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197-078
STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT D-01A JBR 05/14/2025 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:1 The check valve going to the 3" COMBI Rams was leaking (changed out) and passed retest. Precharge Bottles = 1@900psi, 1@950psi and 6@1000psi. Test Results TEST DATA Rig Rep:M. MadsonOperator:Hilcorp North Slope, LLC Operator Rep:M. Igtanloc Rig Owner/Rig No.:Nabors CDR3AC PTD#:1970780 DATE:4/28/2025 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopBDB250429140140 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6 MASP: 2447 Sundry No: 324-702 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 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2"P Annular Preventer 1 7 1/16"P #1 Rams 1 blind/shear P #2 Rams 1 2"P #3 Rams 1 2 3/8 P #4 Rams 1 2"P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"P HCR Valves 2 2 1/16"P Kill Line Valves 1 2 1/16"P Check Valve 0 NA BOP Misc 2 2"P System Pressure P3050 Pressure After Closure P2225 200 PSI Attained P27 Full Pressure Attained P63 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P4@2000 ACC Misc FP1 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 1 P Annular Preventer P12 #1 Rams P13 #2 Rams P3 #3 Rams P3 #4 Rams P1 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9 9999 9 9 check valve going to the 3" COMBI Rams was leaking ACC Misc FP By Grace Christianson at 9:28 am, Dec 17, 2024 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2024.12.16 17:23:21 - 09'00' Sean McLaughlin (4311) 324-702 SFD *The D-01A wellbore beneath the whipstock will not be isolated until the liner for D-01B is cemented. That portion of D-01A will be considered open and retain the status of "Oil" until it is permanently isolated. SFD *BOPE test to 3500 psi. * Per AOGCC regulation 20 AAC 25.112 (i) A variance is approved for abandonment of parent well D-01A with a fully cemented liner on the upcoming sidetrack and the ability to place a reservoir abandonment plug across all annuli at the base of the PBU oil pool confining zones. 10-407 MGR30DEC24 December 26, 2024 * This is a plug for redrill. mgr SFD SFD 12/17/2024 DSR-12/18/24MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.31 09:39:06 -09'00'12/31/24 RBDMS JSB 010925 Casing Length Size Burst Collapse INTERMEDIATE 9277 9-5/8" x 7" 23 - 9300 23 - 8567 6870/7240 4760/5410 LINER 1530 4-1/2" 9138 - 10668 8425 - 9071 8430 7500 LINER 1195 3-1/2" x 3-1/4" 9002 - 9154 8305 - 8439 10160 10540 MD TVD Casing / Tubing Attachment PBU D-01A To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: December 16, 2024 Re:D-01A Sundry Request Sundry approval is requested to set a whipstock and mill a window in the D-01A wellbore as part of the drilling and completion of the proposed D-01B CTD lateral. Proposed plan: Prior to drilling activities, slickline will DMY GLVs, Pull the 3-1/4" R NIP and plug, and drift for whipstock. E-line will set a 3-1/2" whipstock. If unable to set the whipstock, the rig will perform that work. 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 3-1/4" whipstock. A single string 2.74" window + 10' of formation will be milled. The well will kick off drilling in the Shublik and land in Ivishak Zone 2. The lateral will continue in Zone 4, 3 and 2 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will isolate and abandon the parent Prudhoe Pool perfs. This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in 12/29/24) x Reference D-01A Sundry submitted in concert with this request for full details. 1. Slickline : Pull Monopak packer/plug, drift for whipstock 2. E-Line : Set 3-1/4" whipstock @ 9,360' MD & orient @ 0 ROHS 3. Valve Shop : Pre-CTD Tree Work 4. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in February 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,447 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 2.74” Window (3-1/4" x 4-1/2" dual string exit) 3. Drill build section: 3.25" OH, ~390' (30 deg DLS planned). 4. Drill production lateral: 3.25" OH, ~2092' (12 deg DLS planned). Swap to KWF for liner. 