N- N- N- N- N- N- N- ti N- N- N- N r- m r r r r r r r i . . 77 . r co IL d co 0 -� L.L. NU' W d 2 = 22222m , . , mm < < m m w Li cn cn a. ct S • Packers and SSV's Attachment PBU H-17A SW Name Type MD TVD Depscription H-17A PACKER 8149.67 6968.91 7" Baker ZXP Packer H-17A TBG PACKER 9629 8267.31 4-1/2" Baker S-3 Perm Packer H-17A PACKER 9815.16 8428.53 5" Baker ZXP Top Packer i 0 C Z o H a) a) Y •C RI Q -p ?i 2 45Q H N ❑ c 1` H M O -O -o c w W N ° O = c C 4. .t c 2 iO a -45 o (Z O 1O a) Q) d m = aN. . w c6 0 +sL � rn� N 3 co s. I- � � � 4- 2 CO Q °- CO (1) Co C O — O) a) a) 0 W' a) p O N O O a) N O O N I L L J ~ N U _C W 0- aa)) O N Q N N as _ -0 D m Q a_ 2 -) O co J W � cflCO c � O J L U O c ❑ W' O Q Q 2 C Q- * 0 U U') 0 m O O co U) Q O II II U) v- cn O co IP Q-' W E c < w 0 pQ c) OQ-o = `, •0 c a) in O) L •c C C. p)r W U U o * U) U) 0 O N W' ❑ 1 ❑ -- r O a u) N O O d -, O ° N .- o Q O Z I..L O O O O i c 1 M O O TO c G1 r ❑ ; CC CC d d - �2 co �� O N N U) 2 Q O O o >, - >, -o > - a) o C) a) U c 4- ❑ Q �a < Q Q Q 3 0 a ° W c m x W a) a) C a) c a) - U) U v> C P O s- a _I a Z > P CO > � > al > m 3 ° 0 U c6 a) _a 4) _ Q ? v CO U U) 0 CO 0 v Et E E - - = uO S� v°i N U o 0 0 �j '-- C.7 o O = 2 v Ce QD � O ° � O N O o O z- io a � a)� t0 � oI - 0 (1) >, Z ❑ w o > � o o o co � � Q c � ❑ � ° a) 2 2 co aZti WF- caf * ~ - (2 * ~ � � * ~ 0- co a *k —8J U *k -_ 0 c � o �* Oc`l LI] cn0D u) 0 cnU -0 ° } cna-' ° n ,- .- - a) W - U) a) cn _ a) a) U) _ N O) v) _ a) QcH v) c a) iu H x 2 Co c in .c c 92 To _c c 02 iO .c o) E D (n o ODI " - °) a) ao a) _ co �, o ` L o o L N o L U C Q o C O c ° Q C3 O 0 O O Cl 3 o Qa o 0_0- 3 o a) 0 -0 D = a -0 a O .- E i U Iw1- (acoa") •- m _o - rns0 a) 'OZF- 2 �OO .EF- z � F- 'E is m O c _ o O p ct = 0 D c 2 0 D c i o p c ,_ ° zt o a o m .� 0 6 a) o o o ~ O ~ N ~ V « ~ as _ ? ° O N ? O O ° z a) a) x ❑ ©: Ur ,, UU) N + UU) N : 0U) I— : C.) 21:34= 1,` UUFr) cn 0_ 0_ .- .*k W I- Q co cor co co CO (0 CO rrr } O O 0 O O C) O F N N N N N N (V ,- V (O N- (0 C) F- 1.1-3 Lo in in c) O co U Lc) n in- Q I cn (15co E co E a� a) co >, Q. fn oa o m 0 a ca a� 0 C J ca o _ a� o .P_ oma (7) N- TRIS 4-1116"CfW • SA NOTES:WELL>70°@ 10602'.INMAL V1,LBORE WELLHEAD= MCEVOY H -17 A NOT SHOWN BROW 9-5/8"MLLOUr. NOTE WLEG @ .ACTUATOR= BAKER 9807'MAY OR MAY NOT BE FULLY INSERTED INTO HT1AL KB.ELE 79 94' 11EBACK SLV. BF.EL&= 44.49' KOP= . _ 3100' Max Angle= 93°@ 10732' 2105' 4-112'HES HXO Sssv N D=3.813^ Datum MD= 10386' © Datum 1VD= 8800'SS ' GAS LFT MANDRELS 13-3/8"CSG,72#,L80,ID=12.347" H 2705' ST M) ND DEV TYPE VLV LATCH FORT DATE 4 3601 3577 22 14.4G-M DOME RK 16 08/02/13 3 6974 6070 44 MM3-M SO RK 20 08/02/13 BKR TEBACK SLV,D=7.250" --I 8141' L 2 8671 7419 27 KBG2LS DMY BTM 0 09/23/97 1 9549 8199 31 KBG2LS DMY BTM 0 09/23/97 9-5/8"X 7"BKR ZXP PKR D=6.312" H 8148' ) 9-5/8"X 7"BKR HMC H 8154' LNR HGR D=6.184" 9-518"MILLOUT VVNDOW (HATA)8298'-8348' 9-5/8"CSG,47#,L-80,ID=8.681" —{ 8298' /---- ' ' 9617' H4-1/2"HES XNIP,D=3.813" Minimum ID = 3.726" @ 9796' 4-1/2" HES XN NIPPLE 8 $ 9628' H 'X 4-1/2"BKR S-3 PKR D=3.875" ' V 9774' H4-1/2"HES XNF,D=3.813' I I 9795' —4-1/2"HES XNNP,D=3.725" 4-1/2"TBG, 12.6#,L-80 IBT, H 9807' .0152 bpf,ID=3.958" TIEBACK SLV,D=5.250" 9808' ' 9807' H4-1/2"WLEG,D=3.958" 7"X 5"BKR ZXP PKR,D=4.408" — 9814' { - 9803' --I ELMD IT LOGGED 09/23/97 7"X 5"BKR HMC HGR,D=4.408" 9822' 7^LNR 26#,L-80,.0383 bpf,D=6.276" —, 9953' , II. FERFORATION SUMMARY I REF LOG: OH CM_ON 09/04/97 ANGLE AT TOP PERF: 91°@ @ I — 12299' 4-112"BKR GBP MILLED Note.Refer to Roduction DB for historical pert data &PUSHED SIZE SPF INTERVAL Opn/Sqz SHOT SOZ % (7/29/13) 2-7/8" 4 10465- 10470 S 04/05/99 07/22/13 2-7/8" 4 10789- 10814 S 03/20/04 07/22/13 SAFETY NOTE A BKR CBP@ 11270' 2-7/8" 4 10835- 10860 S 03/19/04 07/22/13 WAS MILLED OUT AND PUSHED TO BTM 2-3/4" 6 10948- 10963 0 05/31/16 @ 12297'CTMD ON 05/0101-EXERCISE 2-7/8" 4 10980- 11020 S 03/27/98 07/22/13 CAUTION! 2-3/4" 6 11099- 11120 0 05/31/16 4111111s, 2-718" 4 11320- 11500 S 10/26/97 07/22/13 /Of 2-7/8" 4 11530- 11590 S 10/26/97 07/22/13 �Of 2-7/8" 4 11650- 11800 S 10/26/97 07/22/13 / 2-3/4" 4 11750- 11850 S 09/11/97 07/22/13 // -`. 2-7/8" 6 11915- 11935 0 12/14/14 (Bi V)F TD LOGGED 05/04/10) —_12321' 2-3/4" 4 11950- 12090 S 09/11/97 07/22/13 2-3/4" 4 12160-12318 0/C 09/11/97 4-1/2"LNR, 12.6#,L-80, .0152 bpf,ID=3.958' H 12450' DATE REV BY COMMBYTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/23/82 IMTINAL COMPLETION 12/16/14 JDIWJMD ADF132F(12/14/14) WELL. H-17A 09/11/97 N2ES SIDETRACK(H-17A) 06/01/16 ATO/JMD ADFH S(05/31/16) PERMIT No: 1971520 08/10/13 RKT/PJC GLV C/O(08/02/13) API No: 50-029-20862-01 08/11/13 PJC TVD CORRECTIONS(PR ALSO) SEC 21,T11 N,R13E,810'SNL&1735'WEL 08/29/13 JGUJMD MLL CMT/MLL&PUSH C8P(07/29/13) 06/17/14 DGB/JMD MN D CORRECTION BP Exploration(Alaska) • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, April 27, 2016 3:35 PM To: AK, D&C Well Integrity Coordinator; AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; AK, OPS GC2 Facility OTL; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Pettus, Whitney; Sternicki, Oliver R; Dickerman, Eric; Sayers, Jessica; Wallace, Chris D (DOA); Munk, Corey; Odom, Kristine; McVey, Adrienne; Morrison, Spencer; Peru, Cale Subject: OPERABLE: Producer H-17A (PTD#1971520)IA x OA Manageable by Bleeds All, Producer H-17A(PTD#1971520) is reclassified as Operable. A 4-day OA Repressurization Test was performed on the well, with a final build-up rate of 140 psi/day. During the OART,the IA pressure was 1510 psi. At the conclusion of the OART,the IA pressure was bled down to 650 psi, as an added measure of protection against over-pressuring the OA. Plan Forward: 1. Operations: Leave well shut in—DONE 4/17/16 2. Downhole Diagnostics: Cold OA Repressurization Test—DONE 4/21/16 3. Downhole Diagnostics: Bleed IA below 1000 psi—DONE 4/27/16 The well may be brought online as needed. Thanks, Adrienne McVey 2.01bWell Integrity Superintendent—GWO Alaska �,sYKO MAY (Alternate:Jack Lau) S Office: (907)659-5102 Email: AKDCWelIIntegrityCoordinator(cr�BP.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, Ap 016 8:29 PM To: AK, OPS GC2 OSM; AK, OPS GC-. field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; K, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wel s Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; AK, OPS GC2 Facility OTL; Vohra, Prachi; 'Regg, Jame-OS-WA) (jim.regg@alaska.gov)' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordn or; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Pettus, Whitney; Sternicki, Oliver R; Morrison, Spencer; Dickerman, Eric; Sayers, Jessica; Mcvey, Adrienne; 'chris.wallace@alaska.gov'; Munk, Corey; Odom, Kristine Subject: UNDER EVALUATION: Producer H-17A (PTD #1971520) Sustained Outer Annulus Ca—ging—Pressure Exceeding MOASP All, 1 • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday, April 17, 2016 8:29 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ;AK, OPS GC2 Facility OTL; Vohra, Prachi; Regg,James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Pettus, Whitney; Sternicki, Oliver R; Morrison, Spencer; Dickerman, Eric; Sayers, Jessica; Mcvey, Adrienne; Wallace, Chris D (DOA); Munk, Corey; Odom, Kristine Subject: UNDER EVALUATION: Producer H-17A (PTD #1971520) Sustained Outer Annulus Casing Pressure Exceeding MOASP Attachments: Producer H-17A (PTD#1971520) TIO Plot.docx All, Producer H-17A (PTD#1971520) was reported to have sustained Outer Annulus (OA) casing pressure of 1820 psi on 13th April 2016.The Operator bled the OA, but it exceeded MOASP again the following day.The well is reclassified as Under Evaluation for further diagnostics. Please leave the well shut in. Plan Forward: 1. Operations: Leave well shut in 2. Downhole Diagnostics: Cold OA Repressurization Test 3. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO plot has been included for reference. Thanks, Adrienne McVeyscove APR 1 $ °16 (Alternate:Jack Lau) BP Alaska-Well Integrity Superintendent WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator(a)BP.com From: AK Well Integrity Coordinator Sent: Saturday, Februar ry 21, 2015 8:26 PM To: AK, OPS GC2 OSM; AK,DPS GC2 Field 0&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; Bailey, Denise G; 'chris.wallace@alaska.gov'; AK, OPS GC2 Facility OTL Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (iim.regg@alaska.gov) ettus, Whitney; Sternicki, Oliver R Subject: OPERABLE: Producer H-17A (PTD #1971520) Outer Annulus Repressurization Test Passed 1 • • S H-17A(PTD#1971520) TIO Plot 17th April 2016 1.1 N.1) COC WO -1 w oa MOP Dx r 1''S 0126.16 0131.1€ «!02616 0214'16 0521116 024416 069V11 0OATS 061016 062,16 019116 061016 061716 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, February 21, 2015 8:26 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad HUQ; Bailey, Denise G;Wallace, Chris D (DOA);AK, OPS GC2 Facility OTL Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA); Pettus, Whitney; Sternicki, Oliver R Subject: OPERABLE: Producer H-17A (PTD#1971520) Outer Annulus Repressurization Test Passed Attachments: image001.png; image002 jpg All, Producer H-17A(PTD#1971520) passed an outer annulus repressurization test with a pressure build up rate of 14 psi /day after the Y seals in the wellhead were re-energized.This build up rate is considered manageable by bleeds.This well is being reclassified as Operable. Thank you, Laurie Climer (Alternate. Kevin Parks) SCANNED BP Alaska-Well Integrity Coordinator GINGINGlobal Wells Y Organizat'on WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com From: AK, D&C Well -a rity Coordinator Sent: Friday, February 06, 12:48 PM To: AK, OPS GC2 OSM; AK, OPS G ield O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline •,-rations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East - Opt Engr; AK, OPS Well Pad HUQ; Bailey, Denise G; 'chris.wallace@alaska.gov'; AK, OPS GC2 Facility OTL Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Inte• Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) im.re•• • a . - •ov)' Subject: UNDER EVALUATION: Producer H-17A (PTD #1971520) Sustaine• 6- -r Annulus Casing Pressure Above MOASP Producer H-17A(PTD#1971520)was reported to have sustained outer annulus casing pressure above : - P on 02/05/2015. The pressures were reported to be tubing/inner annulus/outer annulus of 1780/1410/1150. The '- I is reclassified as Under Evaluation and placed on a 28 day clock to facilitate evaluation. 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, February 06, 2015 12:48 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wel!pad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad HUQ; Bailey, Denise G;Wallace, Chris D (DOA);AK, OPS GC2 Facility OTL Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer H-17A (PTD#1971520) Sustained Outer Annulus Casing Pressure Above MOASP Attachments: image001.png; Producer H-17A (PTD#1971520) TIO Plot.docx Producer H-17A(PTD#1971520)was reported to have sustained outer annulus casing pressure above MOASP on 02/05/2015. The pressures were reported to be tubing/inner annulus/outer annulus of 1780/1410/1150. The well is reclassified as Under Evaluation and placed on a 28 day clock to facilitate evaluation. Plan forward: 1. DHD: Perform OART 2. Wellhead: PPPOT-IC A copy of the TIO plot is included for reference. ORO Thank you, Kevin Parks (Atte,note i_ani ie c-litni r) BP Alaska-Well Integrity Coordinator GVVGlobal9Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegntyCoordinator@bp.com 1 • Producer H-17A(PTD#1971520)TIO Plot Well N32 30[C -1—Ti t u z KC -•-o 0004 M 1,0E14 '.`5'4 •122.1! 1'29 t2 122.14 12.314 '2 2214 12714 210315 011015 01,215 0`2415 0131:15 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18,2012 IV l s ' 74 Mr. Jim Regg Alaska Oil and Gas Conservation Commission ' ' AUG ( 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB H -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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: 03/17/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 H -02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H -03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 H -04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 H -06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 H -07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 H -08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 411 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18/2010 H -14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18/2010 H -15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 H -16 2000650 50029205920200 0 NA NA NA NA NA -^-- H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 H -18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 H -20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 1421 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H -23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 H -25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 H -26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 H -28 1880440 50029218060000 0.5 NA 0.5 _ NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 H -30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 H -31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 H -32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 H -33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 H -34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 H -35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 H -36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 H -38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 Schlumberger RECEIVED No. 5769 LiUL252011 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Atoka 01 & Gas Cons. CornafiOA Attn: Christine Shartzer ATTN: Stephanie Pacillo Anchorage 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD (t?- I5. H -17A BLPO -00119 PPROF W GHOST 10- Jul -11 1 _ 1 ` 1 ` Sc(S _ 14 -04A AV1P -00093 LEAK DETECTION LOG 9- Jul -11 1 1 J • y E -01A BLPO -00121 PPROF W GHOST 12- Jul -11 1 1 M PB -50 BCRJ -00096 RST WFL LOG 16- Jul -11 1 1 H -14B BD88 -00113 PPROF W/ DEFT & GHOST 2- Jun -11 1 1 OWDW -SW AV1P -00091 RST WFL LOG 16- Jul -11 _ 1 _ 1 06 -02A BL65 -00027 LDWG EDIT OF MCNL 4- May -11 1 1 15 -02B BJOH -00016 LDWG EDIT OF RST 1- Apr -11 1 1 P2 -41 BJOH -00020 LDWG EDIT OF RST 11- Apr -11 1 1 vkl..n`;21. BCRJ -00086 LDWG EDIT OF USIT 18- May -11 N/A 1 1 , - 202 BMSA- 00005 LDWG EDIT OF USIT 30- Jan -11 N/A 1 06 -08A BCRD -00089 LDWG EDIT OF RST 6- Mar -11 1 1 • -Q PLEA;, AGKNOWI..ED(;E RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: Fsp pkoiation (6\Iaska) Inc. Alaska Data & Consulting Services P( Data t:;enten I,. k2 1 2525 Gambell Street, Suite 400 200 H 1 1cncnn i31vrt Anchorage, AK 99503 -2838 (1 Scblumb~rger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job k ,, Log Description NO. 5520 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7fh Ave, Suite 100 Anchorage, AK 98501 Date BL Color CD FI-25 B-13A 0.27A H-17A BCRD-00017 BBSK-00018 BCRD-00021 BAUJ-00020 PRODUCTION PROFILE GRAVEL PACK/TBG PUNCWMP T LDL MEM PRODUCTION PRO ILE 05/09/10 5/06/10 05/12/10 04/10 1 1 1 1 1 1 1 1 F-12 AVYO-00069 PRODUCTION PROFILE - 05/03/10 1 1 07-32B Z-03A F-23A BBUO-00016 BD88-00006 BBSK-00007 SCMT CH EDIT PD R EM O RELATI N RST 05/04/10 03/25/10 02/17/10 1 1 1 1 1 C-13A AYYO-00060 RST - 02/76/10 1 1 E-338 AWJFD0078 MCNL ~ .- 03/25/10 1 1 PLEARF ACKNr1Wl Pnf:F OCC PIDT wv err_uu v_ wan oot~ ~ou,un ....~ .....,.. ~........._ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suhe 400 Anchorage, AK 99503-2838 05/24/10 STATE OF ALASKA R`'IAY ~ ~ ~~~ASKA AND GAS CONSERVATION COMMISS~ I~rs~nAt~,als~nn OF SUNDRY WELL OPERATIONS 1. Operations Aban Repair Well ^ Plug Perforations ^ Stimulate^ Other Q straddle pack Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ® BAKER 45 "KB" Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 10460'-10475' 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill tuber: Name: Development ~ Exploratory ^ 197-1520 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-20862-01-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-028284 ~ PRU H-17A 10. Field/Pool(s): \ PR DH E BAY L U O FIELD TPRUDHOE OIL POO 11. Present Well Condition Summary: Total Depth measured 12450 feet Plugs (measured) None feet true vertical 9039.33 feet Junk (measured) None feet Effective Depth measured 12297 feet Packer (measured) 8148 9628 9814 true vertical 9030 feet (true vertical) 6968 8267 8428 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 29 - 109 29 - 109 1490 470 Surface 2670 13-3/8" 72# L-80 28 - 2698 28 - 2698 4930 2670 Intermediate Production 8271 9-5/8" 47# L-80 27 - 8298 27 - 7092 6870 4760 Liner 1812 7"26# L-80 8141 - 9953 6962 - 8549 7240 5410 Liner 2636 4-1/2" 12.6# L-80 9814 - 12450 8428 - 9039 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 25 - 9807 25 -8421 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Packer 8148 6968 4-1 /2" Baker s-3 Perm Packer 9628' 8267 5" Baker ZXP Tog Packer 9814 8428 12. Stimulation or cement squeeze summary: Intervals treated (measured): : 'a u F ~ , . Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 771 34369 242 1798 Subsequent to operation: 892 31952 625 1805 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 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: N/A Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564-4944 Date 5/10/2010 - a -/7-~~ ~'".-~ ~/' /L? H-17A 197-152 PERF ATTACHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base H-17A 9/11/97 PER 11,750. 11,850. 9,014.29 9,015.22 H-17A 9/11/97 PER 11,950. 12,090. 9,021.65 9,026.64 H-17A 9/11/97 PER 12,160. 12,318. 9,026.1 9,031.3 H-17A 10/26/97 APF 11,320. 11,500. 9,010.04 9,011.27 H-17A 10/26/97 APF 11,530. 11,590. 9,012.07 9,012.67 H-17A 10/26/97 APF 11,650. 11,800. 9,013.95 9,013.88 H-17A 3/26/98 APF 11,000. 11,020. 9,005.03 9,004.51 H-17A 3/26/98 APF 10,980. 11,000. 9,005.54 9,005.03 H-17A 7/3/98 BPS 11,270. 12,321. 9,010.47 9,031.47 H-17A 4/5/99 APF 10,465. 10,470. 8,923.53 8,926.48 H-17A 5/1/01 BPP 11,270. 12,321. 9,010.47 9,031.47 H-17A 3/20/04 APF 10,789. 10,814. 9,005.04 9,005.29 H-17A 3/20/04 APF 10,835. 10,860. 9,005.72 9,006.18 H-17A 10/22/08 BPS 9,785. 12,318. 8,402.39 9,031.3 H-17A 10/31/08 BPP 9,785. 12,318. 8,402.39 9,031.3 H-17A 5/7/10 STC 10,460. 10,475. 8,920.56 8,929.38 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ACTIVITYDATE ~ SUMMARY 5/7/2010.. *** WELL FLOWING ON ARRIVAL (ELINE PACKER)*** 31NITIAL T/I/O = 1800/1100/700 SET BAKER 45 "KB" STRADDLE PACKER. 13CR 4" GS PROFILE. 3-1/2" BOX UP WLEG DOWN, 30K SHEAR RELEASE, SET AT 10460-10475 FT . VALVE POSITIONS ON DEPARTURE: SWAB AND WING - CL ELL SI AND TAGGED, DSO NOTIFIED. LRS DISPATCHED TO FREEZE PROTECT. 1***JOB COMPLETE*** :. ~m~. _ _ . ~~a_ ~..~...~.....~ FLUIDS PUMPED BBLS 11 60/40 METH 1 DIESEL 12 Total TREE = 4-1 /16" MCEV OY WEL~HEAD= ,.