5. Run 2-3/8” 13Cr solid liner 6. Pump primary cement job: 19 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. * Approved alternate plug placement per 20 AAC 25.112(i) PTD 224-155 Sundry 324-702 Not a Plug for Redrill: If approved as proposed, the D-01A wellbore beneath the whipstock will not be isolated until the liner for D-01B is cemented. That portion of D-01A will be considered open and retain the status of "Oil" until it is permanently isolated. SFD Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : Post rig RPM, CBL, perforate ~20-30' 1.56" guns 3. Slickline : Set GLV's, contingent LTP Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 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 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" 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 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 2-3/8" Pipe / Slip CL 2.0" 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 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer 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: 12/06/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231206 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 13-8 50133203040000 177029 11/15/2023 HALLIBURTON EPX NCIU A-17 50883201880000 223031 11/28/2023 HALLIBURTON RBT PBU 04-46A 50029224340100 223082 11/1/2023 HALLIBURTON RBT PBU 05-26A 50029219840100 201221 11/24/2023 HALLIBURTON PPROF PBU 06-20B 50029207990200 223075 10/18/2023 BAKER MRPM PBU D-01A 50029200540100 197078 10/31/2023 HALLIBURTON RBT PBU N-07A 50029201370100 204105 10/7/2023 BAKER SPN PBU P1-08A 50029223840100 202199 9/22/2023 BAKER SPN PBU P2-56 50029226100000 195162 11/14/2023 BAKER SPN PBU P2-57A 50029221830100 202214 11/1/2023 BAKER SPN Please include current contact information if different from above. T38205 T38206 T38207 T38208 T38209 T38210 T38211 T38212 T38213 T38214 12/6/2023 PBU D-01A 50029200540100 197078 10/31/2023 HALLIBURTON RBT Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.06 14:25:58 -09'00' 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 D-01A Install Scab Liner Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-078 50-029-20054-01-00 10670 Surface Intermediate Production Liner Scab Liner 9072 3998 7300 9270 1530 1195 10183 13-3/8" 10-3/4" x 9-5/8" 9-5/8" x 7" 4-1/2" 3-1/2" x 3-1/4" 8980 32 - 4030 2000 - 9300 30 - 9300 9138 - 10668 9002 - 10197 32 - 4030 2000 - 8567 30 - 8567 8424 - 9071 8305 - 8982 10251, 10272 1540 2480 4760 7500 10530 10183, 10272 3090 5210 6870 8430 10130 10034 - 10072 4-1/2" 12.6# 13cr80, L80 28 - 9142 8934 - 8949 Conductor 2413 20" 34 - 2447 34 - 2447 1530 520 4-1/2" Baker S3 Packer 9086, 8379 8928, 9086 8240, 8379 Torin Roschinger Operations Manager Kirsty Glasheen Kirsty.Glasheen@hilcorp.com 907.564.5258 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 0028285 28 - 8428 9140' - 10272'MD in 3-1/2" x 3-1/4" Scab liner x 4-1/2" completion annulus. Pump 17.5-bbls 15.8-ppg Class G Cement. Final squeeze pressure = 1450-psi 591 553 57122 32332 56 1426 100 200 1100 950 323-473 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker SB-3 Packer 8928, 8240 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 12:33 pm, Nov 15, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.11.14 14:38:26 -09'00' Torin Roschinger (4662) RBDMS JSB 111623 WCB 4-26-2024 DSR-11/15/23 ACTIVITYDATE SUMMARY 9/12/2023 ***WELL S/I ON ARRIVAL*** (RWO capital) TAG XN W/ KJ, 3.80" CENT. 2' OF STEM, 3.80" GAUGE RING @ 9,126' SLM (3' correction to 9,129' MD) DRIFT TO DEVIATION W/ KJ, 3.50" CENT, 2" SAMPLE BAILER STOP @ 10,200' SLM (10,203' corrected) ***WELL LEFT S/I*** 9/26/2023 T/I/O/OO = SSV/0/0/20. Temp = SI. PPPOT-T (PASS), PPPOT-IC (FAIL) (Pre CTD). No AL. OA cemented to surface. PPPOT-T: Stung into test port (0 psi), bled void to 0 psi. Monitor for 10 min, no change in pressure. Pump through void, good returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS, all moved freely. PPPOT-IC: Stung into test port (0 psi). Monitor for 10 min, no change in pressure. Single port, unable to pump through void. Unable to pressure void above 600 psi, pressure falls off to 0 psi as soon as pump is shut down (2.5 gal). CM head has no LDS, Wellhead has a compression primary seal and an interference secondary, no provisions for packing off the secondary seal. (FAIL). SV, WV, SSV = C. MV = O. IA, OA, and OOA = OTG. 15:00. 10/14/2023 T/I/O=2300/0/0 Load & Kill Tbg ( Pre RWO ) Pump 2 bbls 60/40, 300 bbls 1% kcl, & 5 bbls 60/40 down tbg. FWHPs=0/0/0 10/14/2023 T/I/O= 1850/0/0 TFS unit 4 (Well Kill) Pump 156 BBLS 1% KCL and 6 BBLS 60/40 to FP surface lines and Tree, JOB CONTINUES ON 10-15-23 10/15/2023 Well support had to lubricate 4" H BPV due to pressure still on well after two unsuccessful attempts to kill it, nipple down THA, clean void ring groove, & BPV profile, set CTS plug, make up 4-1/2" TC-II test sub to lift threads in tubing hanger, test 3500 psi/10 min., good test bleed off, install new BX-160, RDMO 10/15/2023 T-Bird Rig 1. Job Scope: Run Scab Liner. Move Rig from MPM-22 to D-01A. Begin Rig up operations, Install well houses on BOPE, RU Aux equipment ***Continue Job on 10/16/23 WSR*** 10/15/2023 TFS Unit 4 JOB CONTINUES FROM 10-14-23, Standby to monitor PSI. Well support in controll of well upon departure FWHP=250/0/0 10/15/2023 T/I/O/OO=250/0/0/0. Pre TB-#01. Set 4" CTD BPV # CTS4-03 @ 125" with CIW lubricator, ND 4" CIW tree and 13" CIW THA. NU 13 5/8" 5k spacer spool and 13 5/8" CIW BOP stack with Birdbath and shooting flange. Torqued flanges to spec. Secure and turn over to rig personnel. ***Job COmplete*** Final WHP's BPV/0/0. 10/16/2023 TB1 RWO Job Scope: Run Scab Liner Continue to Rig Up. Prep for BOP Test. AOGCC Witness waived by Josh Hunt at 16:00.Troubleshoot annular bag with yellow jacket ***Continue Job on 10/17/23 WSR*** 10/17/2023 Pull CTS plug w/ dry rod. S/B for rig to pump 250 bbls through 4"HBPV @ 1.5 BBL per min. Pull 4" CTSHBPV. Daily Report of Well Operations PBU D-01A Daily Report of Well Operations PBU D-01A 10/17/2023 TB1 RWo Job Scope: Run 3-1/4" X 3-1/2" Scab Liner. Continue to test BOPE ( AOGCC inspector Josh Hunt waived witness), Change out annular on bope, Test annular, prep and tally scab liner, Pull CTS plug from BPV, Pump 250 BBL sea water @ 1.5 BPM initial pump pressure 2450 PSI, Well on vac @ 130 BBL away, Flow check tubing. .............continue WSR on 10/18/2023 10/17/2023 T/I/O= 2450/0/0 TFS Unit 4 assist T-Bird Rig (Load and Kill) Pumped 2 BBLS 60/40 down Kill line to open top an 3 BBLS 60/40 and 250 BBLS SW down TBG, JOB CONTINUES ON 10-18-23 10/18/2023 TFS Unit 4 Assist TFS RIG, Load and kill well, pump 300 BBLS SW, 755 BBS 1% KCL, 1184 BBLS Slick KCL JOB CONTINUES ON 10-19-23 10/18/2023 TB1 RWO Job Scope: Run 3-1/4"X 3-1/2" Scab Liner. Bullheaded well w/ 250 bbls 1% KCL 4 bpm @ 250 psi. Top fill hole at 4.8 BPM. Fluid level not at surface after 180 bbls away. Reduce rate to 1.8 bpm constant hole fill. Rigged up replacement elevators. Run 3-1/2 x 3-1/4" liner w/ muke-shoe entry gude, dual float collars, ORCA cementing valveSliding sleeve (closed) XN no-go w/ seal unit, and Deployment Sleeve w/ 4" 'G' fish neck. OAL 1199'. Start running in on 2- 7/8" WS filling pipe at 15 joint intervals. Fluid level @ surface. Loss rate ~1.5 BPH. Attempt to Bullhead well w/ 1% KCL 3.3 BBl in pump caught 1000 psi, try to bump pump through holding close to jug tight, Begin pumping down WS @ 1.7 BPM @ 800 PSI,Ttalk with OE decided to pump 300 BBLs here down tubing then continue in hole pumping every joint while maintaining backside full, came offline at 300 BBLS, Hooked up Kellyhose onto JT# 36, Begin pumping down tubing with kill line open to keep backside full, tighten washington head, continue to PU WS installing FOSV on every joint and pumping 1.7 BPM @ 800 PSI. .............Continue WSR on 10/19/2023 10/19/2023 **********WSR Continued from 10/18/2023********** (TFS Unit 4 Assist TFS Rig with load and kill pump as directed) Pumped 325 bbls of 1%KCL Slick followed by 1603 bbls of 1% KCL to keep Pressure below 500 psi for Rig. ********WSR Continued on 10/20/2023********* 10/19/2023 TB1 RWO Job Scope: Run 3-1/4" X 3-1/2" Scab Liner. Continue running scab liner in on WS. Pumping down WS each connection to maintain a 1.5 bbpm avergae hole fill. Stopped at 3202' and pumped down backside while reciprocating pipe. Opened up flowpath on backside @ 385 psi. Pressure fell to 150 psi @ 1.7 bpm. Continue running in hole continuously filling down the backside @ 1.7 bpm stripping through the Washington head. Fill WS every 15 jts w/ 3 bbls. Change out washington rubber, swap out Pipe wrangler for ASR wrangler Thaw unit to get running. 