~ MCEVOY - ACTUATOR = BAKER KB. ELEV = 72.97 BF. ELEV = 44.49' KOP = 3100' Max Angle = 93 @ 10732' Datum MD = 10386' Datum TV D = 8800' SS 13-3(8" CSG, 72#, L80, ID = 12.347" BKR TIEBACK SLV, ID = 7.250" 9-5/8" X 7" BKR ZXP PKR, ID = 6.312" 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.184" 9-5/8" GSG, 47#, L-80, ID = 8.681" SAFETY N :WELL > 70° @ 10600'. PRE-SDTRK H -17A WEILBORE NOT SHOWN BELOW 9-5/8" MILLOUT. NOTE WLEG @ 9807' MAY OR MAY NOT BE FULLY INSERTED INTO TIEBACK SLV. 2105' 4-112" HES HXO SSSV N, ID = 3.813" GAS LIFT MANDRFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3601 3496 22 MMG-M DMY RK 0 09/28/05 3 6974 5992 44 MMG-M DMY RK 0 09/28(05 2 8671 7347 27 KBG2LS DMY BTM 0 09123!97 1 9549 8126 31 KBG2LS DMY BTM 0 09!23197 9-5/8" MILLOUT WINDOW (H-17A} 8298' - 8348' 9617' 4-112" HES X NIP, ID = 3.813" Minimum ID = 3.725" @ 9795' 4-1 /2" HES X NIP 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" TIEBACK SLV, ID = 5.250" 7" X 5" BKR ZXP PKR, ID = 4.408" 7" X 5" BKR HMC HGR, ID = 4.408" __ 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: OH GNL ON 09/04/97 ANGLE AT TOP PERF: 54 @ 10465' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-7/8" 4 10465 - 10470 O 04/05/99 2-718" 4 10789 - 10814 O 03120!04 2-718" 4 10835 - 10860 O 03/19104 2-718" 4 10980 - 11020 O 03/27/98 2-7/8" 4 11320 - 11500 O 10126/97 2-7/8" 4 11530 - 11590 O 10!26197 2-718" 4 11650 - 11800 O 10/26/97 2-314" 4 11750 - 11850 O 09/11/97 2-314" 4 11950 - 12090 O 09/11/97 2-3/4" 4 12160 - 12318 O 09/11/97 9628' --j 7" X 4-1 /2" BKR S PKR, ID = 3.875" 9774' 4-112" HES X NIP, ID = 3.813" 4-1/2" HES XN NIP, ID = 3.725" 9$07' -14-112" WLEG, ID = 3.958" 9803' ELMD TT LOGGED 09/23/97 P~~ \ ) ~ I ~16r~ - 'f75' 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" SAFETY NOTE: A BKR CIBP @ 11270' WAS MILLED OUT AND PUSHED TO BTM @ 12297' CTMD ON 05/0101. EXERCISE CAUTION! PBTD PRUDHOE BAY UNfT WELL: H-17A PERMIT No: 1971520 API No: 50-029-20862-01 SEC 21, T11 N, R13E, 810' SNL & 1735' WEL BP Exploration (Alaska) H-17A (PTD #1971520) Internal~iver Cancellation -Not Operable • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj ';~~~~ 1~~~ ~c 7 Sent: Thursday, December 13, 2007 9:12 AM ~~ ~ ~ "l To: Maunder, Thomas E (DOA); Regg, James B (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Starck, Jennifer L Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Roschinger, Torin T. Subject: H-17A (PTD #1971520) Internal Waiver Cancellation -Not Operable /~ All, An internal waiver was issued for IAxOA communication on well H-17A (PTD #1971520) on 01105!06. Although this well is allowed to produce under dispensation from the Weil Integrity System Policy until 12131/07, the well is already shut-in with no plans to return it to production before the end of the year. Therefore, the waiver is cancelled. The well has been reclassified as Not Operable. Please remove all Waivered well signs and the laminated copy of the waiver from the wellhouse. Please call with any questions of concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 12/18!2007 r'\ "'" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandonD Alter Casing 0 Change Approved Program D 2. Operator SuspendD Repair Well 0 Pull TubingD Operation ShutdownD Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate ŒJ WaiverD Stimulate 0 Time ExtensionO Re-enter Suspended Well 0 Other!!] Pull Patch 5. Permit to Drill Number: 197-1520 Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519.6612 7. KB Elevation (ft): 72.97 8. Property Designation: ADL-o028284 11. Present Well Condition Summary: Development Œ] Stratigraphic D 9. Well Name and Number: H-17A 10. FieldlPool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD ServiceD 6. API Number 50-029-20862-01-00 Total Depth measured 12450 feet true vertical 9039.3 feet Effective Depth measured 12297 feet true vertical 9030.1 feet Casing Conductor Liner Liner Production Surface Perforation depth: Measured depth: 10465 -10470,10789 -10814,10835 -10860,10980 -11000,11000 -11020,11320 -11500 11530 -11590,11650 -11750,11750 -11800,11800 -11850,11950 -12090,12160 -12318 True vertical depth: 8923.53 -,9005.04 - 8926.48, 9005.72 - 9005.29,9005.54 - 9006.18,9005.03 - 9005.03,9010.04 - 9004.51 9012.07 - 9011.27, 9013.95 - 9012.67, 9014.29 - 9014.29, 9013.88 - 9013.88, 9021.65 . 9015.22, 9026.1 - 9026.64 Tubing (size, grade, and measured depth): 4-1I2"12.6#L-80 @ 25 - 9807 RECEIVED Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 9628 5" Baker ZXP Liner Top Packer @ 9814 7" Baker ZXP Packer @ 8148 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Reoresentative Daily Average Production or Iniection Data Gas-Me! Water-Bbl Casing Pressure 28.6 234 2300 Daily Report of Well Operations! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron )f~~ ~~ Length 80 1812 2636 8271 2670 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - Signature Form 10-404 Revised 12/2003 Plugs (measured) Junk (measured) None 12297 Size 20" 91.5# H-40 7" 26# L-80 4-1/2" 12.6# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD 29 109 29.0 . 109.0 8141 - 9953 6961.8 - 8548.8 9814 - 12450 8427.5 - 9039.3 27 - 8298 27.0 - 7091.9 28 - 2698 28.0 - 2698.0 Collapse 470 5410 7500 4760 2670 Burst 1490 7240 8430 6870 4930 APR 1 4 2004 ^Iaska Oil & Gas Cona. Coínmil$ion Anchorage Oil-Bbl 540 Tubing Pressure 1633 1388 1289 29.3 1600 197 15. Well Class after proposed work: Exploratory 0 DevelopmentŒ ServiceD 16. Well Status after proposed work: Operational Shutdown 0 OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Phone 564-4657 Date 4/12/04 nQIGINAL Wl-l' 4 10n\ ... Bfl r'\ ~ H-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/16/04 ( PRE CTU PERF) PULL TOP SECTION OF 41/2 ECLIPSE PATCH FROM 10431' SLM PULLING OUT OF HOLE WI LOWER PACKER 03/17/04 PULLED LOWER PATCH 03/18/04 MIRU OS CTU #5. MU SWS MEMORY GRICCL. 03/19/04 CTU #5, ADD PERF; LOAD WELL WITH 1% KCL TO REDUCE WHP. RIH WITH SWS MEMORY GR/CCL. LOG INTERVAL 11000' TO 10600'. FLAG PIPE. POOH. WAIT ON WEATHER, TEMPERATURE @ -41 DEG F, CANNOT PICK LUBRICATOR OFF WELL. TIE INTO SWS CNL 9/4/97. RIH W/ GUN #1 (25' - SWS 2 7/8" PJ2906- 15.0 GM, 4 SPF, 60/180 DEG). PERFORATE 10,835' TO 10,860'. POOH WITH GUN #1. ALL SHOTS FIRED. RIH WI GUN #2 (25' - SWS 2 7/8" PJ2906- 15.0 GM, 4 SPF, 60/180 DEG). 03/20/04 RIH with gun #2. Perforate 10789'-10814' 4 SPF. POOH with gun #2. All shots fired. RD OS CTU #5. Job complete. FLUIDS PUMPED BBLS 173 189 362 60/40 Methonal 1 % KCL TOTAL Page 1 I 13-3/8"CSG, 72#, L80,ID=12.34r' H 2705' ~ TOPOFBKR llEBACKSLV, ID = 7.250" H 8141' h L - 9-5/8"X7"BKRZXPA<R,ID=6.312" H 8148' J i 19-518" X r' BKR H\,1C ~ 8154' Lt-R H3R,ID =6.184" 19-5/8" CSG, 47#, L-80, ID = 8.681" H 8298' Minimum ID =2,25"@ 10472' 4.1/2" ECLIPSE PATCH 8 LOWER ELEMENT ~ " TREE = 4-1/16"MCEVOY WB.U"EAD= MCEVOY AClUATOR = BAKER KB. ELBI = 72.97' BF. ELBI = 44.49' KOP= 3100' Max Angle = 93@ 10732' Da1um MD = 10388' Da1um lV D = 8800' SS 4-1/2"TBG, 12.6#, L-80, H 9806' .0152bpf,ID=3.958" 1- ITOPOFllEBACKSLV,ID=5.250" H 980S' Ir'X5"BKRZXPPKR,ID=4.4O8" H 9814' 17" X (}' BKR HMC HGR, ID = 4.408" H 9822' r' LNR, 26#, L-80, ID = 6.276" H 9953' PERFORATION SUMMARY RIT LOG: OH O'JL ON 09104/97 ANGLEATTOPPERF: 54@10465' IIble: Refer 10 A'oduetion DB for historical perf data SIZE SPF INTERo/ AL OpnlSqz D6. TE 2- 7/8" 4 10465 - 10470 0 04105199 2- 7/8" 4 10789 - 10814 0 03/20/04 2- 7/8" 4 10835 - 10860 0 03/19/04 2- 7/8" 4 10980 - 11020 0 03/27/98 2- 7/8" 4 11320 - 11500 0 10/26/97 2-7/8" 4 11530-11590 0 10/26/97 2-7/8" 4 11650-11800 0 10/26/97 2-3/4" 411750-11850 0 09/11/97 2-3/4" 4 11950 - 12090 0 09/11/97 2-3/4" 4 12160 - 12318 0 09/11/97 DATE 12/23182 09111/97 09/23/01 10/04102 03/23/03 04101/03 04128103 COMWENTS ORIGINAL COMPLETION RIG SlDErRACK Œi/KAK CORRECllONS BMffP WAIVERSAÆlY NOTE JMPiKK DB-EYE WA tv' ER SAFETY NOTE" JRCiKK WAIVERSAÆlY NOTE ATDffLH WAIVERSAÆlY NOTE ,~ ~ ( I ~ r'\ H-17A SAFETY NOTES: W B..L > 70o@ 10600' AND> 90o@ 10700'. PR&SDTRK WB..LBORE NOT SHOWN ON TtiS DIAGRAM BELOW 9-5/S" SECTION MILLOUT WINDOW. ***T X IA X OA COMM. OPERATING UMITS:MAX lAP = 2500 PSI; MAX OAP = 2500 PSI. (06/06/03 W AlVER)*** NOTE: WLEG@ 9807' MAYOR MAY NOT BEFULLYINSERTB> INTO TEBACK SLV. . 2105' H4-1/2" HES HXO SSSVN, ID = 3.813" I . GA S LIFT MANDRB.S ST MD lVD DBI TYPE VLV LATCH PORT D6.TE 4 3601 3496 22 MMG-M OOWE RK 16 09/23/97 3 6974 5992 44 MMG-M S/O RK 20 09/23/97 2 8671 7347 27 KBG2LS DV BTM 09/23/97 1 9549 8126 31 KBG2LS DV BTM 09/23/97 I 9-5/8" MILLOUTWIJ\DOW 8298' - 8348' (SECTION MLL) 9617' 9628' H4-1/2"HffiXNIP,ID=3.813" I H7"X 4-1/2" BKRS PKR,ID =3.875" I H4-1/2" Hffi X NIP, ID = 3.813" H4-1/2" Hffi XN NP, ID = 3.725" 9774' 9795' ~ ~ 9807' 9803' H4-1/2"WLEG,ID= 3.958" I H ELMD TT LOGGID 09/23/97 I SAFETY NOTE: A BKR CIBP @ 11270' WAS MILLED our AND PUSHID TO BTM @ 1229r CTMDON051O101. EXERCISE CAUllON! 12321' 4-1/2"LNR,12.6#,L-80,.0152bpf,ID=3.958" H 12450' DATE RBI BY COMMENTS 06/06/03 JRC/KK W AIV ER SA FETY NOTE 12/05/03 KLC/TLP ECUPSE PA TŒi 3/16-20104 SRB/TLP ADD PERFS, DELEfEPATCI-ES REV BY PRUDHOE BA Y UNrr WB.L: H-17A ÆRMTNo: 1971520 API No: 50-029-20862-01 SEe 21, T11 N, R13E, 810' SNL & 1735' WEL BP Exploration (Alaska) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Suspend 0 Repair WellŒ] Pull Tubing D Operation Shutdown 0 Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate 0 WaiverD Stimulate D Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 197-1520 OtherD Name: BP Exploration (Alaska), Inc. 72.97 8. Property Designation: ADL-0028284 11. Present Well Condition Summary: Development ŒJ Stratigraphic D 9. Well Name and Number: H-17 A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD Service D 6. API Number 50-029-20862-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 12450 feet true vertical 9039.3 feet Plugs (measured) None Effective Depth measured 12297 feet Junk (measured) None true vertical 9030.1 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 29 109 29.0 109.0 1490 470 liner 1812 7" 26# L-80 8141 - 9953 6961.8 - 8548.8 7240 5410 liner 2636 4-1/2" 12.6# L-80 9814 - 12450 8427.5 - 9039.3 8430 7500 Production 8271 9-5/8" 47# L-80 27 - 8298 27.0 - 7091.9 6870 4760 Surface 2670 13-3/8" 72# L-80 28 - 2698 28.0 - 2698.0 4930 2670 Perforation decth: Measured depth: 10465 -10470,10980 -11000,11000 -11020,11320 -11500,11530 -11590,11650 -11750,11750 -11800 11750 -11800,11800 -11850,11950 -12090,12160 -12318 True vertical depth: 8923.53 - 8926.48, 9005.54 - 9005.03, 9005.03 - 9004.51, 9010.04 - 9011.27, 9012.07 - 9012.67, 9013.95 - 9014.29 9014.29 - 9013.88,9013.88 - 9015.22,9021.65 - 9026.64,9026.1 - 9031.3 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 25 2-7/8" 6.5# L-80 @ 10460 Packers & SSSV (type & measured depth): 2-7/8" Eclipse Patch Packer 2-7/8" Eclipse Patch Packer 4-1/2" Baker S-3 Perm Packer 5" Baker ZXP liner Top Packer 7" Baker ZXP Packer 9807 10475 @ 10460 @ 10471 @ 9628~ @ ~'ã'14'\;:: @ 8148 ~ŸAR 1 5 200<' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 1110 39.3 153 2160 1429 724 36 234 1850 1271 ReDresentative Dailv Averaae Production or Iniection Data 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒJ Service 0 Daily Report of Well Operations. X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garr Catron Printed Name Garry Catron Signature 16. Well Status after proposed work: Operational Shutdown D OilŒJ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Copies of Logs and Surveys run - Title Production Technical Assistant Phone 564-4657 Date 3/11/04 Form 10-404 Revised 12/2003 ORIGINAL ROOMS 8Ft MAR 1 6 209' H-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/04/03 T/I/O=2400/2160/1180. ASSIST E-LiNE WITH WELL KILL. PUMPED 10 BBLS NEAT, 301 BBLS SEA WATER, 90 BBLS CRUDE, AND 10 BBLS DIESEL DOWN TBG. FINAL WHP=300/1600/1100 12/04/03 OBJECTIVE: TO SET A WEATHERFORD PB ECLIPSE PACKER ACROSS PERF INTERVAL 104651 -104701. SET LOWER ELEMENT AT 104751 AS PER PROGRAM. DID NOT TAG TD. PUMPED A KILL OF 10 BBLS MEOH, 300 BBLS SW, 90 BBLS CRUDE, 10 BBLS DIESEL. INITIAL WELL WEAD PRESSURE WAS 2400, AFTER KILL 500. TRIED RIH, HAVE TROUBLE RUNNING THROUGH TUBING HANGER, WAS ABLE TO BUMP LINE AND GET DOWN. WELLHEAD PRESSURE INCREASED TO 1300 PSI, MAKING WELL CONTROL DIFFICULT. CALL WAS MADE TO RD AND POSTPONE SETTING OF PATCH. 12/05/03 A 4.5" ECLIPSE PATCH WAS SET @ 10460-10475. WELL WAS SHUT IN ON ARRIVAL. PAD OPERATOR WANTED TO FREEZE PROTECT FLOWLINE BEFORE RIG UP COULD BEGIN. UPPER PATCH SET @ 104601. WELL LEFT SHUT IN. PAD OPERATOR NOTIFIED. FLUIDS PUMPED BBLS 10 Neat Methonal 301 Sea Water 90 Crude 10 Diesel 411 TOTAL Page 1 TREE = 4-1/16" MCEVOY W 8... L/-EA D = MCEVOY ACTUATOR = BA KER KB. ELEV = 72.97' BF. ELEV = 44.49' KOP= 3100' Max Angle = 93 @ 10732' Datum MD = 10388' DatumTVD= 8800' SS 13-3/8"CSG, 72#, L80,ID=12.347" TOPOF BKR llEBACK SLV, 10 = 7.250" 9-5/8" X 7" BKR ZXP R<R, ID = 6.312" 9-5/8" X 7" BKR Hv1C LNR I-K3R, ID = 6.184" 9-5/8" CSG, 47#, L-80, ID = 8.681" 2705' 8141' 8148' 8154' 8298' SAFETY NOTES:W B.L > 70o@ 10600' AND> 90o@ 10700'. PRE-SDTRK WB.LBORE NOT SHOW NON THS DIAGRAM BELOW 9-5/8" SECTION MILLOUT WINDOW. *-r X IA X OA COMM. OPERATING UMITS: MAX lAP = 2500 PSI; MAX OAP = 2500 PSI. (06/06/03 W AlVER)*** NOTE: WLEG@ 9807' MAYOR MAY NOT BEFULLYINSERTID INTOTIEBACKSLV. H-17A (t 2105' ST MD 4 3601 3 6974 2 8671 1 9549 Minimum ID = 2.25" @ 10472' 4-1/2" ECLIPSE PATCH LOWER ELEMENT 4-1/2" TBG, 12.6#, L-80, .0152 bpf,lD =3.958" 'TOP OF llEBACK SLV, ID = 5.250" 1 17" X 5" BKRZXP PKR, ID = 4.408" 1 17" X 5" BKR HMC HGR, ID = 4.408" I , 7" LNR, 26#, L-80, ID = 6.276" 1 9806' 9808' 9814' 9822' PERFORATION SUMI'v1A RY REF LOG: OH CNL ON 09/04/97 ANGLEATTOPPERF: 54@ 10465' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 2-7/8" 4 10465 - 10470 0 04/05199 2-718" 4 10980 - 11020 0 03127198 2-718" 4 11320 - 11500 0 10/26197 2-718" 4 11530-11590 0 10/26197 2-718" 4 11650 - 11800 0 10/26197 2-3/4" 4 11750 - 11850 0 09/11197 2-3/4" 4 11950 - 12090 0 09/11197 2-3/4" 4 12160 -12318 0 09/11197 9953' 4-1/2" HES HXO SSSV N, ID = 3.813" GAS LIFT MANCR8...S lV D DEV TYPE V LV LA TCH 3496 22 MWG-M OOrvE RK 5992 44 MWG-M S/O RK 7347 27 KBG2LS DV BTM 8126 31 KBG2LS DV BTM PORT DA TE 16 09/23/97 20 09/23/97 0 09/23/97 0 09/23/97 9-5/8" MILLOUT WINDOW 8298' - 8348' (SECTION MLL) 9617 9628' 9774' 9795' 9807 9803' -14-1/2" HES X NIP, ID = 3.813" I -I7"X4-1/2"BKRSPKR,ID=3.875" I -14-1/2" HES X NIP, ID = 3.813" -14-1/2"HESXNNIP,ID=3.725" I -14-1/2" WLEG, ID = 3.958" I 1-1 ELMD TT LOGGED 09/23/97 I -ITOPOF ECLIPSE PKR SET 12/05/03 I 10460' 4-1/2" ECLiPSEPATCH, ID = 2.25" 10475' 4-1/2" ECLIPSE PATCH, ID = 2.25" SAFETY NOTE: A BKR OBP@ 11270' WAS MILLED OUT AND RJSHEDTO BTM @ 12297' CTMD ON 05/0101. EXERCISE CAUTION! 4-1/2"LNR,12.6#,L-80,.0152bpf,ID=3.958" -I 12450' I DATE REV BY COMMENTS DATE REV BY COMrvENTS 12/23/82 ORIGINAL COM PLETION 04/28/03 A lD/lLH WAIVER SAFETY NOTE 09/11/97 RIG SIŒTRACK 06/06/03 JRC/KK WAIVER SAFETY NOTE 09/23/01 CI-VKAK CORRECTIONS 12/05/03 KLC/lLP EQ.IPSE PA TCH 10/04/02 B IVVTP WAIVER SAFErY NOTE 03/23/03 JMP/KK DELETE WAIVER SAFETY NOTE 04/0 1/03 JRC/KK W AIV ER SA FErY NOTE PRLDHOE BA Y UNIT WELL: H-17A PERMIT No: 1971520 AR No: 50-029-20862-01 SEC21, T11N, R13E, 810'SN. & 1735'WEL BP Exploration (Alaska) Scblunl.epgøP Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# 10558569 10560252 10564482 10559786 40001315 40001315 40001315 10715362 Log Description Date MCNL SCMT SCMT SCiiiiT MWD GR (REPROCESSED) MWD GR MD MWD GR TVD MEM PPROF & IPROF 08/12/03 04/25103 06/10/03 OS/28/03 09/20/97 õ'/,- - ..' O~i ¿OJ?7 --I- 11/21'~:' ., ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~b~~ RECEIVED M^,O 1 PI "004 \':;"'\1', (;I....L ,Alaska Oil & Gas Cons. Commision Anchorage Blueline - " .-- 12/31/03 NO. 3087 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints CD 1 1 ) ;;P- L <=) ~.{ 1 1 1 1 IT 1 1 1 - Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received ~ \ Q..~ ~~\. C C"'o.J\ ø::-rr Schlmberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5714 ATTN: Beth 09/18/03 No. 2963 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD H-17A I <:2~ -cji '1 ~ i-~. MEM PROD PROFILE 08/13/07 E-27A 'i ~ ~ -~.~,~ , MEM PROD PROFILE 08~09~03 D.S. 13-08A i~'~ GLS 09/04/03 E-25 ~ ~' ~-' I ~A ~ LDL 09~05~03 D.S. 3-09 ,"~,~'-~}' ~ PSP PROD PROFILE 08/05/03 D.S. 1-11[~' ~~ -~. INJECTION PROFILE 09116103 K-07C ~' ~1' SBHP 09116103 A-23 ~ ~ ~ ~ RST-C G~VEL PACK 09107103 D.S. 15~8A ~, ~ ~~ PSP LDL 08~30~03 MPS-06 ~O :~ ~ [~ TEMPE~TURE LOG 08~30~03 1-35/O-25 -~ ~-I~ L! PROD PROFILE/DEFT/GHOST 09/14103 ~-209 23076 OH EDIT MWD SLIMPULSE & ARC DATA 10114/02 J-20B 23076 MD VISION RESlSTIVI~ J0/14/02 ~-209 23076 TVD VISION RESlSTIVI~ J0114102 , ;, ,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska),Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED Aiaska O[} & Gas ~,o~s. ~.0mr~l~n Anch0r~ge Schlumberger GeoQuest 3940 Arctic- Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, ~,~ ~ Commissioner ~i ?_~i~;~ Tom Maunder, ~~0.~ P. I. Supe~isor ~ ~, ~ ~ FROM: Lou Gfimaldi, SUBJECT: Petroleum Inspector DATE: April 22, 2001 SVS Misc. tests BPX H pad Prudhoe Bay Field Sunday, A~ril. 22, 2001: ! witnessed the first of the one-month retests of the SVS systems on BPX H pad wells in the GC-2 ama of the Prudhoe Bay Field. Merv Liddelow (BP Rep.) performed the SVS tests today. All components functioned propedy and held their pressure tests. The new style pilot boxes were installed on most of the wells, which combined with the reliability of the electronic pilots helped to produce these gmat results. The well houses were all clean with pilot valves in proper position. S.UMMARY: I witnessed the SVS test on twenty BPX H pad wells in the Prudhoe Bay Field. 