3/4" fill hose froze trying to fill up on Jt # 246 in hole at time of report ..............Continue WSR 10/20/2023 10/20/2023 (TFS unit 4 Standby for weather) ************WSR Continued on 10/21/2023************ 10/20/2023 *********WSR Continued from 10/19/2023*********** (TFS unit 4 assist TFS Rig) Pumped 1200 bbls of 1% KCL and 275 bbls of Safelube down backside to assist Rig with keeping pressure below 500 psi while they pulled Pipe. Pumped 3.5 BBLS of 60/40 and 30 BBLS of Diesel to Freeze Protect Tubing. Thunderbird Rig in control of Well upon departure. Daily Report of Well Operations PBU D-01A 10/20/2023 TB1 RWO Job Scope: Run 3-1/4" X 3-1/2" scab liner Continue in hole with workstring and scab liner. Maintain continuous hole fill 1.6 BPM down backside and filling tubing every 15 joints with 3 BBLS. Up/Dn Wts 90/55K. Land tapered swage in XN nipple @ 9,129'. Top of deplyoment sleeve @ 9002'. Bottom of liner @ 10,197'. Stack 25K down and come online with pump down WS @ 2 BPM @ 830 psi. PU and release out of scab liner lost ~14k Lbs Up Wt 75K. POH and laydown WS. Freeze protect to 2000' w/ 30 bbls diesel. Set TWC. Start RD , ..........Continue WSR On 10/21/2023 Report. 10/21/2023 TB-1 RWO - RD and move to END1-01 Continue to RD equipment and load out to END1-01, Well Sppt craned off well shelter. 5 hrs NPT due to ice on locking pins in mast causing difficulties unpinning floor and Tbg board. Lower derrick and move to END1-01 ***Job Complete*** 10/21/2023 ************WSR Continued from 10/20/2023************ (TFS unit 4 Standby for weather) 10/22/2023 T/I/O= 330/0/0 Temp= S/I TFS Unit 4 Assist T-Bird Rig (Load and Kill) Pumped 6.5 BBLS of 60/40 followed by 285 BBLS of 1% KCL and 38 BBLS of DSLl Down the Tubing for a Freeze Protect. FWHP= TBG= 0 went on a Vac. 10/22/2023 T/I/O=300/SI/SI. Pull 4" CIW H TWC #712 through BOP's. ***JOB COMPLETE*** Final WHP's= 300/SI/SI. 10/22/2023 Set 4" CTSHBPV w/ dry rod. S/B for N/D BOP. 10/23/2023 T/I/O/OO = BPV/0/0/00. Removed T-Bird BOPs. Installed 4" CIW Production Tree. Torqued to spec. PT Low (350 psi) Passed. PT High (5000 psi) Passed. BPV Removed by Vault Wellhead Tech. FWP = 0/0/0/0 10/23/2023 Inspect TBG HGR neck and lift threads. Install CTS plug. Fill void w/ test oil. Install new BX160. N/U THA. R/U test equipment and test void to 500 for 10 min. passed. 5000 for 30 min. -200 in first 15min. -50 in final 15 min. passed. S/B for tree N/U and test. Pull CTS plug. Pull 4" CTSHBPV. 10/28/2023 SLB CTU #9 - 1.75" CT - .156" WT - Job Scope = Post RWO/Shift Sleeve Open, Cement Scab Liner, CB Log, Perf MIRU CTU. Pump 1.188" drift ball. Perform BOP test. Function test BOPs when stabbed on well. Make up NS ORCA cemeting BHA (B shifting tool dogs facing down. OD= 2.73"). Sat down in the tubing hanger. Work through. Sat down in GLM#3. Unable to pass. POOH. Reconfigure tool. Add MBT below Centralizer and increase nozzle to 2.670". Run Down to Stage Collar @ 9145'. Stack down with no apparent indication of sleeve shift. POOH to Check Tools. ***Job Continued to 10/29/23*** Daily Report of Well Operations PBU D-01A 10/29/2023 SLB CTU #9 - 1.75" CT - .156" WT - Job Scope = Post RWO/Shift Sleeve Open, Cement Scab Liner, CB Log, Perf Make a 3rd attempt to get stage collar to shift OPEN. RIH with NS B shifting tools again, 2.600" Centralizers, and 2.125" Tempress Tool. Get to 9162' CTM. Stack down again 10k. Pump 1 bpm, NO GO. Increase to 1.5 bpm, after 5 minutes got all the string weight back. Indicative of sleeve shifting open. Run past stage collar dry 2x's with no slackoffs, good indication sleeve is OPEN. Injectivty test still the same as initial well kill however. 5 bpm @ 525 psi. At surface, discover that both upper and lower B shifting tools have sheared. Stage Collar sleeve still now appears to be stuck in CLOSED position @ 9140'. Discuss plan forward with OE. Reran the BHA and tag the stage collar, unable to shift the sleeve open. Flag pipe. Make up same BHA with tubing punch (2' 4 shots per ft) and RIH. NoGo at sleeve. Tubing Punch Holes 9150.3' - 9152.3' 4 SPF. 0 deg Phase. 