20 wells, 40 components, No failures. Wellhouse Inspections; 33 wellhouses, No problems noted. Attachments: SVS PBU H-pad 4-22-01 LG.XLS . NON,-CONFIDEN?IAL, SVS PBU H-pad 4-22-01 LG Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Lou Grimaldi Submitted By: Lou G. Date: Field/Unit~ad: Prudhoe Bay field, H-pad Separator psi: LPS 157 HPS 22-Apr 650 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI TAp Code Code Code Passed GAS or CYCLE H-01A 1951100 H-02 1710160 H-04 1710220 H-05 1710240 650 550 550 P P OIL H-06 1770020 15'7 125 125 P P OIL H-07A · 2001280 H-08 1770230 H-11 1800680 157 125 100 P P 0iL H-12 1800670 H-13 1810170 650 550 525 P P OIL H-14A 1980680 H-15 1810610 157 125 125! P P OI~' H-16B 2000650 H-17A 1971520 65'0 550 510 P P OILi H-18 1822100 H-19B 1980940 65b 550 540 P e oIL , H-20 183007O H-21 1860710 650 550 525 P P OIL H-22A 1970480 157 125 125 P P OIL , H-23A 1950850 650 550 550 P P OIL H-24 1853050 157 125 115 P P OIL H-25 1852680 650 550 550 P P OIL H-26 1852770 157 125 95 P P OIL , H-27 1852360 H-28 1880440 H-29A 1980380 650 550 530 P P OIL H-30 1880350 650 550 525 P P OIL H-31 1940140 1H-32 1940250 157 1251 100 P P OIL H-33 1940380 650 5501 515 P P OIL H-34 1971640 157 125: 125 P P OIL H-35 1951490 650 550 515 P P OIL H-36A 2000250 H-37 1971020 157 125 125 P P OIL W~J,~'i/16/O! 20 comPonents: .. p~_~el~a#lu~es: 0 Well I Permit / Separ I Set [ L/P I T~st / Test / Test / Date Ion, WAG, GIN& Number I Number / PS! I PSI I Trip I Code / Code / Code ! Passed / GAS or CYCLE Remarks: Great test, no failures. RJF 1/16/01 Page 2 of 2 SVS PBU H pad 4-22-01 LG AOGCC Geological Materials Inventory PERMIT 97-152 ARCO Log 7849 Data Sent Recieved Box gP-E P~y'qVl p~I'/G Pale WR~ ...................... - ...... roy'r'sr97 .... ~T5'/9~ ....... ~'~ ¢'~CHLUM PEX-AIT/BHC 10/22/97 10/22/97 8155 &~PERRY GR/EWR4 MWD SRVY ~'~is~RRy 8292.20-12450. NGP/DGR/EWR4-MD ~060-12450 NGP/DGR/EWR4-TVD ~f~87-9039 PEX-AIT ~f~00-12430 PEX-BHP ~9~-00-12430 PEX-CN ~9~00-12430 PEX-CSL ~9~00-12430 PEX-LDT [~00-12430 PEX-SSTVD Leg)800-12430 TBNG CUT ~0-9070 dc~-407 Completion Date ~//r' ~ Are dry ditch samples required? yes Was the well cored? yes Are tests required? yes Well is in compliance Initial Comments Daily well ops 10/22/97 10/22/97 12/3/97 12/4/97 10/22/97 10/22/97 10/22/97 10/22/97 10/22/97 10/22/97 T 10/22/97 10/22/97 10/22/97 10/22/97 10/22/97 10/22/97 T 10/22/97 10/22/97 10/22/97 10/22/97 9/15/97 9/18/97 ~no And received? yes~'~"-no Analysis description recieved? -- Received? Thursday, September 23, 1999 Page 1 of 1 STATE OF ALASKA ALASKA ,JIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate I~ Plugging [] Perforate [--I Pull Tubing I--IAIter Casing I--~ Repair Well I--lOther 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 810' SNL, 1735' WEL, SEC. 21, T11N, R13E, UM At top of productive interval 1179' NSL, 1634' EWL, SEC. 15, T11 N, R13E At effective depth 3503' NSL, 1889' EWL, SEC. 15, T11 N, R13E At total depth 1799' NSL, 3511' EWL, SEC. 15, T11 N, R13E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) KBE = 72.97' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number H-17A 9. Permit Number / Approval No. 97-152 10. APl Number 50-029-20862-01 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 12450 feet true vertical 9039 feet Effective depth: measured 12321 feet true vertical 9031 feet Casing Length Structural Conductor 110' Surface 2667' Intermediate 9950' Production Liner Scab Liner 886' Plugs (measured) Junk (measured) Fill at 10821' MD (07/88); Fish at 10818' MD (03/90) Size Cemented 20" x 30" 8 cu yds concrete 13-3/8" 3720 cu ft Permafrost II 9-5/8" 1426 cu ft 'G', 133 cu ft PF 'C' 7" 391 cu ft Class 'G' 3-1/2" MD TVD 110' 110' 2705' 2705' 9987' 8473' 9602'-10894' 8163'-9311' 9638'-10524' Perforation depth: measured true vertical 10982'-11000'; 11000'-11020'; 11320'-11500'; 11530'-11590'; 11650'-11750'; 11750'-11800'; 11800'-11850'; 11950'-12090'; 12160'-12318' 9006'-9005'; 9005'-9010'(3 intervals)9012'-9013'; 9014'-9015' (3 intervals)9022'-9027'; 9026'- 9031 ', Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 9807' Packers and SSSV (type and measured depth) Packer @ 9328' SSSV @ 2105' RECEIVED 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure Alas~ 0il & Gas Cons. 6emmif~iorl Anchorage 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Prior to well operation: 1138 20790 225 Subsequent to operation: 1601 26958 445 Casing Pressure 0 0 Tubing Pressure 139 146 15. Attachments I16. Status of well classifications as: [--[ Copies of Logs and Surveys run I E] Daily Report o~/Vell Operati~s 7. I hereby c.~ify/t~at th~or/eg/.,gif~ is true,/an~rrect to the best of my knowledge Signed ~i~a I/~,,~__ _~_~J.,¢4,.__ Title Technical Assistant III Prepared By Name/Number: Service Date Form 10-404 Rev. 06/15/88 Submit In Duplicate. H-17A DESCRIPTION OF WORK COMPLETED ADDPERF 03/26/98 SUMMARY The following additional interval were perforated using 2 7/8" guns, 4 SPF, random orientation and 60/120° phasing. 10980' - 11000' MD 11000' - 11020' MD STATE OF ALASKA ~'~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOGs% 1. Status of Well Classification of Service Well.. [~Oil I--~ Gas I--] Suspended E~ Abandoned I-]Service _~,~ ~\ ~ ~¢¢~ 2. Name of Operator 7. Permit Number~~''' BP Exploration (Alaska)Inc. 97-152 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20862-01 4. 810' SNL, 1735' WEb, SEC. 21, T11N, R13E, U MAtL°cati°ntop of OfproductiveWell at surfaCeinterval~ -- - -'~ ~ ¥-'i':;?' il;i ?!~:'i ~ ;i'ii~'~ i c~ '/'~(J ~ i' ...................---'"' ~*: ~~'~""~:~~i¥1~lFl~ ! 10.9' UnitprudhOewell Number°r LeaSeBay UnitName 1179'NSL, 1634'EWL, SEC. 15, TllN, R13E ~ ~;~.iil; i i H-17A At total depth ........ 11. Field and Pool 1799' NSL, 3511' EWL, SEC. 15, T11N, R13E, UM ......................... ; Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 72.97'I ADb 028284 12. Date Spudded8/21/97 113' Date I'D' Reached i 14' Date C°mp" Susp" °r Abandl15' Water depth' if °fish°re 16' N°' °f c°mpleti°ns9/3/97 9/10/97 N/A MSL One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey t20. Depth where SSSV set 121. Thickness of Permafrost 12450 9039 FTI 12321 9031 FTI [~Yes ~lNo (Nipple) 2105' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, DEN,NEU, Sonic D I ¢_ IIk I A I 23. CASING, LINER AND CEMENTING RECORD ~ I \ I t./ ! | ~1/'~ L' CASING SETTING DEPTH HOLE SiZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20"X 30" Insulated Conductor Surface 110' 36" 8 cu yds concrete 13-3/8" 72# L-80 Surface 2705' 17-1/2" 3720 cu ft Permafrost II 9-5/8" 47# L-80 Surface 8298' 12-1/4" 1426 cu ft Class 'G, 133 cu ft PF 'C' 7" 26# L-80 8141' 9953' 8-1/2" 410 cuft Class 'G' 4-1/2" 12.6# L-80 9808' 12450' 6" 331 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9807' 9628' MD TVD MD TVD 11750'- 11850' 9014' - 9015' 11320' - 11500' 9010'- 9011' 11950' - 12090' 9021' - 9026' 11530' - 11590' 9012' - 9013' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 12160' - 12318' 9026' - 9031' 11650' - 11800' 9014' - 9014' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 151 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) September 25, 1997I Flowing Date of Test Hours Tested PRODUCTION FOR IOIL-BBL GAS-MCF WATER-BBb CHOKE SiZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBb GAS-MCF WATER-BBb OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 9911' 8512' Shublik 9950' 8546' Shublik 'B' 9991' 8582' Shublik 'C' 10016' 8604' Top of Sadlerochit 10039' 8624' Zone 4A 10145' 8712' Zone 2B 10430' 8902' HOT 11350' 9009' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true Flied correct to the best of my knowledge Signed ~ ~_.¢~ .... JamesSmith ~ Title Senior Drillin9 Engineer, Acting Date H-17A,// 97-152 Prepared By Name/Number: Terrie Hubble, 564-4628 Well NumbeY Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23.' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility PB H Pad Well H- 17A Rig Nabors 2ES Page 1 Date 24 October 97 Date/Time 16 Aug 97 17 Aug 97 18 Aug 97 19 Aug 97 20 Aug 97 21 Aug 97 10:00-00:00 00:00-02:30 02:30-04:30 04:30-06:00 06:00-07:30 07:30-08:00 08:00-10:00 10:00-13:30 13:30-15:30 15:30-17:30 17:30-19:00 19:00-20:30 20:30-06:00 06:00-07:30 07:30-08:00 08:00-08:30 08:30-15:30 15:30-17:00 17:00-18:00 18:00-19:30 19:30-22:00 22:00-22:30 22:30-03:00 03:00-05:30 05:30-06:00 06:00-18:00 18:00-19:30 19:30-22:30 22:30-23:30 23:30-00:00 00:00-03:30 03:30-05:00 05:00-05:30 05:30-06:00 06:00-07:00 07:00-08:00 08:00-08:30 08:30-09:00 09:00-10:00 10:00-14:00 14:00-14:30 14:30-17:30 17:30-18:30 18:30-19:30 19:30-02:30 02:30-04:00 04:00-05:00 05:00-06:00 06:00-08:30 08:30-09:00 09:00-12:00 12:00-15:30 15:30-17:00 17:00-03:30 Duration 14hr 2-1/2 hr 2hr 1-1/2 hr 1-1/2 hr 1/2 hr 2hr 3-1/2 hr 2hr 2hr 1-1/2 hr 1-1/2 hr 9-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 7hr 1-1/2 hr lhr 1-1/2 hr 2-1/2 hr 1/2 hr 4-1/2 hr 2-1/2 hr 1/2 hr 12hr 1-1/2 hr 3hr lhr 1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr lhr lhr 1/2 hr 1/2 hr lhr 4hr 1/2 hr 3hr lhr lhr 7hr 1-1/2 hr lhr lhr 2-1/2 hr 1/2 hr 3hr 3-1/2 hr 1-1/2 hr 10-1/2 hr Activity Rig moved 100.00 % Removed Hanger plug Rigged up Chicksan lines Circulated at 9045.86 ft Circulated at 9045.86 ft Installed Hanger plug Removed Xmas tree Installed BOP stack Tested BOP stack Removed Hanger plug Retrieved Tubing hanger Circulated at 9045.86 ft Laid down Tubing of 6500.00 ft Laid down 2520.00 ft of Tubing (cont...) Rigged down Tubing handling equipment Installed Wear bushing Conducted electric cable operations Installed Kelly Tested Casing - Via string Made up BHA no. 1 Singled in drill pipe to 3000.86 ft Serviced Block line Singled in drill pipe to 8592.86 ft Circulated at 8592.86 ft Circulated at 8592.86 ft Milled Casing at 8348.86 ft Circulated at 8348.86 ft Pulled out of hole to 675.86 ft Pulled BHA Made up BHA no. 2 R.I.H. to 8268.86 ft Washed to 8450.86 ft Rigged up Cement unit Held safety meeting Batch mixed slurry - 32.000 bbl Displaced slurry - 135.000 bbl Pulled out of hole to 7307.86 ft Circulated at 7307.86 ft Serviced Block line Pulled out of hole to 0.86 ft Washed to 20.86 ft Retrieved Seal assembly Set packer at 37.86 ft with 0.0 psi Rigged down BOP stack Installed Tubing head spool Rigged up BOP stack Pulled out of hole to 0.86 ft Tested BOP stack Tested BOP stack (cont...) Installed Wear bushing Made up BHA no. 3 R.I.H. to 8063.86 ft Drilled cement to 8301.86 ft Drilled to 8348.86 ft Facility Date/Time 22 Aug 97 23 Aug 97 24 Aug 97 25 Aug 97 26 Aug 97 27 Aug 97 Progress Report PB H Pad Well H- 17A Rig Nabors 2ES Page 2 Date 24 October 97 03:30-06:00 06:00-06:00 06:00-16:30 16:30-18:00 18:00-21:00 21:00-22:00 22:00-23:00 23:00-03:00 03:00-03:30 03:30-05:00 05:00-05:30 05:30-06:00 06:00-00:00 00:00-01:30 01:30-02:30 02:30-03:30 03:30-05:30 05:30-06:00 06:00-10:30 10:30-14:30 14:30-15:30 15:30-16:00 16:00-18:30 18:30-19:00 19:00-19:30 19:30-23:30 23:30-00:00 00:00-01:30 01:30-03:00 03:00-03:45 03:45-04:00 04:00-05:00 05:00-06:00 06:00-07:30 07:30-09:00 09:00-11:30 11:30-12:00 12:00-15:30 15:30-16:00 16:00-18:30 18:30-23:00 23:00-00:00 00:00-03:00 03:00-04:00 04:00-06:00 06:00-07:30 07:30-08:30 08:30-11:00 11:00-14:30 14:30-17:30 17:30-18:30 18:30-23:00 23:00-23:30 23:30-00:00 Duration 2-1/2 hr 24 hr 10-1/2 hr 1-1/2 hr 3hr lhr lhr 4hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 18hr 1-1/2 hr lhr lhr 2hr 1/2 hr 4-1/2 hr 4hr lhr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 4hr 1/2 hr 1-1/2 hr 1-1/2 hr 3/4 hr 1/4 hr lhr lhr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 2-1/2 hr 4-1/2 hr lhr 3hr lhr 2hr 1-1/2 hr lhr 2-1/2 hr 3-1/2 hr 3hr lhr 4-1/2 hr 1/2 hr 1/2 hr Activity Drilled to 8385.86 ft Drilled to 9042.86 ft (cont...) Drilled to 9416.86 ft (cont...) Circulated at 9416.86 ft Pulled out of hole to 900.86 ft Pulled BHA Made up BHA no. 4 R.I.H. to 8200.86 ft Serviced Block line R.I.H. to 9353.86 ft Reamed to 9416.86 ft Drilled to 9430.86 ft Drilled to 9953.86 ft (cont...) Circulated at 9953.86 ft Pulled out of hole to 8298.86 ft R.I.H. to 9953.86 ft Circulated at 9953.86 ft Pulled out of hole to 9500.86 ft Pulled out of hole to 1000.86 ft (cont...) Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Liner to 1790.86 ft (7in OD) Rigged down Casing handling equipment Circulated at 1880.86 ft Ran Drillpipe in stands to 8298.86 ft Circulated at 8298.86 ft Ran Liner on landing string to 9953.86 ft Circulated at 9953.86 ft Pumped Water based mud spacers - volume 70.000 bbl Mixed and pumped slurry - 73.000 bbl Displaced slurry - 206.500 bbl Reverse circulated at 8140.86 ft Reverse circulated at 8140.86 ft (cont...) Pulled Drillpipe in stands to 5400.86 ft Laid down 3568.00 ft of 5in OD drill pipe Retrieved Wear bushing Tested BOP stack Installed Wear bushing Made up BHA no. 5 Singled in drill pipe to 4700.86 ft Serviced Block line R.I.H. to 9810.86 ft Tested Liner - Via annulus and string Drilled installed equipment - Landing collar Drilled installed equipment - Float collar (cont...) Held drill (Kick (well kill)) Drilled cement to 9974.86 ft Circulated at 9974.86 ft Drilled to 10080.86 ft Circulated at 10080.86 ft Pulled out of hole to 222.86 ft Pulled BHA Made up BHA no. 6 Facility PB H Pad Progress Report Well H- 17A Rig Nabors 2ES Page Date 3 24 October 97 Date/Time 28 Aug 97 29 Aug 97 30 Aug 97 31 Aug 97 01 Sep 97 02 Sep 97 03 Sep 97 00:00-04:00 04:00-06:00 06:00-12:00 12:00-13:30 13:30-18:30 18:30-19:30 19:30-20:00 20:00-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-06:00 06:00-07:30 07:30-08:30 08:30-14:30 14:30-15:30 15:30-16:30 16:30-20:00 20:00-22:00 22:00-00:30 00:30-05:30 05:30-06:00 06:00-07:00 07:00-10:30 10:30-11:30 11:30-12:00 12:00-15:00 15:00-17:30 17:30-22:30 22:30-23:00 23:00-00:30 00:30-05:00 05:00-05:30 05:30-06:00 06:00-06:00 06:00-10:00 10:00-12:30 12:30-17:30 17:30-19:00 19:00-19:30 19:30-22:00 22:00-22:30 22:30-00:30 00:30-04:00 04:00-04:30 04:30-05:30 05:30-06:00 06:00-07:00 07:00-04:00 04:00-04:30 04:30-06:00 06:00-08:30 08:30-10:00 10:00-11:00 Duration 4hr 2hr 6hr 1-1/2 hr 5hr lhr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 1/2 hr 5hr 1-1/2 hr lhr 6hr lhr lhr 3-1/2 hr 2hr 2-1/2 hr 5hr 1/2 hr lhr 3-1/2 hr lhr 1/2 hr 3hr 2-1/2 hr 5hr 1/2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 24 hr 4hr 2-1/2 hr 5hr 1-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 2hr 3-1/2 hr 1/2 hr lhr 1/2hr lhr 21 hr 1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr lhr Activity R.I.H. to 10080.86 ft Drilled to 10163.86 ft Drilled to 10412.86 ft (cont...) Circulated at 10412.86 ft Pulled out of hole to 222.86 ft Pulled BHA Made up BHA no. 7 R.I.H. to 9885.86 ft Serviced Block line R.I.H. to 10355.86 ft Reamed to 10412.86 ft Drilled to 10615.86 ft Drilled to 10645.86 ft (cont...) Circulated at 10645.86 ft Pulled out of hole to 222.86 ft Pulled BHA Made up BHA no. 8 R.I.H. to 10550.86 ft Washed to 10645.86 ft Drilled to 10665.86 ft Pulled out of hole to 200.86 ft Pulled BHA Made up BHA no. 9 R.I.H. to 9867.86 ft Serviced Block line R.I.H. to 10665.86 ft Drilled to 10721.86 ft Circulated at 10721.86 ft Pulled out of hole to 200.86 ft Pulled BHA Made up BHA no. 10 R.I.H. to 10710.86 ft Circulated at 10721.86 ft Drilled to 10755.86 ft Drilled to 11655.86 ft (cont...) Drilled to 11813.86 ft (cont...) Circulated at 11813.86 ft Pulled out of hole to 200.86 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Made up BHA no. 11 R.I.H. to 9720.86 ft Serviced Block line R.I.H. to 11595.86 ft Reamed to 11620.86 ft Reamed to 11813.86 ft (cont...) Drilled to 12345.86 ft Circulated at 12345.86 ft Drilled to 12450.86 ft Circulated at 12450.86 ft Pulled out of hole to 9953.86 ft R.I.H. to 12450.86 ft Facility PB H Pad Progress Report Well H-17A Page 4 Rig Nabors 2ES Date 24 October 97 Date/Time 04 Sep 97 05 Sep 97 06 Sep 97 07 Sep 97 11:00-14:00 14:00-20:30 20:30-22:00 22:00-22:30 22:30-23:00 23:00-00:00 00:00-00:30 00:30-02:00 02:00-03:30 03:30-04:00 04:00-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-12:00 12:00-13:00 13:00-13:30 13:30-18:30 18:30-20:00 20:00-23:30 23:30-01:00 01:00-04:30 04:30-06:00 06:00-12:00 12:00-13:30 13:30-14:30 14:30-20:30 20:30-22:00 22:00-22:45 22:45-23:00 23:00-03:00 03:00-03:30 03:30-06:00 06:00-08:00 08:00-08:30 08:30-09:00 09:00-15:00 15:00-16:00 16:00-17:00 17:00-19:00 19:00-19:15 19:15-19:35 19:35-20:10 20:10-20:15 20:15-20:20 20:20-20:30 20:30-23:00 23:00-01:00 01:00-02:00 02:00-04:30 04:30-05:00 05:00-06:00 06:00-07:30 07:30-08:00 Duration 3hr 6-1/2 hr 1-1/2 hr 1/2hr 1/2hr lhr 1/2hr 1-1/2 hr 1-1/2 hr 1/2 hr 2hr lhr lhr lhr 3hr lhr 1/2 hr 5hr 1-1/2 hr 3-1/2 hr 1-1/2 hr 3-1/2 hr 1-1/2 hr 6hr 1-1/2 hr lhr 6hr 1-1/2 hr 3/4 hr 1/4 hr 4hr 1/2 hr 2-1/2 hr 2hr 1/2 hr 1/2 hr 6hr lhr lhr 2hr 1/4 hr 1/4 hr 1/2 hr 0hr 0hr 0hr 2-1/2 hr 2hr lhr 2-1/2 hr 1/2 hr lhr 1-1/2 hr 1/2 hr Activity Circulated at 12450.86 ft Pulled out of hole to 200.86 ft Pulled BHA Held safety meeting Held safety meeting Rigged up Logging/braided cable equipment Held safety meeting Rigged up Logging/braided cable equipment R.I.H. to 2100.86 ft Held safety meeting R.I.H. to 7500.86 ft R.I.H. to 8500.86 ft (cont...) Held safety meeting R.I.H. to 9754.86 ft Conducted electric cable operations Held safety meeting Rigged down Logging/braided cable equipment Pulled out of hole to 0.86 ft Removed Logging/braided cable equipment R.I.H. to 9714.86 ft Functioned Formation logs Ran logs on tubulars Ran logs on tubulars Ran logs on tubulars (cont...) Conducted electric cable operations Serviced Block line Pulled out of hole to 0.86 ft Rigged down Logging/braided cable equipment Rigged up Casing handling equipment Held safety meeting Ran Liner to 2625.86 ft (4-1/2in OD) Rigged up Tubing handling equipment Ran Tubing to 2-7/8in (1000.86 ft OD) Ran Tubing to 2550.86 ft (2-7/8in OD) (cont...) Installed Liner hanger Circulated at 2550.86 ft Ran Drillpipe in stands to 9953.86 ft Circulated at 9953.86 ft Ran Drillpipe in stands to 12450.86 ft Circulated at 12450.86 ft Pumped Water based mud spacers - volume 70.000 bbl Mixed and pumped slurry - 59.000 bbl Displaced slurry - 161.000 bbl Functioned Liner hanger Functioned Permanent packer Functioned Other sub-surface equipment Circulated at 12363.86 ft Pulled Drillpipe in stands to 9805.86 ft Circulated at 9808.86 ft Pulled Drillpipe in stands to 2550.86 ft Rigged down sub-surface equipment - Other sub-surface equipment Pulled Tubing in stands to 1500.86 ft Pulled Tubing in stands to 0.86 ft (cont...) Tested Liner - Via annulus and string Facility PB H Pad Progress Report Well H-17A Page 5 Rig Nabors 2ES Date 24 October 97 Date/Time 08 Sep 97 09 Sep 97 10 Sep 97 08:00-08:15 08:15-10:00 10:00-13:00 13:00-14:00 14:00-18:00 18:00-18:30 18:30-20:30 20:30-00:00 00:00-00:30 00:30-04:30 04:30-06:00 06:00-06:05 06:05-07:00 07:00-13:30 13:30-14:00 14:00-14:30 14:30-15:15 15:15-15:30 15:30-16:00 16:00-17:00 17:00-17:30 17:30-18:00 18:00-03:30 03:30-05:30 05:30-06:00 06:00-08:00 08:00-09:00 09:00-09:15 09:15-18:00 18:00-19:00 19:00-22:00 22:00-23:00 23:00-00:00 00:00-01:00 O1:00-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:15 08:15-08:30 08:30-09:00 09:00-09:30 09:30-11:00 11:00-13:00 13:00-13:30 13:30-14:30 14:30-15:00 15:00-16:00 16:00-18:00 18:00-19:00 19:00-20:00 Duration 1/4 hr 1-3/4 hr 3hr lhr 4hr 1/2 hr 2hr 3-1/2 hr 1/2 hr 4hr 1-1/2 hr 0hr 3/4 hr 6-1/2 hr 1/2 hr 1/2 hr 3/4 hr 1/4 hr 1/2 hr lhr 1/2 hr 1/2 hr 9-1/2 hr 2hr 1/2hr 2hr lhr 1/4 hr 8-3/4 hr lhr 3hr lhr lhr lhr 5hr 1/2 hr 1/2 hr 1/2 hr 3/4 hr 1/4 hr 1/2 hr 1/2 hr 1-1/2 hr 2hr 1/2 hr lhr 1/2 hr lhr 2hr lhr lhr Activity Held safety meeting Rigged up TCP guns Ran Tubing in stands to 2032.86 ft Ran Drillpipe in stands to 3940.86 ft Ran Drillpipe in stands to 10219.86 ft Functioned Perforating tools Ran Drillpipe in stands to 12321.86 ft Pulled Drillpipe in stands to 6000.86 ft Serviced Block line Pulled Drillpipe in stands to 600.86 ft Rigged down sub-surface equipment - TCP Rigged down sub-surface equipment - TCP (cont...) Rigged up sub-surface equipment - TCP Ran Drillpipe in stands to 10124.86 ft Functioned Perforating tools Ran Drillpipe in stands to 12321.86 ft Rigged up DST surface equipment Held safety meeting Perforated from 11750.86 ft to 12318.86 ft Reverse circulated at 9600.86 ft Flow check Circulated at 9600.86 ft Laid down 9700.00 ft of 5in OD drill pipe Laid down 2031.00 ft of Tubing Retrieved TCP Retrieved Gun assembly (cont...) Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 2100.86 ft (4-1/2in OD) Installed SCSSSV nipple assembly Ran Tubing to 9807.86 ft (4-1/2in OD) Space out tubulars Installed Tubing hanger Ran Tubing on landing string to 9807.86 ft Reverse circulated at 9807.86 ft Reverse circulated at 9807.86 ft (cont...) Set packer at 9627.86 ft with 3000.0 psi Tested Tubing Tested Casing Functioned Side pocket valve Retrieved Tubing landing string Installed Hanger plug Rigged down All functions Installed Adapter spool Tested Adapter spool Installed Xmas tree Tested Xmas tree Removed Hanger plug Circulated at 3600.86 ft Installed Hanger plug Rigged down High pressure lines H-17A Add Perforation 1 O/26/97 The following additional intervals were perforated using 2-7/8" guns, 4 SPF, random orientation and 90° phasing. 11320' - 11500'MD 11530' - 11590'MD 11650' - 11600'MD SPERRY-SUN DRILLING SERVICES BP EXPLORATION PBU / H-17A 500292086201 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/24/97 PAGE ANCHORAGE ALASKA qq- [ 5'2-' DATE OF SURVEY: 090397 MWD SURVEY JOB NUMBER: AK-MW-70241 KELLY BUSHING ELEV. = 72.97 OPERATOR: BP EXPLORATION INC. FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8292.20 7086.88 7013.91 8300.00 7093.41 7020.44 8326.82 7116.22 7043.25 8357.30 7142.71 7069.74 8388.34 7169.98 7097.00 33 28 32 47 30 38 28 39 28 24 N 75.57 E .00 1021.97N 3083.04E N 75.57 E 8.72 1023.03N 3087.17E N 75.57 E 8.05 1026.55N 3100.82E N 75.57 E 6.50 1030.30N 3115.42E N 73.56 E 3.20 1034.25N 3129.71E 3243.79 3248.06 3262.15 3277.23 3292.05 8418.80 7196.75 7123.77 28 34 8450.90 7224.96 7151.99 28 23 8482.67 7252.88 7179.91 28 38 8512.99 7279.49 7206.52 28 42 8544.76 7307.33 7234.36 28 53 N 71.55 E 3.20 1038.60N 3143.58E N 65.93 E 8.37 1044.15N 3157.83E N 58.90 E 10.59 1051.17N 3171.26E N 54.21 E 7.42 1059.18N 3183.39E N 48.02 E 9.40 1068.78N 3195.28E 3306.57 3321.79 3336.60 3350.42 3364.44 8576.00 7334.66 7261.69 8605.65 7360.60 7287.63 8637.63 7388.73 7315.76 8669.83 7417.30 7344.33 8699.86 7444.18 7371.21 29 7 28 52 27 59 26 58 26 2 N 41.43 E 10.25 1079.53N 3205.93E N 35.52 E 9.70 1090.77N 3214.86E N 29.46 E 9.43 1103.59N 3223.04E N 21.92 E 11.25 1116.94N 3229.48E N 15.34 E 10.24 1129.62N 3233.77E 3377.56 3389.16 3400.45 3410.22 3417.72 8731.55 7472.66 7399.69 8763.30 7501.12 7428.15 8794.89 7529.36 7456.39 8827.00 7558.09 7485.12 8858.85 7586.69 7513.72 26 3 26 36 26 37 26 26 25 47 N 7.52 E 10.83 1143.24N 3236.52E N 1.34 E 8.80 1157.26N 3237.60E N 1.00 W 3.32 1171.41N 3237.64E N .32 W 1.10 1185.75N 3237.48E N .03 W 2.05 1199.78N 3237.44E 3424.00 3428.77 3432.57 3436.22 3439.91 8888.74 7613.64 7540.67 8920.81 7642.62 7569.65 8952.09 7670.78 7597.81 8982.35 7697.81 7624.84 9077.86 7783.42 7710.45 25 27 25 15 26 19 27 5 25 31 N .46 W 1.33 1212.70N 3237.38E N .20 W .69 1226.43N 3237.30E N 2.42 W 4.58 1240.04N 3236.99E N 4.51 W 4.01 1253.61N 3236.16E N 3.55 W 1.69 1295.83N 3233.18E 3443.29 3446.87 3450.18 3452.99 3461.34 9170.86 7867.34 7794.37 9264.51 7951.09 7878.12 9354.11 8030.19 7957.22 9446.94 8110.91 8037.94 9539.77 8190.50 8117.53 25 32 27 35 28 26 30 41 31 15 N 3.01 W .25 1335:85N 3230.88E N .07 W 2.60 1377.70N 3229.80E N .79 E 1.05 1419.78N 3230.06E N 1.64 W 2.75 1465.57N 3229.69E N 1.35 W .63 1513.32N 3228.45E 3469.77 3479.85 3491.30 3503.11 3514.61 9633.65 8271.16 8198.19 9725.30 8350.46 8277.49 9818.10 8430.91 8357.94 9881.65 8486.18 8413.21 9981.57 8573.68 8500.71 3O 29 29 29 28 17 52 55 14 29 N .66 W 1.10 1561.35N 3227.60E N 1.40 E 1.21 1607.28N 3227.89E N .63 W 1.09 1653.53N 3228.20E N 1.60 E 2.04 1684.90N 3228.46E N 2.84 E .96 1733.09N 3230.32E 3526.57 3539.06 3551.66 3560.25 3574.86 SPER'~-~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION PBU / H- 17A 500292086201 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/24/97 DATE OF SURVEY: 090397 MWD SURVEY JOB NUMBER: AK-MW-70241 KELLY BUSHING ELEV. = 72.97 FT. OPERATOR: BP EXPLORATION INC. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10015.33 8603.43 8530.46 27 55 10037.48 8623.01 8550.04 27 51 10072.84 8653.82 8580.85 30 56 10102.91 8679.11 8606.14 34 31 10134.11 8704.08 8631.11 39 10 N 3.19 E 1.73 1749.03N 3231.16E 3579.90 N 6.33 E 6.64 1759.35N 3232.02E 3583.48 N 11.09 E 10.95 1776.49N 3234.68E 3590.60 N 16.46 E 15.32 1792.25N 3238.58E 3598.55 N 19.79 E 16.24 1810.02N 3244.43E 3608.91 10165.62 8727.62 8654.65 44 5 10196.03 8748.67 8675.70 48 17 10227.74 8769.30 8696.33 50 32 10259.21 8789.45 8716.48 49 55 10290.25 8809.59 8736.62 49 9 N 22.33 E 16.50 1829.54N 3251.97E N 24.97 E 15.13 1849.63N 3260.79E N 31.00 E 16.09 1870.86N 3272.10E N 37.46 E 15.89 1890.85N 3285.68E N 39.98 E 6.67 1909.27N 3300.45E 3621.37 3635.21 3651.76 3670.17 3689.30 10322.13 8830.45 8757.48 49 7 10369.56 8861.73 8788.76 48 20 10401.82 8883.26 8810.29 47 55 10428.56 8900.83 8827.86 49 54 10458.94 8919.74 8846.77 53 7 N 39.31 E 1.59 1927.83N 3315.83E 3709.07 N 40.50 E 2.49 1955.18N 3338.70E 3738.38 N 40.97 E 1.72 1973.39N 3354.38E 3758.34 N 42.89 E 9.17 1988.37N 3367.84E 3775.30 N 45.34 E 12.33 2005.43N 3384.40E 3795.80 10489.43 8937.39 8864.42 10519.32 8953.35 8880.38 10553.96 8969.84 8896.87 10584.85 8982.58 8909.61 10602.16 8988.81 8915.84 56 7 59 20 63 46 67 30 70 19 N 50.35 E 16.64 N 53.30 E 13.63 N 55.93 E 14.43 N 58.53 E 14.28 N 59.77 E 17.61 2022.09N 3402.83E 3818.00 2037.70N 3422.70E 3841.30 2055.32N 3447.54E 3869.93 2070.54N 3471.20E 3896.78 2078.82N 3485.06E 3912.35 10617.82 8993.78 8920.81 72 39 10646.46 9001.13 8928.16 77 36 10677.92 9006.21 8933.24 83 46 10700.44 9007.48 8934.51 89 46 10732.26 9006.79 8933.82 92 42 10763.24 9005.41 8932.44 92 23 10794.85 9004.87 8931.90 89 34 10825.41 9005.33 8932.36 88 42 10856.73 9005.94 8932.97 89 3 10887.49 9006.22 8933.25 89 52 N 59.99 E 14.94 N 59.23 E 17.51 N 60.43 E 19.97 N 63.94 E 30.85 N 67.15 E 13.66 N 70.24 E 10.02 N 71.47 E 9.73 N 72.20 E 3.69 N 72.69 E 1.90 N 72.62 E 2.71 2086.27N 3497.90E 3926.71 2100.27N 3521.77E 3953.44 2115.86N 3548.60E 3983.45 2126.34N 3568.48E 4005.40 2139.51N 3597.43E 4036.81 2150.75N 3626.26E 4067.59 2161.12N 3656.11E 4099.13 2170.64N 3685.14E 4129.65 2180.09N 3715.00E 4160.94 2189.26N 3744.36E 4191.68 10918.63 9006.12 8933.15 90 29 N 74.05 E 4.99 10950.95 9005.84 8932.87 90 31 N 73.73 E .99 10981.75 9005.31 8932.34 91 26 N 73.13 E 3.57 11010.80 9004.55 8931.58 91 34 N 74.44 E 4.53 11042.14 9004.04 8931.07 90 18 N 74.24 E 4.07 2198.19N 3774.19E 4222.81 2207.16N 3805.24E 4255.13 2215.94N 3834.75E 4285.91 2224.05N 3862.64E 4314.95 2232.50N 3892.81E 4346.28 SPER -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION PBU / H-17A 500292086201 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/24/97 DATE OF SURVEY: 090397 MWD SURVEY JOB NUMBER: AK-MW-70241 KELLY BUSHING ELEV. = 72.97 FT. OPERATOR: BP EXPLORATION INC. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11073.70 9004.45 8931.48 11104.82 9005.47 8932.50 11136.24 9006.53 8933.56 11168.19 9007.65 8934.68 11198.78 9008.70 8935.73 88 10 N 74.06 E 6.77 2241.12N 3923.16E 88 3 N 74.37 E 1.07 2249.58N 3953.09E 88 4 N 74.00 E 1.18 2258.14N 3983.30E 87 55 N 73.57 E 1.42 2267.06N 4013.96E 88 9 N 72.69 E 2.98 2275.93N 4043.22E 4377.83 4408.94 4440.34 4472.26 4502.83 11229.74 9009.63 8936.66 11260.23 9010.22 8937.25 11291.86 9010.19 8937.22 11321.39 9009.83 8936.87 11352.60 9009.23 8936.26 88 24 N 73.60 E 3.04 2284.90N 4072.83E 89 22 N 74.27 E 3.89 2293.34N 4102.13E 90 42 N 73.55 E 4.78 2302.10N 4132.51E 90 40 N 72.47 E 3.66 2310.73N 4160.75E 91 32 N 73.04 E 3.31 2319.98N 4190.55E 4533.76 4564.24 4595.87 4625.38 4656.57 11384.15 9008.39 8935.42 11415.51 9008.28 8935.31 11446.26 9009.14 8936.17 11477.43 9010.28 8937.31 11508.98 9011.38 8938.41 91 30 N 73.51 E 1.49 2329.06N 4220.76E 88 54 N 71.71 E 10.08 2338.43N 4250.68E 87 55 N 72.33 E 3.77 2347.92N 4279.91E 87 52 N 71.86 E 1.51 2357.49N 4309.55E 88 7 N 72.95 E 3.54 2367.02N 4339.61E 4688.10 4719.44 4750.14 4781.26 4812.77 11540.90 9011.99 8939.02 11571.67 9012.24 8939.27 11603.16 9012.72 8939.75 11634.94 9013.44 8940.47 11665.79 9013.98 8941.01 89 41 N 73.62 E 5.35 2376.20N 4370.17E 89 22 N 72.90 E 2.55 2385.06N 4399.64E 88 53 N 72.46 E 2.09 2394.44N 4429.69E 88 30 N 72.65 E 1.37 2403.96N 4460.00E 89 30 N 73.02 E 3.49 2413.06N 4489.47E 4844.67 4875.43 4906.90 4938.65 4969.48 11696.62 9014.26 8941.29 11727.94 9014.30 8941.33 11755.46 9014.05 8941.08 11791.58 ~9013.72 8940.75 11820.79 9013.98 8941.01 11852.25 9015.15 8942.18 11883.62 9016.73 8943.76 11915.09 9018.98 8946.01 11945.28 9021.21 8948.24 11974.75 9022.52 8949.55 89 26 N 72.53 E 1.60 90 24 N 71.79 E 3.84 90 39 N 72.03 E 1.26 90 24 N 71.73 E 1.08 88 33 N 71.10 E 6.66 87 10 N 71.28 E 4.42 87 3 N 70.80 E 1.58 84 43 N 72.10 E 8.45 86 48 N 72.41 E 6.93 88 7 N 73.44 E 5.68 2422.19N 4518.92E 5000.29 2431.79N 4548.73E 5031.58 2440.33N 4574.89E 5059.07 2451.57N 4609.22E 5095.15 2460.87N 4636.90E 5124.31 2471.01N 4666.66E 5155.69 2481.19N 4696.29E 5186.96 2491.17N 4726.04E 5218.30 2500.35N 4754.71E 5248.38 2508.99N 4782.85E 5277.81 12006.66 9023.63 8950.66 12037.66 9024.80 8951.83 12069.50 9026.03 8953.06 12100.39 9026.40 8953.43 12131.35 9026.06 8953.09 87 54 N 73.12 E 1.20 87 43 N 73.47 E 1.27 87 50 N 74.04 E 1.83 90 46 N 75.68 E 10.84 90 29 N 76.85 E 3.89 2518.17N 4813.40E 5309.69 2527.07N 4843.07E 5340.66 2535.97N 4873.61E 5372.47 2544.04N 4903.42E 5403.35 2551.39N 4933.49E 5434.30 SPEP -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLOR3~TION PBU / H-17A 500292086201 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/24/97 DATE OF SURVEY: 090397 MWD SURVEY JOB NUMBER: AK-MW-70241 KELLY BUSHING ELEV. = 72.97 FT. OPERATOR: BP EXPLORATION INC. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 12162.55 9025.91 8952.94 90 3 N 78.75 E 6.24 2557.98N 4963.98E 12193.71 9025.95 8952.98 89 49 N 78.66 E .82 2564.08N 4994.54E 12224.76 9026.37 8953.40 88 37 N 78.67 E 3.86 2570.19N 5024.98E 12255.64 9027.63 8954.66 86 42 N 79.58 E 6.85 2576.01N 5055.27E 12285.34 9029.27 8956.30 86 55 N 79.45 E .86 2581.40N 5084.43E 5465.44 5496.52 5527.49 5558.24 5587.78 12316.65 9031.04 8958.07 86 37 N 79.64 E 1.16 2587.08N 5115.18E 12348.72 9032.92 8959.95 86 39 N 79.91 E .85 2592.76N 5146.68E 12388.15 9035.29 8962.32 86 25 N 80.97 E 2.75 2599.29N 5185.49E 12450.00 9039.14 8966.17 86 25 N 80.97 E .00 2608.98N 5246.46E 5618.93 5650.81 5689.96 5751.31 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5859.36 FEET AT NORTH 63 DEG. 33 MIN. EAST AT MD = 12450 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 74.58 DEG. TIE-IN SURVEY AT 8292.20' MD WINDOW POINT AT 8300.00' MD PROJECTED SURVEY AT 12,450.00' MD SPER -SUN DRILLING SERVICES ANCHOR3AGE ALASKA PAGE BP EXPLORATION PBU / H-17A 500292086201 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/24/97 DATE OF SURVEY: 090397 JOB NUMBER: AK-MW-70241 KELLY BUSHING ELEV. = 72.97 FT. OPERATOR: BP EXPLORATION INC. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8292.20 7086.88 7013.91 9292.20 7975.63 7902.66 10292.20 8810.86 8737.89 11292.20 9010.19 8937.22 12292.20 9029.64 8956.67 1021.97 N 1390.52 N 1910.40 N 2302.20 N 2582.66 N 3083.04 E 1205.32 3229.78 E 1316.57 111.25 3301.40 E 1481.34 164.77 4132.84 E 2282.01 800.67 5091.17 E 3262.56 980.55 12450.00 9039.14 8966.17 2608.98 N 5246.46 E 3410.86 148.30 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPER' -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION PBU / H-17A 500292086201 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/24/97 DATE OF SURVEY: 090397 JOB NUMBER: AK-MW-70241 KELLY BUSHING ELEV. = 72.97 FT. OPERATOR: BP EXPLORATION INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8292.20 7086.88 7013.91 1021.97 N 3083.04 E 1205.32 8391.75 7172.97 7100.00 1034.71 N 3131.27 E 1218.77 13.45 8505.56 7272.97 7200.00 1057.15 N 3180.45 E 1232.59 13.82 8619.74 7372.97 7300.00 1096.37 N 3218.59 E 1246.77 14.17 8731.90 7472.97 7400.00 1143.39 N 3236.54 E 1258.93 12.16 8843.59 7572.97 7500.00 1193.09 N 3237.45 E 1270.62 11.69 8954.54 7672.97 7600.00 1241.13 N 3236.93 E 1281.56 10.95 9066.28 7772.97 7700.00 1290.85 N 3233.49 E 1293.31 11.74 9177.10 7872.97 7800.00 1338.54 N 3230.74 E 1304.13 10.83 9289.20 7972.97 7900.00 1389.14 N 3229.78 E 1316.23 12.10 9402.90 8072.97 8000.00 1443.23 N 3230.25 E 1329.93 13.70 9519.26 8172.97 8100.00 1502.68 N 3228.70 E 1346.29 16.35 9635.74 8272.97 8200.00 1562.41 N 3227.59 E 1362.77 16.49 9751.26 8372.97 8300.00 1620.21 N 3228.21 E 1378.29 15.51 9866.51 8472.97 8400.00 1677.51 N 3228.25 E 1393.54 15.26 9980.76 8572.97 8500.00 1732.71 N 3230.30 E 1407.79 14.25 10095.54 8672.97 8600.00 1788.32 N 3237.51 E 1422.57 14.78 10233.49 8772.97 8700.00 1874.62 N 3274.45 E 1460.52 37.96 10386.44 8872.97 8800.00 1964.73 N 3346.90 E 1513.47 52.94 10561.37 8972.97 8900.00 2059.00 N 3453.16 E 1588.40 74.94 12450.00 9039.14 8966.17 2608.98 N 5246.46 ~ 3410.86 1822.45 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11482 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape H-17A ~ ~/~r_~(-/ 97464 PEX-AIT,BHC 970904 1 H-17A 97464 PEX-AIT 970904 1 1 H-17A 97464 PEX-CNL 970904 I 1 H-17A 97464 PEX-LDT 970904 I 1 H-17A 97464 PE×-COMPENSATEDSONIC 970904 I 1 H-17A 97464 PEX-BOREHOLEPROFILE 970904 I 1 N-17A 97464 PEX-SSTVD 970904 1 1 10/22/97 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 0 Ft I I--I_11M G S ~: I~! ~.~ I r- ~:: c:~ WELL LOG TRANSMITTAL To: State of Alaska October 22, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 (~"'1 ,-' t ~ ~ MWD Formation Evaluation Logs H-17A, AK-MW-70241 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' Ylm Galvi~ Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 H-17A: 2" x 5" MD Resistivity & Cramma Ray Logs: 50-029-20862-01 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20862-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 'REC OCT 22 199:t 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ri IR I LLI I~i G S I:: IR~./I C E S WEI,I, LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: M'WD Formation Evaluation Logs H-17A, AK-MW-70241 October 22, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-20862-01. RECEIvbu OCT 2 2 1997 Oil & Ga~ ~,.,~:-',.~ ,.~,,,~ .~ch.' cra,..~e 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 9/15/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11349 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape A- 23 PRODUCTION PROFILE W/DEFT 9 70 80 5 I 1 E-02A ~ PLUG SET RECORD 970802 I 1 ' F-39 STATIC SURVEY 9 70 80 3 I 1 F-43 L1 PRODUCTION LOG 970809 I 1 H-17A TUBING CUT W/JET CUTTER 9 70 8 0 7 I 1 H-22A LEAK DETECTION 9 70 8 0 3 I 1 H-37 L1 ML PACKER SET 970801 I 1 J-17 MULTI-RATE PROD. LOG 9 70 80 3 I 1 N- 1 9 PERFORATION RECORD 9 70 80 7 I 1 U- 13 STATIC TEMP/PRESS SURVEY 9 70 81 0 I 1 U- 14 STATIC TEMP/PRESS SURVEY 9 70 81 0 I 1 W-06A JEWELRY LOG/GR-CCL 9 70 80 5 I 1 W-06A DP GUNS/PERFORATING RECORD 9 70 805 I 1 W-06A I STATIC PRESSURE & TEMP 970806 I I qo · zq I qq. 'a'5' o'"~ 7-~' roi q~'/oD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED SEP 1 8 1997 ~aska C/~ ~,~ ~,,,. - ............. Anchorage Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received MEMORANDUM TO: David Johnst~o,-~ Chairman~ THRU: Blair Wondzell, P. !. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 1, 1997 FILE NO: aimkiaee.doc FROM: Chuck Scheve, ~- 4~ SUBJECT: Petroleum Inspector BOPE Test- Nabors 2ES PBU H-17A PTD # 97-152 Monday September 1~ 1997: I traveled to BPX's PBU well H-17A and witnessed the weekly BOPE test on rig 2ES. As the attached AOGCC BOPE Test Report shows there were no failures. The testing went very well this evening with good test procedures being employed by the Nabors crew. The rig was clean and all equipment seemed to be in good working order. The location was clean and all extra equipment was stored properly. Summary: I witnessed the weekly BOPE test on Nabors Rig 2ES drilling BPXs H-17A well. NABORS 2ES, 9/1/97, TEST TIME 2.5 HOURS, NO FAILURES Attachment: aimkiaee.xls X Unclassified Confidential (Unclassified if doc. removed ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: NABORS Rig No. Operator: BPX Well Name: H-f7A Casing Size: 7" Set @ 9,953 Test: Initial Weekly X Other 2ES PTD # Rep.: Rig Rep.: Location: Sec. 97-152 DATE: 9/1/97 Rig Ph.# 659-4836 Charfie Dixon Robert French 21 T. 11N R. 13E Meridian Um. Test Well Sign OK Drl. Rig OK Hazard Sec. YES - FLOOR SAFETY VALVES: Quan. Pressure P/F Upper Kelly/IBOP I I 500~5000 I P Lower Kelly / IBOP 1 I 500~5000 I P Bali Type 2 500/5,000 I P Inside BOP 2 500/5,000 I P MISC. INSPECTIONS: Location Gen.' OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan, Test Press. 250/2500 250/50O0 250/5000 250/5000 250/5000 250/5OOO 250/5000 N/A P/F Test P CHOKE MANIFOLD: Pressure P/F , , P No. Valves 14 250/5, 000 P ,~ , P No. Flanges 32 250/5,000 P P Manual Chokes 1 Functioned P P Hydraulic Chokes ~ Functioned P 2 P P 3, 000 P 1,600 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: MUD SYSTEM: Visual Alarm 0 minutes 25 sec. TdpTank OK OK 1- minutes 37 sec. Pit Level Indicators OK OK YES Remote: YES Flow Indicator OK OK 4 ~2 ~ O0 Meth Gas Detector OK OK , Psig. H2S Gas Detector OK OK Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good Test Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector FI-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: AIMKIAEE.XLS Chuck Scheve TONY KNOWLE$, GOVEF~NOF~ ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 7, 1997 Dan StoRz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit H- 17A BP Exploration (Alaska) Inc. Permit No: 97-152 Sur. Loc.: 810'SNL, 1735'WEL, Sec. 21, TI 1N. RI3E. UM Btmhole Loc: 1749'NSL, 1606'WEL, Sec. 15, T1 IN, RI3E, UM Dear Mr. StoRz: Enclosed is the approved application for permit to redrill the above rcfercnccd well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting &terminations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of thc Commission may xvitncss the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. J~:i~ston Chairman ~) BY ORDER OF THE COMMISSION dlffenclosures cc: Departmet~t oF Fish & Game. ltabitat Section w/o encl. Department ol'l~.nvinonuncnt Conservation w'o encl. ~' .... . STATE OF ALASKA ALASKA ...~L AND GAS CONSERVATION CO~,,,¢IlSSlON PERMITTO DRILL ':.' " 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] S..t_r. atigraPh!C Test [] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas []sir~gie'z0ne [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 72.14' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028284 ~,. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 810' SNL, 1735' WEL, SEC. 21, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 29100302630-277 1251' NSL, 3414' WEL, SEC. 15, T11N, R13E H-17A At total depth 9. Approximate spud date Amount $200,000.00 1749' NSL, 1606' WEL, SEC. 15, T11N, R13E, UM 08/17/97 :i"2. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028285, 1606'I No Close Approach 2560 12563' MD / 8960' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8300' MD Maximum Hole Ang e 89° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig i'8. Casing Program Setting Depth ...... Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-Mod 1744' 8150' 6896' 9894' 8436' 165 sx Class 'G' .... 6" 4-1/2" 12.6# L-80 IBT-Mod 2819' 9744' 8303' 12563' 8960' 290 sx Class 'G' i~l.~.,I..~ v ~,,,,,'-. 19. To be completed for Redrill, Re-entry, and Deepen Operations. 0RI ~ t ~_~A L ~ Present well condition summary /~(~-'.' "5: 11~0~ Total depth: measured 10901 feet Plugs (measured) .... true vertical 9317 feet AlaS}G3 011 & Gas Cons. C0mmissi~,' Effective depth: measured 10821 feet Junk (measured) Fill at 10821' MD (07/88); Fish ~tfl6fl~r{l~eMD (03/90) true vertical 9237 feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" x 30" 8 cu yds concrete 110' 110' Surface 2667' 13-3/8" 3720 cuft Permafrost II 2705' 2705' Intermediate 9950' 9-5/8" 1426 cuft 'G', 133 cuff PF 'C' 9987' 8473' Production Liner 7" 391 cuff Class 'G' 9602' - 10894' 8163' - 9311' 886' 3-1/2" Scab Liner 9638' - 10524' Perforation depth: measured Aggregate Open Interval: 10540' - 10622' Aggregate Squeeze / Abandoned Interval: 10282' - 10540' true vertical Aggregate Open Interval: 8972' - 9050' Aggregate Squeeze / Abandoned Interval: 8733' - 8972' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number:__ _ /3 .