2" 4T38 punch in pup joint below the sleeve. ***Job Continued to 10/30/2023*** 10/30/2023 SLB CTU #9 - 1.75" CT - .156" WT - Job Scope = Post RWO/Shift Sleeve Open, Cement Scab Liner, CB Log, Perf Trim 30' of CT. Change Packoffs, Inspect Injector/Chains. RIH with NS Cement Stinger BHA (ORCA). Kill well with 1% KCL w/ Safelube, 240 bbls, 5 bbl/min. Underbalance the well with 130 bbls of diesel. Sting into ORCA. Establish circularion through tbg punch at 9150'-9152'. HES cement van blew a hydraulic line. Continue bullheading down bsct through tubing punch to formation. Pump 17.5 bbls 15.8 ppg Class G HES Cement. Circulate ~6 bbls up Scab Liner Annulus, Squeeze ~11.5 bbls into Lower Formation = 10216' - 10266'. Unsting from ORCA Valve with 3k Overpull. POOH, circulate PowerVis below tubing punch @ 9150'. POOH pumping coil displacement with Diesel, maintain ~500 psi WHP. ***Job Continued to 10/31/23*** 10/31/2023 SLB CTU #9 - 1.75" CT - .156" WT - Job Scope = Post RWO/Shift Sleeve Open, Cement Scab Liner, CB Log, Perf LD NS Cement Stinger. GS ORCA Sleeve Recovered. Trim 30' of CT. MU NS CTC, DFCV, Disco. PT to 3500 psi. S/B for Cement until 0700. ASH Handbook Review with Coil Crew. Fire Drill with SLB Coil Crew. Make up 2.74" JSN drift and RIH. Tagged TD at 10180' ctm. Make up HES Cement Bond log BHA and RIH. CBL Data Shows Cement up to 9140' of varying competency. +15 Correction, OE Confirmed. Very Competent Cement across planned perf interval. Will Proceed with 2 Perf Runs. ***Job in Progress*** 11/1/2023 SLB CTU #9 - 1.75" CT - .156" WT - Job Scope = Post RWO/Shift Sleeve Open, Cement Scab Liner, CBL Log, Perf PT MHA to 3500 psi. RIH and perforate with HES 2" Millenium 10' Perf Gun, 60 deg Phase, 6 SPF. 10062' - 10072'. POOH confirm guns fired and retrieve ball. RIH w/HES 2" Millenium 10' Perf Gun, 60 deg Phase, 6 SPF, perforate 10,034'-10,044' MD. POOH confirm gun fired and retrieve ball. RDMO. ***Job Complete*** Make up HES Cement Bond log BHA and RIH. CBL gg g Data Shows Cement up to 9140' of varying competency. +15 Correction, OE y gy Confirmed. Very Competent Cement across planned perf interval. Will Proceed with 2 Perf Runs. Continuey bullheading down bsct through tubing punch to formation. Pump 17.5 bbls 15.8 ppggggg Class G HES Cement. Circulate ~6 bbls up Scab Liner Annulus,Squeeze ~11.5 bbls into Lower Formation RIH and perforate with HES 2" Millenium 10' Perf Gun, 60 deg Phase, 6 SPF. 10062' - 10072'. RIH g w/HES 2" Millenium 10' Perf Gun, 60 deg Phase, 6 SPF, perforate 10,034'-10,044 RIH with NS Cement g j Stinger BHA (ORCA). Kill well with 1%KCL w/ Safelube, 240 bbls, 5 bbl/min. g() Underbalance the well with 130 bbls of diesel. Sting into ORCA. Establish circularion through tbg punch at 9150'-9152gg 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: 11/15/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231115 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU D-01A 50029200540100 197078 10/31/2023 HALLIBURTON RBT TBU D-07RD2 50733201170200 192155 11/5/2023 READ Caliper Survey TBU D-17RD 50733201680100 181023 11/5/2023 READ Caliper Survey TBU D-47 50733201950200 191011 11/4/2023 READ Caliper Survey Please include current contact information if different from above. T38136 T38137 T38138 T38139 11/21/2023 PBU D-01A 50029200540100 197078 10/31/2023 HALLIBURTON RBT Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.21 10:31:56 -09'00' 2023-1016_Rig_Hilcorp_Thunderbird1_PBU_D-01A-jh Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: October 19, 2023 P. I. Supervisor FROM: Josh Hunt SUBJECT: Rig Inspection – Thunderbird 1 Petroleum Inspector PBU D-01A Hilcorp North Slope LLC PTD 1970780; Sundry 323-473 10/16/2023: Standby for Thunderbird BOPE test on PBU D-01A, pushed due to problems rigging up. Made a trip out to location to see what was going on. Did a walk- through of the rig with the company man. They have a new building to go around the BOP stack, but the structure was built too narrow to account for choke and kill line connections. Due to this they are having to reconfigure the choke and kill lines, the hole fill line and the return line to the pits with 90s and T’s. Overall, this structure will be an improvement over scaffolding with plastic wrap. Talked to the company man about time management for us so he has a better understanding of the situation for future planning. Took photos while at location. Attachments: Photos (6) Supervisor Notes: I agree the structure around the BOP stack is a weather-driven upgrade from the previously employed scaffold and plastic wrap. However, the narrow structure as shown from the interior views raises questions about the adequacy of the torturous path of the choke and kill lines at the BOP stack connection points. It appears to be a degraded capability in responding