~W~.p~AubeR, 564-4825 Prepared By Name/Number: Terrie Hubble, 564-4628 21.1 hereby certify that th/e~fore~l/oing/~//t/fu¢?r)d correct to the best of my knowledge Signed l / Z..,,~. ~"'.,,/ .... DanStoltz jl~f¢~______~~;;~ Title Senior Drilling Engineer Date"/¥'- Commission Use Only "~ermit Number I APl Number I Approval Date I See cover letter ....~'7-'/~', ~'2, 50-029-20862-01 ~_~ ~ ¢ ~ ~'~ for other requirements Conditions of Approval: Samples Required I--lYes ~--INo Mud Log Required []Yes [] No Hydrogen Sulfide Measures j~]Yes [] No Directional Survey Required I~[Yes [] No Required Working Pressure for BOPE 1--12M; 1'-13M; 1~]5M; I'-110M; I--I15M Other: Original Sigpeo i¢y by order of Date~-'" Approved By David W. Johnston Commissioner the commission Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: IH-17A I HAW Sidetrack Summary I Type of Well (producer or injector): I Producer I Surface Location: Target Location: 4470' FSL, 1736' FEL, S21, TI iN, R13E, UM 1749' FSL, 1606' FEL, S15, TllN, R13E, UM I AFE Number: 14Pi000.0 ] ] Estimated Start Date: 18/17/97 I I MD: 112,563' [ ]TVD: [Rig: I Nabors 2ES I Operating days to complete: 126 18,960' ss I I KB Elev. 172.14' I Well Design (conventional, slimhole, etc.) I HAW Sidetrack Objective: H-17A targets Zone 2B 22P (FLS 6200-6600) sand intervals in a high-angle wellbore section imme- diately north (updip) of the updip limit of the northeastern H-Pad GDWFI area. The Zone 2 target is an elongate east-west trending fault block bounded on the north, south, and west by moderate dis- placement faults (10'-40' displacement) which step down from the target fault block. H-17A TD will lie immediately north (updip) of the present northern H-Pad GDWFI water influx wedge, so H-17A is expected to show little or no water cut during the first year of production. Liquid offtake from D-26A should help limit updip water movement from the GDWFI into the GD area, so should help H-17A production remain at relatively Iow watercut for a longer time. Formation Markers Formation Tops MD TVD (ss) 8514' 7209' Kingak Sag River Shublik 9883' 8426' 9918' 8457' TSAD 10011' 8540' Cement Calculations Lead Cement Tail Cement Casing/Liner Sk / Wt / Yield Sk / Wt / Yield Comments .,; ..... Cl G; Tail FW=0; '? 7" N/A 165 / 15.8 / 1.14 30% excess; Pump time=4+ hr.; TOC = _+8860' MD (_+1,000' above Sag River) 4-1/2" N/A 290 / 15.7 / 1.19 Class G: 30% excess; Pump time = 4 hr.; TOC 150' above TOL Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. CasingfTubing Program Hole Tubular Wt/Ft Grade Conn Length Top Btm Size O.D. MD/TVD MD/'FVD 8-1/2" 7" 26# L-80 BTC- M od 1744' 8150'/6896' 9894'/8436' 6" 4-1/2" 12.6# L-80 I BT-Mod 2819' 9744'/8303' 12563'/8960' Prod Tubin~l N/AI 4-1/2" 12.6# L-80 BTC-Mod 9718' 26'/26' 9744'/8303' Logging Program Open Hole Logs: 8-1/2" Hole 6" Hole IMWD/GR MWD/GR/Resistivity, DPC GR/Resistivity/Density/Neutron/Sonic None planned Cased Hole Logs: Mud Program Milling Interval: Gel-free 6% KCI Biozan [ Density, ppg I Funne, Vis, secI YP [ Gels I .. I.~.~.~,co 9.8 - 10.0 50 - 65 50 - 60 20-30 / 30-40 9 - 10 <14 Hazards/Concerns Maintain YP 50 - 60 to insure adequate removal of metal cuttings. Insure adequate preparation to eliminate metal entering motor and MWD from mud bypassing solids control equipment. Intermediate (8-1/2" hole) Section: Gel-free 6% KCI Biozan I Density, ppg I Funne, Vis, sec 1 LSRYP [ Gels ] p. HPH, FL, cc 10.0 50 - 65 8 - 13 15-25 / 20-35 8 - 9 <10 Hazards/Concerns Follow guidelines for stabilizing Kingak shale. Be alert for lost circulation, differential sticking due to higher MW. Production (6" hole) Sections: Quickdriln (viscosified SW) I Density, ppg I Funne, Vis, sec [ LSR YP[ LSR Vis i pH 8.6 - 8.8 55 - 65 14 - 20 > 45,000 8.5 - 9.0 NC Hazards/Concerns Potential high torque could require lubricant use. Be alert for lost circulation, differential sticking due to overbalanced MW. Maximize solids control to keep fluid as clean as possible. Max mud weight 8.8 ppg. KOP: 18300' MD IMaximum Hole Angle: Surface Close Approach Wells: Drilling Close Approach Wells: Directional 89° through targets H-24 is approx. 55' away None Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular pre- venter will be installed and is capable of handling maximum potential surface pressures. DJ- verter, BOPE and mud fluid system schematics on file with AOGCC. Hazards · H-Pad is a known shallow hydrocarbon area. · Stuck pipe, tight hole, and swabbing have occurred in H-Pad wells through Kingak shale. · Lost circulation through conductive faults is a possibility on H-Pad. No annular injection is planned for H-17A. Pre-Rig Procedure 1. , , , , Operations Summary Notify AOGCC representative prior to commencing P&A operations. Kill well with sea water. If significant fluid loss is experienced (> 20 bbl/hr), inform Nabors 2ES rig representative immediately. RU electric line unit and chemical cutter for 5-1/2" tubing. RIH and chemical cut 5-1/2" tubing at _+9500' MD, in middle of first full joint of 5-1/2" tubing above SBR. RU and reverse circulate seawater through tubing cut until returns are clear. Monitor for fluid loss. Freeze protect well with diesel to 2,000'. Have FMC wellhead services replace and test 9-5/8" packoff to 5,000 psi and service lock down studs. Notify Rig Representative immediately of any pressure test or wellhead con- dition problems. 6. Bleed pressure from tubing, inner and outer annuli; zero psi is requested. , Install BPV. Remove well house and flowlines. Prepare for rig arrival. Level pad. Dig out cellar. Drillinq Rig Procedure 1. MIRU drilling rig. Kill well if necessary. ND tree, NU and test BOPE. 2. Pull tubing hanger and 5-1/2" tubing. 3. Set EZSV @ _+8600' MD. Test 9-5/8" casing to 3500 psi. , RU and establish injection using seawater. Bullhead seawater to kill well if necessary. Mix and pump 17.5 bbl (100 ft3) Class G cement. Displace cement below EZSV until _+5 bbls cement are squeezed into perforations from 10,540'-10,620' MD, leaving _+9.4 bbls (_+979') cement above top perforation. Proposed TOC is _+9561' MD (top of production packer). 5. Mill section in 9-5/8" casing near 8300' MD. 6. Set cement plug' above EZSV, kick off @ 8300' MD and drill 8-1/2" well bore per plan. 7. Run and cement 7" liner to TD. 8. Drill 6" horizontal lateral per directional plan. 9. Log well per asset request. 10. Run and cement 4-1/2" solid liner. 11. 12. 13. Perforate 4-1/2" solid liner with DPC guns. Run 4-1/2" L-80 completion. Freeze protect well, set packer, set BPV, ND BOPE, NU and test tree, RDMO. Prepared by: Ops Drlg Engr Approved by: Sr Drlg Engr H-17A (P6) 28 Jul 1995 Page ~~mmmm~ mmmmmmmm ~m RTAT£ON bL?.AS UR ~ INCL~ £ DEIV~I PZCAT l ON DEPTH ANGI2R TOP S}{UBLXK 9917.79 27.56 TOP SADLEROCHIT LDDLI.4L 27.56 CURV~ L5/L00 L001~,73 2~.56 ~0~00.00 32.97 30200,00 43,07 ~ XS/100 CU~VH 10227.06 46.19 TOP ZONE ] 10234.28 TOP ZONH 2C 'k0335.4/ 46-19 CURVE 15/100 ~0357.08 46.19 PGC)'C ~D386.96 49.78 2SN FAULT 30400.00 53.38 10427.86 54.85 10445.73 57.11 10474.84 60.85 10500.00 6t. LL L0600.O0 77.33 OMC 10628.89 81.19 · END 15/100 CURVE 10688.43 89.18 TAROET START **~**** 30688.43 89.18 CURVE 5/L00 32081.32 89.18 12100.00 88.99 END 5/100 CUR1/B 12119.]0 88.79 4-1/2" LIITHR POINT 12562.51 88.79 BASE O~f / ROT 12569-.51 88-79 TD / TARGET END ~**~ 1256~-.51 88.79 (Anadx/ll (c]97 HLTAP06 3.0C 4:19 PM P) PR~)POSBD ~ELL PROFI~H RHCTKON VERT2 CAL -DEPTHS 0,98 8529. L4 8457.00 0.98 86L2.L~ 8540,00 0.98 86~5.08 8542.94 24,~8 8688.95 8616.01 42.37 8767.88 8695.74 SECTION COORDINATES-FROM ALASKA Zone 4 TOOL D~/ DB~ART W~LLHEAD X Y FAC]5 100 3619.58 £710.a£ N 3209.21 E 646018.88 596174~.77 3644.~5 1753.53'N 3209.95 H 646038.79 596~784.09 HS 0.00 3645.02 1755.06 N 3209.97 E 646018.79 5961785.62 76R 0.00 3675.96 ~796.12 N 3219.86 H 6~6017.89 5961826.86 55R [5.00 3732.42 1846.45 ~ 325{.21 E 64606X.28 596~877.83 41R 15.00 46.06 8787.[~ 87/5.00 46.06 8792.34 8~20.00 46.06 8862.14 8790,00 46.06 8877.14 8805.00 49.68 8897,14 8825,00 3751.00 1860.06 N 3267.4? B 64607~,28 5961891.68 H$ 15.00 3756.12 1863.67 N 3271.23 H 646097.97 5961895.57 H~ 0.00 38~7,91 1914.31 N 3323-78 E 646129.54 5961946.99 HS 0.00 3843,30 L925.16 N 3335.04 E 646140.59 5961958.06 38R 0.00 3865.25 L940,04 N 3351.51 E 646156.78 5961973.24 36R 15.00 51.14 8905.42 8833,28 54,05 8922.14 8850,00 55.79 8932-]4 8860,00 58.43 8947.14 8875,00 60.~$ 8958.77 8886.63 38~5.26 1946.~5 N 3359.28 H 646164.42 5961979.80 35R LS.00 3897,49 1959.98 N 3376.98 E 646181.86 5961993.66 33R L5.00 3912.30 1968.49 N 3389.10 E 646193.82 5962002.40 32R 1~.O0 3937,23 1982.02 N 34~0.05 E 646214.50 5962016.32 ~R 1~.00 3959.51 1993.34 N 3429.27 ~ 646233.51 5962028.00 30R 15.00 68.1~ 8991.76 89£9.62 40~2.68 2033.86 70.11 8997.1~ 8925.00 4080-34 2043.97 74.i2 9002.~4 8930.00 4137.~1 2062.16 74.12 9002-14 8930.00 4137.41 2062.16 74.12 9022-14 8950.00 5464.28 2443.30 3514.20 B 646317.6{ 5962070.13 27R LS.O0 3540.70 g 646343.9~ 5962080.74 27R 3~.00 3597.12 E 646400.00 5962100.00 ~[S 1~.00 3597.12 E 646400.00 5962100.00 RS 15.00 4936.7[ N 64773~,00 S962506.50 102R 0.00 T5-03 9022.44 8950.30 75.98 9022.8~ 8950.67 75.98 9032.14 8960.00 75.98 9032,34 8960.00 75.98 9032.~4 8960.00 5482.02 2448,26 N 4954,TL 5500,26 2453.09 N 4973,39 5917-82 2~60.~6 N 5405.30 59L7.82 2560,46 N 540].3~ 5917.82 2560.46 N 5403.30 , . , 647749.90 5962511.81 LO~R 5,00 647768.49 5962516.99 HS 5,00 648196.25 5962632.50 0.00 648196.25 5961632.5~ 0.00 648196.95 596263~,50 0.00 ANADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOP, EXECUTION PLAN .. -~.~.~ ~ .... ; ............ ~.-. .... ~ ..~.~ .~- r. ---=:.: ',.'-. ---: -.,-,- ~: ~.= -- -----='= Z C) AnadrlLi Schlumberger ALaska District llll East 80th Avenue Anchorage, AK 99518 (90~) 349-45Lt Pa~ 344-2L60 ' DIRECTIONAL NELL PL~%~ for SHARED S~RVICES DRILbING well ......... : K-11A (P6) Field ........ : Prudhoe Bay, Computation..: Minimum Curvature Units ........ : FHHT Surface l~at..: 70.29815551 Surface Long.= 148.843L~750 Legal Description Burface ...... : 4470 FSL 1736 T~e-£n survey: 2iL F~L 3930 Target S~arL.: 125L FSL 34L4 PHL 815 TllN R13~ UM 8~{L .......... : 1749 F~L 1606 STATION IDenTIFICATION T~H-IN ~URVEY TOP 0~ WINDOW KOP CIlRVE 9/100 IX)CATIONS - ALASKA Zone: & X-Cx>°rd ¥-Coord 642843.00 5959970.00 645905.82 596L050.30 646400.00 648196.25 5962632.50 MHASURED IN(~N D~RECT/ON DBPT~ ANGLE AZIMUTH ummlmmml mmmmmm Q=~:~{mmm 8292.20 33.48 75.57 8295.~0 33.45 7~-58 SlO0,00 $~.40 $5.6L 8400,00 28.25 6L.L3 8500,00 25,15 42.23 PROPOSHD W~uL PROP~hH prepared ..... : 28 JuL 1997 Vert sect a=.: 56.42 KB elevation.: 72.14 i~ Magneh£c Dcln: ~28.353 (H) Scale Factor.: ~,999923L8 Convergence..: +1,08911861 TV/) SUB-SEA DEPART WEhLH~AD 7086.88 70~4.74 3133-83 102~.97 N 3083.04 7089,22 7017.08 3115.29 1022.B$ N 3084.~3 7093,39 $021.25 3L37.89 1023.04 N 3087,20 7179,35 ~107.21 3L87.58 104~,34 N 3134,69 7268.84 7196.70 323~.85 L068,~5 E 3~69,77 ANADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION' PLAN ' ALASKA Zone 4 T00I, X Y FACE 645905.82 5961050.~0 645907.3L 5961050.7~ 645909-96 5961055.45 645957.09 596L070.65 64599L.64 5961098.52 DL/ 100 164R <TIE ~64R L.0S 131L L.05 118L 9-00 LOLL 9.00 TOP KZNGAK E~D 9/~00 CU~V~ TOP SAG RIVER 8513.57 24,93 39.59 728l. L4 7209.00 3237,39 1072-90 8600,00 24.87 20.85 7~$9.65 7287.51 ~269,63 1104.01 87~0,00 27.50 1.25 7449.55 7377.4l 32~9.98 1146.83 87~1.54 27.56 0.98 $450.92 7378.78 33~0.39 11~7.54 9882.82 27.56 0,98 8498.14 8426,00 3610.40 1694.04 3173.52 E 645995.3L 5961102-94 99L 9,00 319L.58 E 646052,77 5961134.38 82L 9.00 3199.58 ~ 646059,96 596LL$7.3~ 64L 9.00 ]199.60 H 646019,96 596LL78.05 HS 9.00 3208.93 ~ 646018.91 S96L?2~,5~ HS 0.00 CARING POINT 9894.10 27.56 0.98 8508.14 6~36.00 26L3.36 L699,25 N 3209.02 B 6460L8.90 5961729.8L H8 0.00 (Anadrill (c) 97 HLTAD06 3.0C 4:19 D~ P) Z ~U 07/28/1997 15:46 907-3447~'~G0 ~N~DRI'LL DPO ~ . PAGE 04 mi SHARED SERVICES DRILLING ! H-17A (PC) VERTICAL SECTION VIEN 6o0 Sect ion at: 56.42 TVD Scale ' ~ inch : 1200 feet Dep Scale · ~ inch : 1200 feet t200 , Drawn · 28 Jul 1997 i ~oo 4nadrJ ]] Sch]umOerger L ! i i Marker Identification MD BKB SECTN INCLN 2~00 ' A) TIE-IN SURVEY 8292 7087 ~34 B) TOP OF WINDOW 8295 7089 3135 33.4~ C) KOP CURVE 9/100 8300 7093 3138 3000 .... D) END 9/100 CURVE 8702 745! 3300 27.56 E) 7' CASING POINT 989a 8508 3613 27.56 T F] CURVE 15/I00 10015 8615 3645 27.56 G) END ).5/100 CURVE 10227 8787 3751 46. V 3600 H) CURVE ~5/I00 ~0357 8877 38,43 ,46,~9 I) END 15/100 CURVE 10688 9002 4~37 89.18 D J) TARGET START ~*~* 10688 9002 4J37 89, 4200 .... K) CURVE 5/100 12081 9022 5464 89.18 L) END 5/100 CURVE t2'~19 9023 5500 88.79 M) 4-i/2" LINER POINT 12563 9032 5918 88.79 N) TD / TARGET END ~. 12563 9032 5918 88,79 ..... 4800 XN .. 5400 .... ~__i,. ;~,NADI ~ILL ..- AlIA-DP(' FE,~,F-,IR) I IT'~' PI ~,NI 6000 .... '~ NO" APPRO'¥ED FOR .-% FXFCI JTIC)N " · -~' '- ::~:-=:i =%-_7 7200 7800 Ol~ ~ ! - 8,400 .: 9600- 10200 10800 0 §00 1200 1BO0 2400 3000 3600 4200 4800 §400 6000 §600 7200 7BDD Section Departure m m m lc) 97 1(17N=05 .1.OC 4: ~ PI,I PI ! ..... -,' ,'"S'H","A.RED ~na#rill Schlumberger SERVICES i9 i i i i i i i i i ii i iiii i i i ii DRILLING __ i~ iii iii ii I i i H-17A (PC) ANADRILL AKA-DPC J VERTICAL SECTION VIEVl iii ii ii ilUlllll iiiiii i i ii i i FEASIBILITY PLAN Isectio~ ~t: ~,4~ '-- ' .... NO" APPI~O'V'ED FOR ITV~ Scale,: 'i inch:500 feet IOep Sca:le.: I inch: 500 feet E'____XECUT ION,Drawn ..... : 28 Jul 1997 2~. ......... .'~., .... ;.,..,~,_.._o,"'--~'. ..... .,.. ..... -"-~-'--,,,,-~o ~i · II I I I II I I iii nlml I II I I t-- ~' .................. 14apker Identification MD BKB SECIIt I~L A) TIE-TH SURVEY 8292 ?087 3134 33.z B) ¥OP DF HINDaH 82§5 7089 3)35 33,z ,,, C) KOP CURVE 9/100 8300 70g3 3138 33.z ~-.-- ,f~p'k h~'-?~3 D) END 91100 CURVE 8702 745! 3300 27,~. E) 7' CASING POINT §894 8508 36~3 27,.' k F] C~VE 15/~00 iOOf5 8615 3645 27. ~-,-~ . .... ,,, GJ END ~5/100 CURVE ~0227 8787 37§~ t,~ 'H) CURVE ]5/100 i0357 8877 3843 46, 1) END t5/~00 CURVE 10588 §002 4137 J) TARGET START ~()~)<x ~0688 §00~ 4337 89. ~ ........ K) CURVE 5/300 ~2OB~ ~22 5464 89.1 L) END 5/~00 C~VE ~211B 9023 5500 M) 4-3/2' LINER POINT 12563 9032 5938 BB. N) ID / TARGET END NN~, ~2563 9032 5BIB BB.~ .... ...... .... ;~ ......... ~: ..... ~~:~:~::::2::::2::~:::: ., ~ ~k ,r '~ ~ ................~ ~'~ ~ .... ~L~ ,* ' ' .... ..... , ,. 2800 3050 3300 3550 3800 4050 4300 4550 4830 5050 5300 5550 5800 6050 6300 6550 6800 7050 7300 Section Departure i ii i i iml i ! im · ii n ii i ! i m _ T ..... HAR'EB .... SERVICES DRI'LLING II · i_ I I I I II IIIII IIII I I I III iii iii! ii i Ii II I · i I II - I iii II I I I I . H-17A (P6) VERTICAL SECTION VIEW Section at: 56 42 I I ~-~' ' ' TVD Scale.: ! inch = tO0 feet J F ............. r~,~o~-~ Dep Scale.: ~ inch = lO0 feet ......... DPaun ..... : 28 Jul 1§97 ~~i I i I I Illl I i I II I , - , ..... Narker Identification MD 8KB SECTN INCLf "- ' A) 7' CASING POINl ~94 6508 36]3 27.~ r-t B] CURVE ~5/~00 100~5 ~5 36~5 27.~ __ ~ C) E~ ~5/t00 CURVE ~0227 6787 375~ 46.~! ' " D] CURVE ~5/~00 ~0~7 B677 ~43 46.1~ E] END 15/tO0 CURVE ~06~ 9002 4137 Bg. II ' .-. F1 TAMET STAR1 l,M~l,~ ~06BB 9002 4~37 89.11 G] CURVE 5/~00 iZOBi 9022 5464 ~.~1 ;:'. ~'~ % HI END 5/~00 CURVE ~2~19 9023 5500 86.7~ ': I) 4-1/2" LINER POINT 12563 9032 591~ BB.7~ . ., ' J) TD / fAR~T ENO ~.~ 12563 9032 5918 88.7~ _~ ~-~ ....... ,,;,. , .... ~ ,, ' '/~'NADP ILE' ' Al ;A-DP( ' FBNSIB LIT~/PL,~N -,~~.=, ............ ~NuAP~)RO~/eD --% EXE CUT ON ................... '~- ~ ................... . ............ : ...... ..: ....... ~; ,~, ~ Clnadri L ] lc) g? U 17~°m~ 3.OC 4:Z6 I~1 P) 3600 3650 3700 3750 3800 3850 3900 3950 4000 4050 4 ~.00 4 ~50 4200 4250 4300 4350 4400 4450 4500 Section Departure II i ii i I i i ii I i i i ii i ii iiii I i I I i i i Z i i iii i iii i i i i i ii i Anadri / J Schlumberger i iii · ii i i iii il i H- I 7A (P6) PLAN VIEW CLOSURE ' 5979 feel at Azimuth 64.65 DEgL 1 MATI ON,' +28.353 (E) SCALE ' 1 inch: 800 feet DRAWN ' 28 Jul 1997 SH'A qED .... 'SE'NV ICE'S"' iml ii _ i i i i i i i i i i i i i i J _ Nafkep Identitication MD !~/$ E/W A) lIE-IN Sb'RVEY 8292 ~022 N 3083 E 8) lOP OF WINDOW 8295 ~022 N 308§ E · C) KDP CURVE g/tO0 8300 1023 N 3067 E D) END 9/100 CURVE 8702 ~48 N 3200 E E} 7' CASING POINT 9894 ~699 N 3209 E FI CI~iVE 15/100 10015 1755 N 32t0 E Gl END 15/~00 CUR¥E ~02~7 1860 N 3267 E H) CUHVE t5/100 ~0357 1925 N 3335 E IJ END ~5/100 CURVE J06B~ 2062 N 3597 E J) TARGET STAR[ ,~)M lO6BB 2062 N 3597 E K) CURVE 5/300 J20B1 2443 N 4937 E L) END 5/100 CURVE 12119 2453 N 4973 E M) 4-t/2" LINER POINf 12563 2580 N 5403 E N) TO / TARGET ENO x~, ~2563 2560 N 5403 E DRILLIN~ i ..... ANADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOP., EXECUTION _ ._. ' ,' ...... -- ' '" -.---JL .~'. '.-'--- ...... ;.-, ~.___..~i;~----'~.: KB 400 0 400 BO0 1200 IBOO 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6BO0 <- WES]'' EAST -> z 3> Frl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re~Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 810' SNL, 1735' WEL, SEC. 21, T11N, R13E, UM At top of productive interval 298' NSL, 2394' EWL, SEC. 15, T11N, R13E, UM At effective depth 326' NSL, 2626' EWL, SEC. 15, T11N, R13E, UM At total depth 328' NSL, 2648' EWL, SEC. 15, T11N, R13E, UM 5. Type of well: [~ Development E] Exploratory I--I Stratigraphic I--]Service 6. Datum Elevation (DF or KB) KBE = 79.94 AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number H-17 9. Permit Number 82-190 10. APl Number 50-029-20862 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10901 feet true vertical 9317 feet Effective depth: measured 10821 feet true vertical 9237 feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) · DUPLICATE Fill at 10821' MD (07/88); Fish at 10818' MD (03/90) Size Cemented MD TVD 110' 20" x 30" 8 cu yds concrete 110' 110' 2667' 13-3/8" 3720 cu ft Permafrost II 2705' 2705' 9950' 9-5/8" 1426 cu ft 'G', 133 cu ft PF 'C' 9987' 8473' 7" 391 cu ft Class 'G' 9602' - 10894' 8163' - 9311' 886' 3-1/2" Scab Liner 9638' - 10524' Perforation depth: measured Aggregate Open lnterval: 10540'-10622' Aggregate Squeeze / Abandoned Interval: 10282' - 10540' true vertical Aggregate Open Interval: 8972' - 9050' Aggregate Squeeze / Abandoned Interval: 8733' - 8972' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 9561' with 4-1/2" tailpipe to'~i~' 0/'1~, ~, Packers and SSSV (type and measured depth) 9-5/8" BdT packer at 9561'; 5-1/2" SSSV Landing 13. Attachments [] Description summary of proposal BI Detailed operations program E} BOP sketch 4. Estimated date for commencing operation August 10, 1997 16. If proposal was verbally approved Name of approver Date approved Contact Engineer Name/Numben Winfon Aubert, 564-4825 15. Status of well classifications as: [] Oil E] Gas [] Suspended Service Prepared By Name/Number: 17. I hereby certify that tht?/f~going is~ect to the best of my knowledge Signed Dan Stoltz ,~¢~//~,~ ,,:,,4::r ~'*"~ Title Senior Drilling Engineer Terrie Hubble, 564-4628 Commission Use Only Approval: Notify Co~sion~ent. Cj.v-e4~ Conditions of Approved by order of the Commission~'-'~------~/'~\ Form 10-403 Rev. 06/15/88 witness I Approval No....~ ~ ¢-7' ~ on clearance quired 10- ~' ¢ '7 Commissioner Date ~::~/¢A~' Submit'In ~-ril~licate · WELL PERMIT CHECKLIST COMPAN'¢ FIELD & POOL ~.~ ,),_¢ ~ INIT CLASS GEOL AREA ~:'~/~.,'"~ U~IT# /"/,.~._~'" ~ ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13, Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... /Y\ N 15. Surface casing protects all known USDWs ........... ~y~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ N 18. CMT will cover all known productive horizons .......... N 19. Casing designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or reserve pit ................. (~ N 21. If a re-drill, has a 10-403 for abandonment been approved... ~ N 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... Y N 24, Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................ O N 26. BOPE press rating appropriate; test to ~O~O psig. ~ N 27. Choke manifold complies w/APl RP-53 (M~y 84) ........ ~ N 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... ~N ' YY N '"'/~--'¢¢if-/' ~ 31. Data presented on potential overpressure zones ....... i 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weeklypro~ress reports ..... .///Y N Y N [exploratory only] REMARKS GEOLOGY: ENGINEERING: COM~ ~I~SION' JDH ~ RNC Com m ents/Instru ctio ns: HOWIIjt - A:\FORMS\cheklist rev 07/97 _ .,~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * AI~SKA COMPUTING CENTER * ....... SCHLUIV~ERGER ....... COMPANY NAME : BP EXPLORATION WELL NAi~iE : H-17A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292086201 REFERENCE NO : 97464 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 **** REEL HEADER **** SERVICE NAME : EDIT DATE . 97/10/20 ORIGIN : FLIC REEL NAF~E : 97464 CONTINUATION # PREVIOUS REEL : COFk~ENT : B.P. EXPLORATION, H-17A, PRUDHOE BAY, API #50-029-20862-01 PAGE: **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/10/20 ORIGIN : FLIC TAPE NAf4~ : 97464 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : B.P. EXPLORATION, H-17A, PRUDHOE BAY, API #50-029-20862-01 TAPE HEADER Prudhoe Bay OPEN HOLE WIRELINE LOGS WELL NA~E : API ~ER : OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB ~ER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: RUN 1 97464 C. A . Yon D. Stearns WELL CASING RECORD 1ST STRING 2ND STRING H-17A 500292086201 BP Exploration SCHLUMBERGER WELL SERVICES 20-0CT-97 RUN 2 RUN 3 21 liN 13E 4470 1736 72.97 71.57 43.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 7.000 9953.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 3RDSTRING PRODUCTION STRING CONTAINED HEREIN IS THE DATA ACQUIRED ON 4-SEP-97 ON BP EXPLORATION WELL H-17A. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION ' O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 1 EDITED OPEN HOLEMAIN PASS Ail tOO1 strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INC~: 0.5000 FILE SUF~4ARY LDWG TOOL CODE AIT BCS SDN CNT $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 12420.0 9966.0 12379.0 9950.0 12408.0 9950.0 12395.0 9950.0 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: .......... EQUIVALENT UNSHIFTED DEPTH .......... AIT BCS SDN CNT RUN NO. PASS NO. ~IERGE TOP MERGE BASE THIS FILE CONTAINS THE CLIPPED AND EDITED DATA FOR THE ARRAY INDUCTION TOOL (AIT) , BOREHOLE COMPENSATED SONIC TOOL (BCS) , ANDPLATFORM EXPRESS LITHO-DENSITY (SDN) AND COMPENSATED NEUTRON (CNT) TOOLS. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL DATA. THE DATA IN THIS FILE WAS ACQUIRED ONLY OVER THE OPEN-HOLE SECTION OF THIS LOGGING RUN. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center LIS FORMAT DATA 20-0CT-1997 16:35 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 152 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~E 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 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 GR AIT GAPI 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 TENS AIT LB 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 TEND AIT LB 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 FIRES AIT OH~M1022516 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMAIT DEGF 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 DEV AIT DEG 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 FCNTCNT CPS 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNT CPS 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 NRATCNT 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNT PU-S 1022516 O0 000 O0 0 I 1 1 4 68 0000000000 DT BCS US/F 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 1022516 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN OPiMM1022516 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI. dlSS MODNUI~ SAMP ELI~Vl CODE (HEX) MINVSDN 0H~1022516 O0 000 O0 0 1 1 1 4 68 0000000000 ~4NORSDN OH~k~1022516 00 000 O0 0 1 1 1 4 68 0000000000 AOiO AIT 0P~4~1022516 O0 000 O0 0 1 1 1 4 68 0000000000 A020 AIT 0H~4~1022516 O0 000 O0 0 1 1 1 4 68 0000000000 A030 AIT 0P~4~1022516 O0 000 O0 0 1 1 1 4 68 0000000000 A060 AIT 0H~1022516 O0 000 O0 0 1 1 1 4 68 0000000000 A090 AIT 0H~1022516 O0 000 O0 0 1 1 1 4 68 0000000000 ATiO AIT 0P~4~1022516 O0 000 O0 0 1 1 1 4 68 0000000000 AT20 AIT 0P~4~1022516 O0 000 O0 0 1 1 1 4 68 0000000000 AT30 AIT 0H~1022516 O0 000 O0 0 1 1 1 4 68 0000000000 AT60 AIT 0H~4~1022516 O0 000 O0 0 1 1 1 4 68 0000000000 AT90 AIT OHMM1022516 O0 000 O0 0 1 1 1 4 68 0000000000 AFiO AIT OH~M1022516 O0 000 O0 0 1 1 1 4 68 0000000000 AF20 AIT 0H~9~1022516 O0 000 O0 0 1 1 1 4 68 0000000000 AF30 AIT OH~f1022516 O0 000 O0 0 1 1 1 4 68 0000000000 AF60 AIT OH~M1022516 O0 000 O0 0 1 1 1 4 68 0000000000 AF90 AIT OPiMM1022516 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA DEPT. 12430.000 GR.AIT -999.250 TENS.AIT 1294.000 TEND.AIT ~i~ES.AIT -999.250 MTE~.AIT -999.250 DEV. AIT -999.250 CNTC. CNT CFTC. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT -999.250 CRAT. CNT NRAT. CNT -999.250 NPHI.CNT -999.250 CPHI.CNT -999.250 DT. BCS CAL1.SDN -999.250 DRHO.SDN -999.250 PEF. SDN -999.250 RHOB.SDN MSFL.SDN -999.250 MINV. SDN -999.250 f~NOR.SDN -999.250 AOiO.AIT AO20.AIT -999.250 AO30.AIT -999.250 AO60.AIT -999.250 AO90.AIT ATiO.AIT -999.250 AT20.AIT -999.250 AT30.AIT -999.250 AT60.AIT AT90.AIT -999.250 AFiO.AIT -999.250 AF20.AIT -999.250 AF30.AIT AF60.AIT -999.250 AFgO.AIT -999.250 DEPT. ~!RE S . A I T CFTC. CNT NRA T . CNT CALl. SDN MSFL. SDN A020. AIT ATi O .AIT AT90. AIT AF60 .AIT 9950. 000 0 052 2922 139 1 734 7 551 0 101 -999 250 -999 250 -999 250 -999 250 GR.AIT 61.498 TENS.AIT MTE~I. AIT 193.027 DEV. AIT FCNT. CNT 2500.834 NCNT. CNT NPHI. CNT 14.175 CPHI.CNT DRHO.SDN 0.067 PEF.SDN MINV. SDN 0.075 ~NOR.SDN AO30.AIT -999.250 AO60.AIT AT20.AIT -999.250 AT30.AIT AFiO.AIT -999.250 AF20.AIT AFgO.AIT -999.250 981.000 TEND.AIT 28.653 CNTC. CNT 4243.233 CRAT. CNT 13 726 DT.BCS 3 904 RHOB.SDN 0 060 AOiO.AIT -999 250 AO90.AIT -999 250 AT60.AIT -999 250 AF30.AIT -668.873 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 263.088 4544.707 1.611 23.500 2.586 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE **** FILE TRAILER **** FILE NANi~ : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NANiE : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE H~ER FILE NI]ICi~ER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUNk4ARY LDWG TOOL CODE START DEPTH CNT 9950.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH .......... 9720.0 BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... CNT THIS FILE CONTAINS THE CLIPPED AND EDITED DATA FOR THE PLATFORM EXPRESS COMPENSATED NEUTRON TOOL (CNT) . NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL DATA. THIS DATA WAS ACQUIRED ONLY OVER THE CASED-HOLE SECTION OF THIS LOGGING RUN. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022516 O0 000 O0 0 2 1 1 4 68 0000000000 TENS AIT LB 1022516 O0 000 O0 0 2 1 1 4 68 0000000000 TEND AIT LB 1022516 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH AIT GAPI 1022516 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS 1022516 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS 1022516 O0 000 O0 0 2 1 1 4 68 0000000000 FCNTCNT CPS 1022516 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS 1022516 O0 000 O0 0 2 i 1 4 68 0000000000 CRAT CNT 1022516 O0 000 O0 0 2 1 1 4 68 0000000000 1FRAT CNT 1022516 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNT PU-S 1022516 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNT PU-S 1022516 O0 000 O0 0 2 1 1 4 68 0000000000 PAGE: ** DATA ** DEPT. 9950.000 TENS.AIT 981.000 TEND.AIT 263.088 GRCH.AIT CNTC. CNT 4544.707 CFTC. CNT 2922.139 FCNT. CNT 2500.834 NCNT. CNT CRAT. CNT 1.611 NRAT. CNT 1.734 NPHI.CNT 14.175 CPHI.CNT DEPT. 9720.000 TENS.AIT 243.000 TEND.AIT 323.052 GRCH.AIT CNTC. CNT 1423.878 CFTC. CArT 396.680 FCNT. CNT 355.191 NCNT. CNT CRAT. CNT 3.909 NRAT. CNT 4.123 NPHI.CNT 53.589 CPHI.CNT 61.498 4243.233 13.726 94.283 1391.370 45.924 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAF~E : EDIT .002 SERVICE . FLIC VERSION · O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE ~ER **** FILE NAME : EDIT .003 SERVICE . FLIC VERSION . O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUM~ER: TOOL STRING NUM~ER: PASS AU]M~ER: DEPTH INCREMENT: FILE SUM~zARY FILE HEADER FILE N73MBER 3 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 2 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 12432.0 9950.0 BHC 12432.0 9950.0 PEX 12432.0 9950.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TDDRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): 4-SEP-97 8C0-609 1000 2-SEP-97 300 4-SEP-97 12450.0 12430.0 9800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 12430.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. ~fEAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ TOOL NU~ER HILTB-DTB AIT-H BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 9953.0 9950.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATUN~ (DEGF) : 204.0 RESISTIVITY (OH~fl~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.141 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): 0.134 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 495 MUD CAKE AT (BHT)'. Quickdriln 8.80 74.0 75.0 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR TItERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 0.3 This log was depth referenced to a Sperry-Sun MWD GR log dated 03-Sep-1997. Platform Express and BHC run in combination, the Array Induction curves presented is merged from the down pass, the up pass version was not available due to tool failure. Three 0.5" standoffs used for BHC. Two 0.5" standoffs used for AIT. Two tool turners used to orient Densitypad and HGNT tool. Saline mud (29000mg/1) may affect shallow inducton curve (especially 10"). Deviation is 29 DEG @ casing shoot & 86 DEG @ TD. Casing was found to be at 9550". THIS IS THE RAW (OPEN-HOLE) MAIN PASS PEX/AIT/BHC DATA PRESENTED AT O. 5 ' SAMPLE RATE. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center LIS FORMAT DATA 20-0CT-1997 16:35 PAGE: 9 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 180 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 5 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAIVE SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 GR AIT GAPI 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 TENS AIT LB 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 HTENAIT LB 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 FIRES AIT OH~M1022516 O0 000 O0 0 3 1 1 4 68 0000000000 MTE~AIT DEGF 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 GDEVAIT DEG 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC PEX CPS 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC PEX CPS 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT PEX CPS 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 RClVTPEX CPS 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA PEX 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 RTArR PEX 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH PEX PU 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI PEX PU 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR PEX PU 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 DT BHC US~Fl022516 O0 000 O0 0 3 1 1 4 68 0000000000 TT1 BHC US 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 TT2 BHC US 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 TT3 BHC US 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 TT4 BHC US 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 10 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~B SAMP ELEM CODE (HEX) HCAL PEX IN 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 RHOZ PEX G/C3 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 HDRA PEX G/C3 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 PEFZ PEX 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 DPHZ PEX PU 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 H~IN PEX OH~ 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 H~NO PEX OH~$ 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 RXOZ PEX OP~4~ 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 RX08 PEX OH~4M1022516 O0 000 O0 0 3 1 1 4 68 0000000000 AOiO AIT OH~f~i022516 O0 000 O0 0 3 1 1 4 68 0000000000 A020 AIT 0H~4~1022516 O0 000 O0 0 3 1 1 4 68 0000000000 A030 AIT 0H~4~1022516 O0 000 O0 0 3 1 1 4 68 0000000000 A060 AIT OH~4M1022516 O0 000 O0 0 3 1 1 4 68 0000000000 AO9OAIT OH~4M1022516 O0 000 O0 0 3 1 1 4 68 0000000000 ATiO AIT 0H~4~1022516 O0 000 O0 0 3 1 1 4 68 0000000000 AT20 AIT 0H~4~1022516 O0 000 O0 0 3 1 1 4 68 0000000000 AT30 AIT 0H~4~1022516 O0 000 O0 0 3 1 1 4 68 0000000000 AT60 AIT 0H~1022516 O0 000 O0 0 3 1 1 4 68 0000000000 ATgO AIT 0H~4~1022516 O0 000 O0 0 3 1 1 4 68 0000000000 AFiO AIT OH~ 1022516 O0 000 O0 0 3 1 1 4 68 0000000000 AF20 AIT 0H~1022516 O0 000 O0 0 3 1 1 4 68 0000000000 AF30 AIT OH~M1022516 O0 000 O0 0 3 1 1 4 68 0000000000 AF60 AIT 0H~4~1022516 O0 000 O0 0 3 1 1 4 68 0000000000 AF90 AIT 0HM~$1022516 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. FiRES.AIT 0 045 MTE~f. AIT 210.939 GDEV. AIT -999 CFTC. PEX 2311 781 RCFT. PEX 1972.834 RCNT. PEX 3865 RTNR.PEX 1 945 TNPH. PEX 17.478 NPHI.PEX 17 DT. BHC 67 700 TT1.BHC 444.800 TT2.BHC 300 TT4.BHC 336 800 HCAL. PEX 7.182 RHOZ.PEX -999 PEFZ.PEX -999 250 DPHZ.PEX 60721.211 H~IN. PEX 70 RXOZ.PEX 4985.737 RXO8.PEX 4985.737 AOiO.AIT AO30.AIT 4.490 AO60.AIT 5.295 AO90.AIT AT20.AIT 3.701 AT30.AIT 4.540 AT60.AIT AFiO.AIT 3.570 AF20.AIT 3.706 AF30.AIT AF90.AIT 5.430 12432.000 GR.AIT 59.590 TENS.AIT 1294 000 HTEN. AIT -668.873 250 CNTC. PEX 4144.748 604 TNRA.PEX 1.807 437 NPOR.PEX 17.269 800 TT3.BHC 463.600 250 HDRA.PEX -999.250 954 H~VO. PEX 25.997 3.566 AO20.AIT 3.700 5.529 ATIO.AIT 3.565 5.373 AT90.AIT 5.416 4.573 AF60.AIT 5.296 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION . O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NABiE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUFiBER: PASS NUMBER: DEPTH INCREMENT: FILE SO?4MARY FILE HEADER FILE~ER 4 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 2 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 12432.0 9950.0 BHC 12432.0 9950.0 PEX 12432.0 9950.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TI) LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPH~) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 4-SEP-97 8C0-609 1000 2-SEP-97 300 4-SEP-97 12450.0 12430.0 9800.0 12430.0 1800.0 TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 AMS AUX. MEAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ AMS - A HILTB-DTB AIT-H BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 6.000 9953.0 9950.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 204.0 RESISTIVITY (Oh?4~) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): 0.141 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 134 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 495 MUD CAKE AT (BHT): Quickdriln 8.80 74.0 75.0 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): O. 3 REMARKS: This log was depth referenced to a Sperry-Sun MWD GR log dated 03-Sep-1997. Platform Express and BHC run in combination, the Array Induction curves presented is merged from the down pass, the up pass version was not available due to tool failure. Three 0.5" standoffs used for BHC. Two 0.5" standoffs used for AIT. Two tool turners used to orient Density pad and HGNT tool. Saline mud (29000mg/1) may affect shallow inducton curve (especially 10"). Deviation is 29 DEG @ casing shoot & 86 DEG @ TD. Casing was found to be at 9550" THIS IS THE RAW (OPEN-HOLE) MAIN PASS PEX/AIT/BHC DATA ACQUIRED AT 0.25' SAMPLE RATE. $ LIS FORMAT DATA PAGE: 12 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD~ SAMP ELE~ CODE (HEX) DEPT FT 1022516 O0 000 O0 0 4 1 1 4 68 0000000000 AOiO AIT 0P~$1022516 O0 000 O0 0 4 1 1 4 68 0000000000 A020 AIT OH~M1022516 O0 000 O0 0 4 1 1 4 68 0000000000 A030 AIT 0H~1022516 O0 000 O0 0 4 1 1 4 68 0000000000 A060 AIT OH~M1022516 O0 000 O0 0 4 1 1 4 68 0000000000 A090 AIT OH~f1022516 O0 000 O0 0 4 1 1 4 68 0000000000 ATiO AIT OP~W~1022516 O0 000 O0 0 4 1 1 4 68 0000000000 AT20 AIT OFfV~f1022516 O0 000 O0 0 4 1 1 4 68 0000000000 AT30 AIT 0H~$1022516 O0 000 O0 0 4 1 1 4 68 0000000000 AT60 AIT OPhir lO22516 O0 000 O0 0 4 1 1 4 68 0000000000 AT90 AIT 0P~4~1022516 O0 000 O0 0 4 1 1 4 68 0000000000 AFiO AIT 0~1022516 O0 000 O0 0 4 1 1 4 68 0000000000 AF20 AIT OH~M1022516 O0 000 O0 0 4 1 1 4 68 0000000000 AF30 AIT 0H~1022516 O0 000 O0 0 4 1 1 4 68 0000000000 AF60 AIT OH~M1022516 O0 000 O0 0 4 1 1 4 68 0000000000 AF90 AIT 0H~$1022516 00 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12432. 000 AOiO.AIT 3.566 AO20.AIT 3. 700 AO30.AIT A060. AIT 5. 295 A090. AIT 5. 529 AT10. AIT 3.565 AT20. AIT AT30 .AIT 4. 540 AT60.AIT 5. 373 AT90 .AIT 5. 416 AFIO .AIT AF20.AIT 3.706 AF30.AIT 4.573 AF60.AIT 5.296 AF90.AIT 4. 490 3. 701 3.570 5. 430 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 14 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION - O01CO1 DATE · 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NLC4~ER: TOOL STRING NUMBER: PASS NUM~ER: DEPTH INCREMENT: FILE SUF~/zARY FILE HEADER FILE NUAfBER 5 RAW OPE1VHOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 2 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 12432.0 9950.0 BHC 12432.0 9950.0 PEX 12432.0 9950.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : 4-SEP-97 8C0-609 1000 2-SEP-97 300 4-SEP-97 12450.0 12430.0 9800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 15 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): 12430.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ TOOL NUMBER AMS-A HILTB -DTB AIT-H BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 6.000 9953.0 9950.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 204.0 RESISTIVITY (OHI~M) AT TEMPERATURE (DEGF) : MUD AT IVlEASURED TEMPERATURE (MT): O. 141 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 134 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 495 MUD CAKE AT (BHT): Quickdriln 8.80 74.0 75.0 74.0 NEUTRON TOOL TOOL TYPE (EPITHE~ OR THERMAL) : THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): O. 3 This log was depth referenced to a Sperry-SunMWD GR log dated 03-Sep-1997. Platform Express and BHC run in combination, the Array Induction curves presented is merged from the down pass, the up pass version was not available due to tool failure. Three 0.5" standoffs used for BHC. Two 0.5" standoffs used for AIT. Two tool turners used to orient Density pad and HGNT tool. Saline mud (29000mg/1) may affect shallow inducton curve (especially 10"). Deviation is 29 DEG @ casing shoot & 86 DEG @ TD. Casing was found to be at 9550" THIS IS THE RAW (OPEN-HOLE) MAIN PASS PEX/AIT/BHC DATA ACQUIRED AT O. 1667 ' SAMPLE RATE. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 16 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 0.166 9 65 FT 1i 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 RHOZ PEX G/C3 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 HDRA PEX G/C3 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 PEFZ PEX 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 DPHZ PEX PU 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 HMIN PEX OH~M1022516 O0 000 O0 0 5 1 1 4 68 0000000000 HMNO PEX OHI4M1022516 O0 000 O0 0 5 1 1 4 68 0000000000 RXOZ PEX OH~M1022516 O0 000 O0 0 5 1 1 4 68 0000000000 RX08 PEX 0tff~1022516 O0 000 O0 0 5 1 1 4 68 0000000000 HCNT PEX CPS 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 HCFT PEX CPS 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 HGR PEX GAPI 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 RHFT PEX CPS 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 RHA~PEX CPS 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 HTNP PEX PU 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 PiNPOPEX PU 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 TT1 BHC US 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 TT2 BHC US 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 TT3 BHC US 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 TT4 BHC US 1022516 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE 17 ** DATA ** DEPT. 12432.000 RHOZ.PEX -999.250 HDRA.PEX -999.250 PEFZ.PEX DPHZ.PEX 60721.211 H~IN. PEX 70.954 H34NO. PEX 25.997 RXOZ.PEX RXO8.PEX 4985.737 HCNT. PEX 4144.749 HCFT. PEX 2311.781 HGR.PEX RHFT. PEX 1972.834 RHNT. PEX 3865.604 HTNP. PEX 17.478 HNPO. PEX TT1.BHC 444.800 TT2.BHC 300.800 TT3.BHC 463.600 TT4.BHC -999.250 4985.737 59.590 17.269 336.800 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 6 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN ND?4~ER : 1 TOOL STRING NUMBER: 1 PASS NUFIBER : 2 DEPTH INCREMENT: 0.0833 FILE SUMMARY VENDOR TOOL CODE START DEPTH AIT 12432.0 BHC 12432.0 PEX 12432.0 STOP DEPTH 9950.0 9950.0 9950.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 18 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION'. TIME CIRCULATION ENDED'. TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 4-SEP-97 8C0-609 1000 2-SEP-97 300 4-SEP-97 12450.0 12430.0 9800.0 12430.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ TOOL ~FUMBER AMS - A HILTB-DTB AIT-H BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 6.000 9953.0 9950.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 204.0 RESISTIVITY (Ot{~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 141 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 134 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 495 ~ CAKE AT (BHT): Quickdriln 8.80 74.0 75.0 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 0.3 REMARKS: This log was depth referenced to a Sperry-Sun MWD GR log dated 03-Sep-1997. Platform Express and BHC run in combination, the Array Induction curves presented is merged from the down pass, the up pass version was not available due to tool failure. Three 0.5" standoffs used for BHC. LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 19 Two 0.5" standoffs used for AIT. Two tool turners used to orient Density pad and HGNT tool. Saline mud (29000mg/1) may affect shallow inducton curve (especially 10"). Deviation is 29 DEG @ casing shoot & 86 DEG @ TD. Casing was found to be at 9550" THIS IS THE RAW (OPEN-HOLE) MAIN PASS PEX/AIT/BHC DATA ACQUIRED AT 0.0833' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 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 1022516 O0 000 O0 0 6 1 1 4 68 0000000000 HCAL PEX IN 1022516 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 12432.000 HCAL.PEX 7.182 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 2O ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUI~VARY FILE HEADER FILE NUMBER 7 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 12432.0 12802.0 BHC 12432.0 12802.0 PEX 12432.0 12802.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~!E CIRCULATION ENDED: TItlE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 4-SEP-97 8C0-609 1000 2-SEP-97 300 4-SEP-97 12450.0 12430.0 9800.0 12430.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 21 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~ff4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (I4T) : MUD CAKE AT (BHT) : TOOL NUMBER AMS - A HILTB-DTB AIT-H 6.000 9953.0 9950.0 Qui ckdri in 8.80 9.0 204.0 0.141 74.0 0.134 75.0 0.495 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 0.3 REMARKS: This log was depth referenced to a Sperry-Sun MWD GR log dated 03-Sep-1997. Platform Express and BHC run in combination, the Array Induction curves presented is merged from the down pass, the up pass version was not available due to tool failure. Three 0.5" standoffs used for BHC. Two 0.5" standoffs used for AIT. Two tool turners used to orient Density pad and HGNT tool. Saline mud (29000mg/1) may affect shallow inducton curve (especially 10"). Deviation is 29 DEG @ casing shoot & 86 DEG @ TD. Casing was found to be at 9550". THIS IS THE RAW (OPEN-HOLE) REPEAT PASS PEX/AIT/BHC DATA ACQUIRED AT 0.5' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 22 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 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 NUM~ SAMP ELEM CODE (HEX) DEPT FT 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 GR AIT GAPI 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 TENS AIT LB 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 HTENAIT LB 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 I~ES AIT 0H~4~1022516 O0 000 O0 0 7 1 1 4 68 0000000000 MTEMAIT DEGF 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 GDEVAIT DEG 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PEX CPS 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PEX CPS 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PEX CPS 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PEX CPS 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PEX 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PEX 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PEX PU 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PEX PU 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PEX PU 1022516 O0 000 O0 0 7 1 1 4 68 0000000000 DT BHC US/Fl022516 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 12433.500 GR. AIT ~I~ES.AIT O. 040 MTEM. AIT CFTC. PEX 1558.363 RCFT. PEX RTlCR . PEX 3.247 TNPH. PEX DT. BHC 67.900 DEPT. 12082.000 GR.AIT ~ES.AIT 0.049 MTEM. AIT CFTC. PEX 1784.615 RCFT. PEX RTNR.PEX 2.117 TNPH. PEX DT. BHC 91.100 20-0CT-1997 16:35 37.921 TENS.AIT 210.304 GDEV.AIT 1340.805 RCNT. PEX 37.223 NPHI.PEX 48.206 TENS.AIT 209.028 GDEV.AIT 1628.851 RCNT. PEX 22.464 NPHI.PEX 1044.000 HTEN. AIT -999.250 CNTC. PEX 4398.884 TNRA.PEX 37.702 NPOR.PEX 1382.000 HTEN. AIT 89.215 CNTC.PEX 3616.040 TNRA.PEX 22.749 NPOR.PEX PAGE: 23 -1141. 474 4720. 924 3. 016 36. 931 -478.107 3689.523 2.075 21.616 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION - O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01COi DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NU~4~ER: 1 PASS NUMBER: 1 DEPTH INC~: 0.2500 FILE SUAg~tRY VENDOR TOOL CODE START DEPTH AIT 12432.0 BHC 12432.0 PEX 12432.0 $ STOP DEPTH 12802.0 12802.0 12802.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 24 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOCKER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~ff~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): 4-SEP-97 8C0-609 1000 2-SEP-97 300 4-SEP-97 12450.0 12430.0 9800.0 12430.0 1800.0 TOOL NUMBER AMS - A HILTB -DTB AIT-H 6.000 9953.0 9950.0 Quickdriln 8.80 9.0 204.0 0.141 74.0 0.134 75.0 0.495 74.0 THERMAL SANDSTONE 2.65 0.3 This log was depth referenced to a Sperry-SunMWD GR log dated 03-Sep-1997. Platform Express and BHCrun in combination, the Array Induction curves presented is merged from the down pass, the up pass version was not available due to tool failure. Three 0.5" standoffs used for BHC. Two 0.5" standoffs used for AIT. LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 25 Two tool turners used to orient Density pad and HGNT tool. Saline mud (29000mg/1) may affect shallow inducton curve (especially 10"). Deviation is 29 DEG @ casing shoot & 86 DEG @ TD. Casing was found to be at 9550" THIS IS THE RAW (OPEN-HOLE) REPEAT PASS PEX/AIT/BHC DATA ACQUIRED AT 0.25' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NL¢~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022516 O0 000 O0 0 8 1 1 4 68 0000000000 AOIO AIT O HMM1022516 O0 000 O0 0 8 1 1 4 68 0000000000 A020 AIT 0I~4~f1022516 O0 000 O0 0 8 1 1 4 68 0000000000 A030 AIT 0H~1022516 O0 000 O0 0 8 1 1 4 68 0000000000 A060 AIT OH~M1022516 O0 000 O0 0 8 1 1 4 68 0000000000 A090 AIT 0Iff4~1022516 O0 000 O0 0 8 1 1 4 68 0000000000 ATIO AIT 0t~4M1022516 O0 000 O0 0 8 1 1 4 68 0000000000 AT2OAIT OH~M1022516 O0 000 O0 0 8 1 1 4 68 0000000000 AT30 AIT OHMM1022516 O0 000 O0 0 8 1 1 4 68 0000000000 AT60 AIT OH~M1022516 O0 000 O0 0 8 1 1 4 68 0000000000 AT90 AIT OPff4M1022516 O0 000 O0 0 8 1 1 4 68 0000000000 AFiO AIT OH~M1022516 O0 000 O0 0 8 1 1 4 68 0000000000 ur. uni pu~ '6ur.J~s Too~ 'ss~d ~m~a iog ~p iap~a[[ 5o~ prre saz~nD 6 H~WI1N T£8 ' £ ~96 ' E 8~ '~ OWE 'S · ~.IV'O6WV ~06'£ £IV'O9~rV 96E'5 £IV'OEa~V 916'E .r. IV'OUS~f £IV'Or~V ~sr'or £IV'O6£V ~£8 'ri £IV'O9£V s6z '~ £IV'OE£V ~IV'OE£V 88£'E £IV'Or£V 9~'£ £IV'O60V ~6£ '6 £IV'O90V ~I¥'OEOV /.rg'~ ~LIV'O~OV 6~8'E ~LIV'OrOV os~'~80~r '~LdHO 6IV'O6~V 8£E'S ~IV'Ogd-v 086'E £IV'OES~f r86'~ ~IV'OU~qf ~IV'Or~V 8sr's ~IV'O6£V 809's £IV'O9~V 668'E ~IV'OE~V ~IV'O~£V r6E'S ~IV'Or~V I6r'S ~IV'O60V 6ZS'S £IV'O90V ~IV'OfOV L£6'~ £IV'O~OV ~6f'S £iv'orov oo£'ff~ 0000000000 89 ~ r r 8 0 oo 000 oo 9rSWWO~AFz~IO ~I¥ 06~f 0000000000 89 ~ r r 8 0 oo 000 oo 9rs~EorI4~q-Io ~IV 09~qf 0000000000 89 ~ r r 8 0 oo 000 oo 9rs~6orw~o £iv o£~v 0000000000 89 ~ r r 8 0 oo 000 oo 9rS~OrAF~HO £IV 0~ (~H) HOOD ~ d~S ~ CON SS~D ~d~ ~ ~ H~O OI SS~DOHd Nd~ ~ZIS ~ ~ H~IS IdV I~ I~ I~ ~DIAH~S ~I~ AN~S ~N ....................................................................................... 9~ :~DVW sf:9r £66r-J~DO-OU 3~U~D fur.~ndu~oD ~3fs~rV J~squmrqmS 6ur.DsT~i uor. ~mr. gr.J~A od~,L SI~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 27 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.1667 FILE SUFff~ARY VENDOR TOOL CODE START DEPTH AIT 12432.0 BHC 12432.0 PEX 12432.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TItlE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 12802.0 12802.0 12802.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OBI~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: 4-SEP-97 8C0-609 1000 2-SEP-97 300 4-SEP-97 12450.0 12430.0 9800.0 12430.0 1800.0 TOOL NUMBER AMS -A HILTB -DTB AIT-H 6.000 9953.0 9950.0 Quickdriln 8.80 9.0 204.0 O. 141 74.0 O. 134 75.0 0.495 74.0 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 28 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 0.3 REMARKS: This log was depth referenced to a Sperry-Sun MWD GR log dated 03-Sep-1997. Platform Express and BHC run in combination, the Array Induction curves presented is merged from the down pass, the up pass version was not available due to tool failure. Three O. 5" standoffs used for BHC. Two 0.5" standoffs used for AIT. Two tool turners used to orient Density pad and HGNT tool. Saline mud (29000mg/1) may affect shallow inducton curve (especially 10") . Deviation is 29 DEG @ casing shoot & 86 DEG @ TD. Casing was found to be at 9550". THIS IS THE RAW (OPEN-HOLE) REPEAT PASS PEX/AIT/BHC DATA ACQUIRED AT 0.1667' SAMPLE RATE. $ 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 O. 166 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 29 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 RHOZ PEX G/C3 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 PiDRA PEX G/C3 1022516 O0 000 O0 0 9 I 1 4 68 0000000000 PEFZ PEX 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 DPHZ PEX PU 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 B~IN PEX OH~M1022516 O0 000 O0 0 9 1 1 4 68 0000000000 H~NO PEX OH~4M1022516 O0 000 O0 0 9 1 1 4 68 0000000000 RXOZ PEX 0H~4~1022516 O0 000 O0 0 9 1 1 4 68 0000000000 RX08 PEX OH~M1022516 O0 000 O0 0 9 1 1 4 68 0000000000 HCNT PEX CPS 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 HCFT PEX CPS 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 HGR PEX GAPI 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 RHFT PEX CPS 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 R3{NTPEX CPS 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 HTNP PEX PU 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 HNPO PEX PU 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 TT1 BHC US 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 TT2 BHC US 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 TT3 BHC US 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 TT4 BHC US 1022516 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 12433.500 RHOZ.PEX -999.250 HDRA.PEX -999.250 PEFZ.PEX DPHZ.PEX 60721.211 H~IN. PEX 29.147 H~NO. PEX 11.239 RXOZ.PEX RXO8.PEX 1509.701 HCNT. PEX 4720.923 HCFT. PEX 1558.363 HGR.PEX RHFT. PEX 1340.805 ~.PEX 4398.884 HTNP. PEX 37.223 HNPO. PEX TT1.BHC 446.400 TT2.BHC 300.400 TT3.BHC 465.600 TT4.BHC DEPT. 12082.334 RHOZ.PEX 2.374 P~RA.PEX 0.011 PEFZ.PEX DPHZ.PEX 16.706 HMIN. PEX 0.066 H~4NO. PEX 0.073 RXOZ.PEX RXO8.PEX 0.125 HCNT. PEX 3691.422 HCFT. PEX 1806.270 HGR.PEX RHFT. PEX 1625.000 RHN.PEX 3409.000 HTNP. PEX 22.772 HNPO.PEX TT1.BHC 583.200 TT2.BHC 391.938 TT3.BHC 580.400 TT4.BHC -999.250 1502.366 37.921 36.931 340.000 3. 704 O. 084 49.143 23. 638 391. 768 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 30 **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE . FLIC VERSION · O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUFiBER: PASS NUMBER: DEPTH INC~ : FILE SUM~J4RY FILE HEADER FILE ArUMBER 10 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 1 0.0833 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 12432.0 12802.0 BHC 12432.0 12802.0 PEX 12432.0 12802.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E CIRCULATION ENDED TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. SONDE PEX PLATFORM EXPRESS 4-SEP-97 8C0-609 1000 2-SEP-97 300 4-SEP-97 12450.0 12430.0 9800.0 12430.0 1800.0 TOOL NUMBER ........... AM$ - A HILTB-DTB LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: AIT $ ARRAY INDUCTION AIT-H BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 9953.0 9950.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 204.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT FiEASURED TEMPERATURE (MT): 0.141 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 134 MUD FILTRATE AT (BHT): MUD CAKE AT (MT): O. 495 MUD CAKE AT (BHT) : Quickdriln 8.80 74.0 75.0 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CO~CTION (IN): TOOL STANDOFF (IN): O. 3 REMARKS: This log was depth referenced to a Sperry-SunMWD GR log dated 03-Sep-1997. Platform Express and BHC run in combination, the Array Induction curves presented is merged from the down pass, the up pass version was not available due to tool failure. Three 0.5" standoffs used for BHC. Two 0.5" standoffs used for AIT. Two tool turners used to orient Density pad and HGNT tool. Saline mud (29000mg/1) may affect shallow inducton curve (especially 10"). Deviation is 29 DEG @ casing shoot & 86 DEG @ TD. Casing was found to be at 9550". THIS IS THE RAW (OPEN-HOLE) REPEAT PASS PEX/AIT/BHC DATA ACQUIRED AT 0.0833' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 32 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 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 1022516 O0 000 O0 0 10 1 1 4 68 0000000000 HCAL PEX IN 1022516 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 12433.500 HCAL.PEX 5.708 DEPT. 12082.000 HCAL.PEX 5.735 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE · FLIC VERSION · 0 O1 CO1 DATE - 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 33 **** FILE HEADER **** FILE NAM~ : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 11 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUFiBER : 2 DEPTH INCREMENT: 0.5000 FILE SUM~RY VENDOR TOOL CODE START DEPTH STOP DEPTH 9950.0 9662.0 PEX LOG HEADER DATA DATE LOGGED: 4-SEP-97 SOFTWARE VERSION: 8C0-609 TIFi~ CIRCULATION ENDED: 1000 2-SEP-97 TIFIE LOGGER ON BOTTOM: 300 4-SEP-97 TD DRILLER (FT) : 12450.0 TD LOGGER (FT): 12430.0 TOP LOG INTERVAL (FT) : 9800.0 BOTTOM LOG INTERVAL (FT) : 12430.0 LOGGING SPEED (FPPLR): 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. FLEAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ BORE~OLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): TOOL NUMBER AMS - A HILTB-DTB AIT-H 6.000 9953.0 9950.0 Qui ckdri in 8.80 9.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 34 MAXIMUM RECORDED TEMPERATURE (DEGF) : 204.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT k4~ASUREi) TEMPERATURE (MT): 0.141 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): 0.134 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 495 MUD CAKE AT (BHT) : 74.0 75.0 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. 3 REMARKS: This log was depth referenced to a Sperry-Sun MWD GR log dated 03-Sep-1997. Platform Express and BHC run in combination, the Array Induction curves presented is merged from the down pass, the up pass version was not available due to tool failure. Three 0.5" standoffs used for BHC. Two 0.5" standoffs used for AIT. Two tool turners used to orient Density pad and HGNT tool. Saline mud (29000mg/1) may affect shallow inducton curve (especially 10"). Deviation is 29 DEG @ casing shoot & 86 DEG @ TD. Casing was found to be at 9550" THIS IS THE RAW (CASED-HOLE) MAIN PASS PEX/AIT/BHC DATA ACQUIRED AT 0.5' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 35 TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAIVE 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 1022516 O0 000 O0 0 11 1 1 4 TENS AIT LB 1022516 O0 000 O0 0 11 1 1 4 HTENAIT LB 1022516 O0 000 O0 0 11 1 1 4 GR AIT GAPI 1022516 O0 000 O0 0 11 1 1 4 CNTC PEX CPS 1022516 O0 000 O0 0 11 1 1 4 CFTC PEX CPS 1022516 O0 000 O0 0 11 1 1 4 RCFT PEX CPS 1022516 O0 000 O0 0 11 1 1 4 RCNTPEX CPS 1022516 O0 000 O0 0 11 1 1 4 Tiv-RAPEX 1022516 O0 000 O0 0 11 1 1 4 RTNR PEX 1022516 O0 000 O0 0 11 1 1 4 NPOR PEX PU 1022516 O0 000 O0 0 11 1 1 4 NPHI PEX PU 1022516 O0 000 O0 0 11 1 1 4 TNPH PEX PU 1022516 O0 000 O0 0 11 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 9720.000 TENS.AIT 243.000 HTEN. AIT 323.052 GR.AIT CNTC.PEX 1423.878 CFTC. PEX 396.680 RCFT. PEX 355.191 RCNT. PEX TNRA.PEX 3.909 RTNR.PEX 4.123 NPOR.PEX 43.225 NPHI.PEX TNPH. PEX 45.924 DEPT. 9662.500 TENS.AIT 274.000 HTEN. AIT 265.280 GR.AIT CNTC. PEX 1402.829 CFTC.PEX 402.072 RCFT. PEX 313.240 RCNT. PEX TNRA.PEX 3.645 RTNR.PEX 4.554 NPOR.PEX 41.030 NPHI.PEX TNPH. PEX 44.328 94.283 1391.370 53.589 87.089 1182.845 48.740 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 36 **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 12 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 2 DEPTH INC~: 0.1667 FILE SUFk~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9950.0 9662.0 PEX LOG HEADER DATA DA TE LOGGED: 4 - SEP - 97 SOFTWARE VERSION: 8C0- 609 TIBIE CIRCULATION ENDED: 1000 2-SEP-97 TIIViE LOGGER ON BOTTOM: 300 4-SEP-97 TD DRILLER (FT) : 12450.0 TI) L~ER (FT) : 12430.0 TOP LOG INTERVAL (FT) : 9800.0 BOTTOM LOG INTERVAL (FT) : 12430.0 LOGGING SPEED (FPHR) : 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER AMS AUX. M~AS. SONDE AMS-A PEX PLATFORM EXPRESS HILTB-DTB AIT ARRAY INDUCTION AIT-H $ BOREHOLE AND CASING DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 9953.0 9950.