to a well control event. Also, there appears to be limited use of targeted 90s, and the kill line 90s may be deficient. According to API STD 53, 5th edition: •Section 4.2.4.1 – “Choke and kill lines should be as straight as possible.” •Section 4.2.4.2 – “Block ells and tees should be targeted or have fluid cushions installed in the direction of flow (or in both directions if bidirectional flow is expected.)” According to API Spec 16C, Choke and Kill Equipment, 3rd edition: •Section 4.4.5 – “All 90-degree elbows, crosses and tees shall have fluid cushions in the direction(s) of flow, except wen the surrounding geometries do not allow the use of fluid cushions. When surround geometries do not allow fluid cushions, the OEM shall recommend maintenance requirements.” jbr; 10/23/2023 2023-1016_Rig_Hilcorp_Thunderbird1_PBU_D-01A-jh Page 2 of 4 Rig Inspection – Thunderbird 1 PBU D-01A (PTD 1970780) Photos by AOGCC Inspector J. Hunt 10/16/2023 Birdbath (spill containment on top of Annular preventer) with flow line connection 2023-1016_Rig_Hilcorp_Thunderbird1_PBU_D-01A-jh Page 3 of 4 New BOPE enclosure 2023-1016_Rig_Hilcorp_Thunderbird1_PBU_D-01A-jh Page 4 of 4 Choke side Kill side 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 D-01A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-078 50-029-20054-01-00 10670 Surface Intermediate Production Liner Scab Liner 9072 3998 7300 9270 1530 1195 9166 13-3/8" 10-3/4" x 9-5/8" 9-5/8" x 7" 4-1/2" 3-1/2" x 3-1/4" 8449 32 - 4030 2000 - 9300 30 - 9300 9138 - 10668 9002 - 10197 32 - 4030 2000 - 8567 30 - 8567 8424 - 9071 8305 - 8982 10251, 10272 1540 2480 4760 7500 10530 9166, 10183, 10272 3090 5210 6870 8430 10130 10034 - 10072 4-1/2" 12.6# 13cr80, L80 28 - 9142 8934 - 8949 Conductor 2413 20" 34 - 2447 34 - 2447 1530 520 4-1/2" Baker S3 Packer 9086, 8379 8928, 9086 8240, 8379 Torin Roschinger Operations Manager Kirsty Glasheen Kirsty.Glasheen@hilcorp.com 907.564.5258 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 0028285 28 - 8428 N/A N/A 245 265 20084 18835 56 15 0 0 840 1160 N/A 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker SB-3 Packer 8928, 8240 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 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.01.03 15:45:36 -09'00' Torin Roschinger (4662) By Grace Christianson at 8:09 am, Jan 04, 2024 RBDMS JSB 011124 DSR-1/26/24WCB 2024-06-24 ACTIVITY DATE SUMMARY 12/8/2023 ***WELL S/I ON ARRIVAL*** DRIFTED TO 3 1/2" x 3 1/4" XO @ 9,154' MD W/ 2.60" CENTRALIZER, 10' x 1 3/4" STEM, 2.76" CENTRALIZER SET 350-272 MONOPAK WRP (2.72" od, 7.59' lih, 1.78" r nipple w/ plug installed) 15' BELOW XO @ 9,166' SLM. ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU D-01A WRP is correctly shown on the new WBS, below. -WCB SET 350-272 MONOPAK WRP (2.72" od, 7.59' lih, 1.78" r nipple w/ plug installed) 15' BELOW XO @ 9,166' SLM. 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 D-01A Mill CIBP, Install Scab Liner Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-078 50-029-20054-01-00 N/A ADL 0028285 10670 Insulation Surface Intermediate Production Liner 9072 237 3998 7300 9270 1530 10272 16" 13-3/8" 10-3/4" x 9-5/8" 9-5/8" x 7" 4-1/2" 8991 1963 - 2200 32 - 4030 2000 - 9300 30 - 9300 9138 - 10668 2370 1963 - 2200 32 - 4030 2000 - 8567 30 - 8567 8424 - 9071 10272 1540 2480 4760 7500 10272 3090 5210 6870 8430 9348 - 10340 4-1/2" 12.6# 13cr80, L80 28 - 91428609 - 8997 Conductor 2413 20" 34 - 2447 34 - 2447 1530 520 4-1/2" Baker S3 Packer 4-1/2" Baker SB-3 Packer 8928, 8240 9086, 8379 Date: Torin Roschinger Area Operations Manager Kirsty Glasheen Kirsty.Glasheen@hilcorp.com 907.564.5258 PRUDHOE BAY 9/1/2023 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 8:05 am, Aug 21, 2023 323-473 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.08.21 07:27:58 -08'00' Torin Roschinger (4662) BOPE test to 2500 psi. 2370 DSR-8/21/23MGR30AUG23 10-404 SFD 8/23/2023 Perforate *&:JLC 8/31/2023 08/31/23 RBDMS JSB 090523 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.31 16:04:25 -08'00' Scab Liner Well: D-01A Date: 08/15/23 Well Name:D-01A API Number:50-029-20054-01 Current Status:Operable- Shut In Pad:D-Pad Estimated Start Date:9/1/2023 Rig:TB, C, EL Reg. Approval Req’d?10-403/10-404 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:1970780 First Call Engineer:Kirsty