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED T~4PERATURE (DEGF) : 204.0 RESISTIVITY (OH~ff4) AT TE~IPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (14T) : 0.141 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 134 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 495 MUD CAKE AT (BHT) : Quickdriln 8.80 74.0 75.0 74.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) .. THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. 3 RE~IARJfS: This log was depth referenced to a Sperry-Sun MWD GR log dated 03-Sep-1997. Platform Express and BHC run in combination, the Array Induction curves presented is merged from the down pass, the up pass version was not available due to tool failure. Three 0.5" standoffs used for BHC. Two 0.5" standoffs used for AIT. Two tool turners used to orient Density pad and HGNT tool. Saline mud (29000mg/1) may affect shallow inducton curve (especially 10"). Deviation is 29 DEG ® casing shoot & 86 DEG @ TD. Casing was found to be at 9550". THIS IS THE RAW (CASED-HOLE) MAIN PASS PEX/AIT/BHC DATA ACQUIRED AT 0.1667' SAMPLE RATE. $ LIS FORMAT DATA PAGE: 37 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1997 16:35 PAGE: 38 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 32 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 1022516 O0 000 O0 0 12 1 1 4 68 0000000000 HCNT PEX CPS 1022516 O0 000 O0 0 12 1 1 4 68 0000000000 HCFT PEX CPS 1022516 O0 000 O0 0 12 1 1 4 68 0000000000 HGR PEX GAPI 1022516 O0 000 O0 0 12 1 1 4 68 0000000000 RHFT PEX CPS 1022516 O0 000 O0 0 12 1 1 4 68 0000000000 Rt{NT PEX CPS 1022516 O0 000 O0 0 12 1 1 4 68 0000000000 HTNP PEX PU 1022516 O0 000 O0 0 12 1 1 4 68 0000000000 PiNPO PEX PU 1022516 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 9720.000 HCNT. PEX 1421.848 HCFT. PEX 394.056 HGR.PEX RHFT. PEX 373.257 Rt{NT. PEX 1524.112 HTNP. PEX 46.121 HNPO.PEX DEPT. 9662.834 HCNT. PEX 1387.847 HCFT.PEX 408.889 HGR.PEX RHFT. PEX 291.081 RPiNT. PEX 1192.580 HTNP. PEX 42.938 HNPO.PEX 98.462 39.066 81.404 40.867 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 97/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE .. 20-0CT-1997 16:35 PAGE: 39 **** TAPE TRAILER **** SERVICE NAYiE : EDIT DATE : 97/10/20 ORIGIN · FLIC TAPE NAME : 97464 CONTINUATION # : 1 PREVIOUS TAPE : COI~VT : B.P. EXPLORATION, H-17A, PRUDHOE BAY, API #$0-029-20862-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/10/20 ORIGIN : FLIC REEL NAME : 97464 CONTINUATION # : PREVIOUS REEL : CO~-~VT : B.P. EXPLORATION, H-17A, PRUDHOE BAY, API #50-029-20862-01 Sperry-Sun Drilling Services LIS Scan Utility Tue Oct 14 09:49:08 1997 Reel Header Service name ............. LISTPE Date ..................... 97/10/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ...... ~ ...... LISTPE Date ..................... 97/10/14 Origin ................... STS Tape Name ................ UNKNO?~ Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY MWD/MAD LOGS WELL NAME: API NUMBER: . OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Date ...i/,-~/(', J RECEIVi:U OCT 22 199,-)~, Oil & G~ go~s. ~ ~0m~ H-17A 500292086201 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 14-OCT-97 MWD RUN 1 AK-MW-70241 MEL GABEL CHARLEY DIXO MWD RUN 2 AK-MW-70241 MEL GABEL CHARLEY DIXO MWD RUN 3 AK-MW-70241 MEL GABEL CHARLEY DIXO JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-70241 RAY FRENCH CHARLEY DIXO MWD RUN 5 AK-MW-70241 RAY FRENCH CHARLEY DIXO MWD RUN 6 AK-MW-70241 RAY FRENCH CHARLEY DIXO JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MWD RUN 7 AK-MW-70241 RAY FRENCH CHARLEY DIXO MWD RUN 8 AK-MW-70241 RAY FRENCH CHARLEY DIXO MWD RUN 9 AK-MW-70241 RAY FRENCH CHARLEY DIXO SECTION: TOWNSHIP: RA/~GE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 21 liN 13E 810 1735 73.00 71.60 43.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8140.0 8.500 7.000 9953.0 6.000 12450.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 7 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTOR. '3. MWD RUNS 8 AND 9 ARE DIRECTIONAL WITH WITH DUAL GAM~U% RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE4 (EWR4). 4. A CHANGE FROM SCINTILLATION DETECTOR (NSF) TO GEIGER-MUELLER TUBE DETECTORS (DGR) OCCURED AT 10684'MD, 9007'TVD. 5. MWD RUNS 1 THROUGH 9 REPRESENT WELL H-17A WITH API#: 50-029-20862-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12450'MD, 9039'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM S FAC INS ) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ........... ~ .... LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ START DEPTH 8287.5 8287.5 10686.5 10686.5 10686.5 10686.5 10686.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 8287 5 9722 9725 9729 9741 9745 9746 9749 9755 9758 9797 9800 9802 9806 9811 9820 9822 9831.0 9887.0 9889 0 9892 5 9904 0 9906 5 9909 0 9910 0 9913 0 9915 0 9938 5 9944 5 9946 5 9947 5 9949 5 9952 5 9955 0 9962 0 9968 5 9970 0 9971 5 GR 8290.0 9725.0 9728.0 9731.5 9743.0 9748.0 9751.5 9754.0 9758.0 9761.0 9796.0 9798.5 9800.5 9810.5 9815.5 9822.5 9825.0 9833.5 9888.0 9889.5 9894.5 9907.5 9911.0 9913.5 9915 0 9919 0 9921 5 9945 5 9951 0 9953 0 9954 5 9956 5 9959 0 9960 5 9969 0 9974 5 9975 5 9977 0 STOP DEPTH 12406 5 12448 5 12413 5 12413 5 12413 5 12413 5 12413 5 EQUIVALENT UNSHIFTED DEPTH -- 0 ££~0~ S gggO~ 0 g~gO~ ~ ~£0~ 0 60gO~ ~ ~£~0~ ~ 69~0~ 0 L9~OZ ~ 99EOI 9 ~9~0I 0 £9~0I ~ 9~0I 0 ~£~0I 0 6I~OI 0 60~0I 9'66IOI 0'£6IOI O'~6IOI ~'~6IOI 0 06IOI ~ 98IOI § ~SIOI 0 9~IOI 0 ~IOI 9 ~IOI 0 E~IOI ~ O~IOI 0'6£IOI O'EEIOI § '9800I 0'£900I 9'~900I 9'E900I 0'£900I § I900I 0 09001 0 ~OOI g ~OOI ~ ~OOI 0 6EOOI ~ 9~00I 0 9 E~OOI 00~OOI 0 6~00I § 9~00I 0 ~OOI § O~OOI § 8IOOI 0 9IOOI 0 ~IOOI 0 IIOOI 0 9000I 0 £666 0 0666 0'6866 0'£866 9'£866 0'6£66 I£COI IUCOI OICOI 60COI LOCOI OLEOI L9EOI 99EOI 99EOI E9EOI I9EOI IgEOI £~0I ~£~0I EI~OI ~O~OI £6IOI 96IOI ~6IOI 06IOI 98IOI SSIOI 08IOI ~gIOI IglOI 6~IOI 6~IOI £EIOI ~£IOI 9~IOI '0800I '99001 '~900I 'IgOOI '09001 '£qOOI ~OOI ¥~00I I~OOI £EOOI ~EOOI IEOOI £~00I 9~00I ~¥00I ~OOI £I00I ~IOOI EIOOI OIOOI 6000I 8000I O000I 8866 9866 9866 g866 9£66 E£66 10417 10427 10430 10433 10446 10464 10465 10467 10472 10475 10477 10479 10479 10482 10484 10485 10487 10490 10492 10495 10496 10574 10582 10602 10603 10606 10627 10631 10633 10634 10654 10658 10661 10665 10669 10671 10679. 10680. 10681. 10687. 10809. 10810. 10817 10821 10824 10869 10871 10874 10884 10889. 10895 10898 10898 10932 11088 11090 11093 11234 11237 11243 5 5 5 0 5 0 5 0 5 0 0 0 5 0 0 5 5 0 5 0 0 5 0 5 5 0 5 0 0 0 5 5 0 5 0 0 0 0 5 0 0 5 0 0 5 5 5 0 0 0 0 0 5 5 0 0 0 5 0 0 10423.0 10431.5 10435.0 10437.5 10451.5 10468.0 10470.0 10471.5 10476.5 10479.5 10481 0 10483 0 10484 5 10486 5 10488 5 10489 0 10490 5 10494 5 10496.0 10498.5 10500.5 10579.0 10583.0 10605 5 10608 0 10608 5 10626 5 10632 0 10636 0 10637 5 10654 5 10656 0 10658.5 10661.5 10665.5 10667.0 10671 5 10672 5 10674 0 10681 0 10813 0 10816 0 10823 0 10826 0 10828 5 10874 5 10879 5 10883 0 10891 0 10896 5 10901 5 10904 0 10905 0 10936 5 11092 5 11096 5 11099 0 11238 5 11241 5 11245 5 0 ZL£Z~ § OLCZ~ ~ 89C[~ 0 0 ~OC~ ~ ~9g~ 0 6~g~ S'T~TYT S ~ST~T 0 £ST~T S SST~T 00~T~T S ~T~T S ~T~T 0 ~6TT S ~T6TT 0'2T6TT 0'806TT O'O06TT 0 T68TT S ~88TT 0 088TT 0 8£8TT S O~STT § 928TT S'T28TT O'T££TT O'£S£TT 0'289TT S'089TT 0 8£9TT S 9£9TT 0 ~SgTT 0 TSgTT 0 S~gTT S 6£9TT 0 S~gTT S 2~gTT S ~29TT 0 STgTT S'£09TT S ~09TT S 68§TT 0 T2STT S 8TSTT 0 9TSTT 0 ~TSTT S TTSTT S'~OSTT 0 £OSTT S OOSTT S £T~TT 0 66~ZT 0 L62TT S ~82TT S 2£2TT 0 Tg~TT 0 8S2TT g £LC~I g ~L£~I 0 69£~T 0 09£~l 0 OOC~l 0 g9~l S 6S~l 0 ~S77T S T9TUT S 8SLUT S £ST~T 0 9STZT S 8£TYT 0 SCTZT 0 SZTZl S OZ6TT 00T6TT S £06TT S 906TT 0 668TT 0 068TT S 088lT S 8£8TT 0 9£8TT 0 6CSTT S TZSTT S £TSTT 0 T££TT 9S£TT 089TT ££9TT ~£9lT C£gTT TSgTT 8~gTT C~gTT ££9TT C£gTT zCgTT ZZgTT TTgTT S09TT O09TT S@STI 6TSTT STSTT ~ISTI 60STI fOSTT OOSTT 86~lT S6~TI STCTT §6~TT £6ZTT 8£ZTT £gZTT 8SZTT CSZTT 12377.5 12374.5 12384.5 12379.0 12388 . 0 12386.0 12393.0 12394.5 12448 . 5 12450.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE MWD 1 8060 MWD 2 9416 MWD 3 9810 MWD 4 10079 MWD 5 10412 MWD 6 10644 I~WD 7 10665 MWD 8 10721 MWD 9 11813 $ RENLARKS: MERGED MAIN PASS. $ TOP 0 0 0 0 0 0 0 0 0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 9416.0 9953.0 10079 0 10412 0 10644 0 10665 0 10721 0 11813 0 12450.0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD FT/H 4 1 GR MWD AAPI 4 1 RPX MWD OHMM 4 1 RPS MWD OHM~ 4 1 RPM MWD OHMH 4 1 RPD MWD OHMM 4 1 FET MWD HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 ' 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean Nsam DEPT 8287.5 12448.5 10368 8323 ROP 1.4694 2119.92 64.2642 8323 GR 14.7129 620.909 63.9706 8239 RPX 1.9408 21.5872 7.77167 3455 RPS 2.3957 23.9249 9.34312 3455 RPM 2.661 23.4285 9.80451 3455 RPD 3.3712 23.915 10.6251 3457 FET 0.3704 22.6224 1.66268 3455 First Reading 8287 5 8287 5 8287 5 10686 5 10686 5 10686 5 10685 5 10686 5 Last Reading 12448 5 12448 5 12406 5 12413 5 12413 5 12413 5 12413 5 12413 5 First Reading For Entire File .......... 8287.5 Last Reading For Entire File ........... 12448.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8290.0 9351.5 ROP 8290.0 9417.5 $ # - LOG HEADER DATA DATE LOGGED: 23-AUG-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: /SP4 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9416.0 TOP LOG INTERVAL (FT) : 8060.0 BOTTOM LOG INTERVAL (FT) : 9416.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 25.3 MAXIMUM ANGLE: 39.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE ~qD CASING DATA ISC 5.06 / MSC 1.32 DEP 2.042 / NGP 5.74 TOOL NUMBER NGP 53 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS M-gD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES {PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 8.500 8.5 KCI k POLYMER 10.00 60.0 8.9 29000 5.0 .000 .000 .000 .000 .0 61.0 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8290 9417.5 8853.75 2256 8290 GR 37.866 210.302 90.1756 2124 8290 ROP 1.4694 234.346 50.0779 2256 8290 Last Reading 9417.5 9351.5 9417.5 First Reading For Entire File .......... 8290 Last Reading For Entire File ........... 9417.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW lV~TD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUN94ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9352.0 9878.5 ROP 9417.5 9953.0 $ LOG HEADER DATA DATE LOGGED: 24-AUG-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: /SP4 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9953.0 TOP LOG INTERVAL (FT) : 9416.0 BOTTOM LOG INTERVAL (FT) : 9953.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 29.2 lvuXXIMUMANGLE: 31.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): ISC 5.06 / MSC 1.32 DEP 2.042 / NGP 5.74 TOOL NUMBER NGP 317 8.500 8.5 KCLkPOL~ER 10.00 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 66.0 9.0 29000 5.0 .000 .000 .000 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9352 9953 9652.5 1203 9352 GR 62.6773 132.239 102.692 1054 9352 ROP 14.707 167.791 43.9683 1072 9417.5 61.0 Last Reading 9953 9878.5 9953 First Reading For Entire File .......... 9352 Last Reading For Entire File ........... 9953 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUM~RY VENDOR TOOL CODE START DEPTH GR 9879.0 ROP 9953.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: /SP4 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10015.5 10079.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GA/v~L~ PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY {OHMIC) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 27-AUG- 97 ISC 5.06 / MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10079.0 9810.0 10079.0 27.8 30.9 TOOL NUMBER NGP 317 6,000 6.0 QUICKDRIL-N 8.70 62.0 9.0 29000 6.0 .000 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 61.0 First Name Min Max Mean Nsam Reading DEPT 9879 10079 9979 401 9879 GR 42.2725 620.909 120.523 274 9879 ROP 9.2131 160.711 55.8046 25~ ' 9953.5 Last Reading 10079 10015.5 10079 First Reading For Entire File .......... 9879 Last Reading For Entire File ........... 10079 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10018.0 ROP 10080.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: /SP4 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: I~AXIMUMANGLE: STOP DEPTH 10348.0 10411.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT M3%X CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 28-AUG-97 ISC 5.06 / MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10412.0 10079.0 10412.0 30.9 50.5 TOOL NUMBER · NGP 53 6.000 6.0 QUICKDRIL-N 8.80 43.0 9.0 29000 6.0 .000 .000 .000 .000 105.0 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10018 10411.5 10214.8 788 10018 GR 18.5365 338.831 42.1545 661 10018 ROP 13.7013 2119.92 95.0727 664 10080 Last Reading 10411.5 10348 10411.5 First Reading For Entire File .......... 10018 Last Reading For Entire File ........... 10411.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10350.0 ROP 10413.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: /SP4 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM _ANGLE: STOP DEPTH 10580.0 10644.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS I~UD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: I¢~ATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 29-AUG-97 ISC 5.06 / MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10644.0 10412.0 10644.0 47.9 67.5 TOOL NUMBER NGP 53 6.000 6.0 QUICKDRIL-N 8.80 43.0 9.0 29000 6.0 .000 .000 .000 .000 133.0 .0 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10350.5 10644 10497.2 588 10350.5 GR 18.0548 120.643 29.3747 460 10350.5 ROP 19.1998 253.083 94.0836 463 10413 Last Reading 10644 10580 10644 First Reading For Entire File .......... 10350.5 Last Reading For Entire File ........... 10644 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10580.5 ROP 10644.5 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: /SP4 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM _ANGLE: STOP DEPTH 10624.0 10665.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OH/V/~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 30-AUG-97 ISC 5.06 / MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10665.0 10644.0 10665.0 70.3 72.7 TOOL NUMBER NGP SPC 317 6.000 6.0 QUICKDRIL-N 8.80 48.0 8.1 · 29000 7.0 .000 .000 .000 .000 60.9 .0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 GR I~WD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10580.5 10665 10622.8 170 10580.5 GR 25.0234 67.2968 33.6107 88 10580.5 ROP 22.2513 105.637 53.901 42 10644.5 Last Reading 10665 10624 10665 First Reading For Entire File .......... 10580.5 Last Reading For Entire File ........... 10665 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW ~D Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUI~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10624.5 10675.5 ROP 10665.5 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: /SP4 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 10721.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 30-AUG-97 ISC 5.06 / MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10721.0 10665.0 10721.0 72.5 84.0 TOOL NUMBER NGP SPC 317 6.000 6.0 QUICKDRIL-N 8.80 51.0 9.0 29000 .0 .000 .000 .000 .000 53.9 .0 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR M?TD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10624.5 10721 10672.8 194 10624.5 GR 25.0497 106.437 53.0213 103 10624.5 ROP 4.1829 93.2261 36.8747 112 10665.5 Last Reading 10721 10675.5 10721 First Reading For Entire File .......... 10624.5 Last Reading For Entire File ........... 10721 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP 10676 0 10680 5 10680 5 10680 5 10680 5 10680 5 10721 5 STOP DEPTH 11776.0 11782 5 11782 5 11782 5 11782 5 11782 5 11813 5 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: /SP4 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: lq]kXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 01-SEP-97 ISC 5.06 / MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 11813.0 10721.0 11813.0 87.9 92.7 TOOL NUMBER P0694SP4 P0694SP4 6.000 6.0 QUICKDRIL-N 8.80 51.0 9.0 29000 6.5 .190 .105 .120 ' 2.500 150.0 .0 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 RPX MWD 8 OHMM 4 1 68 8 3 RPS MWD 8 OHMM 4 1 68 12 4 RPM I~WD 8 OHMS4 4 1 68 16 5 RPD MWD 8 OHMM 4 1 68 20 6 ROP MWD 8 FT/H 4 1 68 24 7 FET ~,~D 8 HOUR 4 1 68 28 8 Name Min Max Mean Nsam DEPT 10676 11813.5 11244.8 2276 GR 14.7129 116.395 38.3125 2201 RPX 1.9408 21.5872 8.74692 2205 RPS 2.3957 23.9249 10.74 2205 RPM 2.661 23.4285 11.4268 2205 RPD 3.4977 23.915 12.566 2205 ROP 13.0814 268.694 70.342 2185 FET 0.3704 15.8113 1.34585 2205 First Reading 10676 10676 10680 5 10680 5 10680 5 10680 5 10721 5 10680 5 Last Reading 11813.5 11776 11782.5 11782.5 11782.5 11782.5 11813.5 11782.5 First Reading For Entire File .......... 10676 Last Reading For Entire File ........... 11813.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE S UlV94ARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG H~ADER DATA DATE LOGGED: SOFTWARE 11776 5 11783 0 11783 0 11783 0 11783 0 11783 0 11815 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: /SP4 5.03 DATA TYPE (MEMORY OR REAL-TIME TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIIVfUM ~GLE: STOP DEPTH 12408.0 12415.0 12415.0 12415.0 12415.0 12415.0 12450.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REI~ARKS: 03-SEP-97 ISC 5.06 / MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 12450.0 11813.0 12450.0 84.7 90.8 TOOL NUMBER P0694SP4 P0694SP4 6.000 6.0 · QUICKDRIL-N 8.80 50.0 8.7 29000 6.5 .170 .089 .100 2.300 158.6 .0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 9 AAPI 4 1 68 RPX MWD 9 OHMM 4 1 68 RPS MWD 9 OHMM 4 1 68 RPM MWD 9 OHMM 4 1 68 RPD MWD 9 OHMM 4 1 68 ROP ~D 9 FT/H 4 1 68 FET I~D 9 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 11776.5 21 4353 2 1072 2 4373 2 9323 3 0867 7 2722 0 5257 Max Mean Nsam 12450 12113.2 1348 92.3646 45.0669 1264 13.2432 6.05905 1265 14.4523 6.90389 1265 14.158 6.97871 1265 14.197 7.25269 1265 377.578 72.3518 1271 22.6224 2.36173 1265 First Reading 11776.5 11776.5 11783 11783 11783 11783 11815 11783 Last Reading 12450 12408 12415 12415 12415 12415 12450 12415 First Reading For Entire File .......... 11776.5 Last Reading For Entire File ........... 12450 , File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/10/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/10/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Physical EOF End Of LIS File