Glasheen Contact:907-350-4310 Current Bottom Hole Pressure:3250 psi @ 8,800’ TVDss Based on Offsets MPSP:2370 psi (BHP- .1psi/ft gas gradient) Recent SITP:2370 psi Taken 10/17/21 Max Dev:86 deg At 10,308’ MD Min ID:3.725” ID of 4-1/2” XN at 9,129’ MD Brief Well Summary: D-01A had Z4 rich gas perforations shot in 2021. The perforations came on competitive, but they have leaned out over the last year, and we are ready to move production deeper in the well in Z2. A recent PNL log was run that confirmed good areas for new perforations. D-01A had a caliper completed in 2021 that showed the 4- 1/2” liner to be in very poor condition with multiple holes identified along the length of the well that are above the GOC. To provide isolation from the Z4 gas and the holes in the liner, we would like to install a scab liner. After the liner is run and cemented in place, we will selectively perforate the well and bring it online. Notes: x D-01 is an operable well. The well passed a CMIT-TxIA to 2670 on 6/9/2021. x D-01 has LGLVs installed, but there are no known integrity issues. x D-01 will have open perforations during RWO with high injectivity perfs. x Max dogleg is 57 at 9332’ MD. Max dev is 86 at 10,308’ MD. x No recent caliper above 8757’ MD; however, no restrictions noted on caliper from 10182-8757’ MD. x Coil ran 3.69” junk mill to 10251’ MD on 3/28/23. Objective: 1. TB1: Install 3-1/2”x3-1/4” scab liner as detailed on proposed schematic. 2. C: Cement scab liner in place 3. EL: add perforations (10067-10077’ MD and 10041-10051’ MD) Procedure: Slickline: 1. 3.8” drift to XN nipple at 9129’ MD. 2. 3.7” drift to ~9140’ MD. FB: 1. Load well with ~ 215 bbls 8.4 ppg KWF a. WBV to CIBP at 9395 = 143 bbls (1.5X’s = 215) 2. Freeze protect tubing to ~2000’ MD at WSL discretion pending rig move date. DHD: 1. Bleed WHP to 0 psi Valve Shop: 2. Set and test TWC Scab Liner Well: D-01A Date: 08/15/23 3. ND tree and tubing head adaptor. Inspect threads. 4. NU BOPE configured top down: annular, 2-7/8”x5” VBR, blind and integral flow cross. RWO: 1. MIRU TB1 and ancillary equipment a. Well will not be a closed system at MIRU. b. Injectivity is expected to be high. FB pumped 1003 bbl SW on 4/16/23. They were on a vac while pumping up to 1.0-4.5 bpm. c. Well has LGLVs installed, but there is no known TxIA. 2. Test BOPE to 250 psi low/2500 psi high, annular to 250 psi low/2500 high. a. Notify AOGCC 24-hr before BOP test. b. Perform test per TB1 test procedure. c. Confirm test pressure per the Sundry Conditions of approval. d. Test VBR ram and annular with 2-7/8” and 3-1/2” test joint. Will have 3-1/4” safety joint. e. Submit AOGCC completed 10-424 form within 5 days of BOPE test 3. Pull TWC w/ lubricator. 4. Kill well with ~215 bbls of 8.4 ppg KWF. Establish kill rate. Keep hole full or pump at minimum rate of 30 bbl/hr throughout operation. a. 1.5 X’s WBV to CIBP at 9395 = 215 bbls b. 30 bbl/hr minimum pump rate needed to prevent gas migration. 5. PU 3-1/2”x3-1/4” scab liner as detailed on proposed liner tally and run liner with workstring. a. Scab liner to be run on workstring with 4” hydraulic GS b. 3.75” swage section of scab liner will no-go out on XN nipple at 9129’ MD. Slow down running speed as approach no-go depth. c. 50’ rathole is being left between bottom of scab liner and CBP debris at 10251’ MD. d. Scab liner weighs ~7250#s in air. e. 3-1/2” section of scab is ~129’ long. 3-1/4” section of scab is ~1035’ long. 6. Release from liner and POOH with workstring 7. Obtain injectivity test to confirm injectivity after scab liner installed. 8. Set TWC 9. RDMO TB1 Valve Shop: 1. ND BOPE 2. NU tree and tubing head adaptor 3. Test tree and tubing hanger void to 500 psi low/5,000 psi high. 4. Pull TWC Fullbore: 1. Load well with 142 bbls diesel. This is for freeze protect and to underbalance the well for the upcoming cement job. Coil: 1. MIRU Coil 2. RIH with cement stinger, engage orca valve at ~10,184’ MD, and shear disk. 3. Cement liner as detailed below: a. 10 bbl fresh water b. 14 bbls 15.8 class G cement i. Scab liner x 4.5” liner volume ~5 bbls Well will not be a closed system at MIRU. Work string to be =>2.875" and =<3.5" - mgr Scab Liner Well: D-01A Date: 08/15/23 c. 10 bbl fresh water 4. After cement is pumped/squeeze pressure achieved, unsting from orca valve. 5. POOH to close sliding stage collar at ~9143. 6. Circulate excess cement and wash tubing. 7. POOH, freeze protect, and RDMO. Fullbore: 1. MIT-T to 1000 psi Slickline: 1. Drift to TD with 10’ of 2” guns. EL: 2. Shoot perforations 10,067-10,077’ MD and 10,041-10,051’ MD. a. If SL drift was not able to make it to request perf depth, coil will shoot perfs. Attachments: x Current Wellbore Schematic x Proposed Wellbore Schematic x 2021 Liner Caliper Log x BOP Schematic x Sundry Change Form Shoot perforations 10,067-10,077’ MD and 10,041-10,051’ MD. Scab Liner Well: D-01A Date: 08/15/23 Figure 1: Current WBS Scab Liner Well: D-01A Date: 08/15/23 Figure 2: Proposed Schematic Scab Liner Well: D-01A Date: 08/15/23 Figure 3: 2021 Liner Caliper Scab Liner Well: D-01A Date: 08/15/23 Figure 4: BOPEs Hi l c o r p N o r t h S l o p e , L L C Hi l c o r p N o r t h S l o p e , L L C Ch a n g e s t o A p p r o v e d R i g W o r k O v e r S u n d r y P r o c e d u r e Da t e : A u g u s t 1 8 , 2 0 2 3 Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l D - 0 1 A Su n d r y # : An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a t e d t o th e AO G C C b y t h e r i g w o r k o v e r ( R W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a ng e . St e p Pa g e Da t e P r o c e d u r e C h a n g e HNS Pr e p a r e d By ( I n i t i a ls ) HN S Ap p r o v e d By ( I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : As s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : Fi r s t C a l l O p e r a t i o n s E n g i n e e r D a t e Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/02/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230415 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 2-20 50029220480000 190060 4/12/2023 BAKER SPN PBU 01-10 50029201690000 175043 4/15/2023 BAKER SPN PBU 01-13 50029202700000 177059 4/13/2023 BAKER SPN PBU 15-05B 50029207310200 211057 4/24/2023 BAKER RPM PBU 15-09B 50029212010200 212024 4/26/2023 BAKER RPM PBU D-01A 50029200540100 197078 4/15/2023 BAKER SPN PBU D-10 50029203890000 179053 4/17/2023 BAKER SPN PBU E-26B 50029217810200 221084 4/9/2023 BAKER MRPM PBU F-33A 50029226400100 208163 4/20/2023 BAKER SPN PBU J-12 50029204450000 180017 4/17/2022 BAKER SPN PBU J-19 50029216290000 186135 4/18/2023 BAKER SPN PBU N-15 50029206070000 181079 4/20/2023 BAKER SPN PBU R-04 50029203740000 179038 4/21/2023 BAKER SPN PBU R-27 50029215570000 186051 4/22/2023 BAKER SPN PBU Z-25 50029219020000 188159 4/23/2023 BAKER SPN Please include current contact information if different from above. T37696 T37697 T37698 T37699 T37700 T37701 T37702 T37703 T37704 T37705 T37706 T37707 T37708 T37709 T37710 PBU D-01A 4/15/2023 BAKER SPN50029200540100197078 Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.05 11:18:47 -08'00' 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: Mill Plug Insulation Surface Intermediate Production Liner 1540 2480 4760 7500 Conductor 520 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: 13b. Pools active after work: 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 RBDMS JSB 040623 DSR-4/6/23WCB 11-28-2023 Milled plug is correctly shown on the new WBS, below. -WCB 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU D-01A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-078 50-029-20054-01-00 10670 Insulation Surface Intermediate Production Liner 9072 237 3998 7300 9270 1530 9395 16" 13-3/8" 10-3/4" x 9-5/8" 9-5/8" x 7" 4-1/2" 8648 1963 - 2200 32 - 4030 2000 - 9300 30 - 9300 9138 - 10668 1963 - 2200 32 - 4030 2000 - 8567 30 - 8567 8424 - 9071 10272 1540 2480 4760 7500 9395, 10272 3090 5210 6870 8430 9338 - 10340 4-1/2" 12.6# 13cr80, L80 28 - 9142 8600 - 8997 Conductor 2413 20" 34 - 2447 34 - 2447 1530 520 4-1/2" Baker S3 Packer 8928, 8240 Stan Golis Sr. Area Operations Manager Noel Nocas Noel.Nocas@hilcorp.com 907.564.5278 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028285 4-1/2" Baker SB-3 Packer 28 - 8428 9086, 8379 N/A N/A 571 63451 474 0 1246 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: 8928, 9086 8240, 8379 No SSSV Installed 1090 51509 100700 By Meredith Guhl at 12:45 pm, Oct 29, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.10.29 12:16:26 -08'00' Stan Golis (880) SFD 11/1/2021 RBDMS HEW 10/29/2021 DSR-10/29/21MGR29OCT2021 ACTIVITY DATE SUMMARY 10/17/2021 T/I/O/OO = 2370/VAC/VAC/10. Temp = SI. T FL (Eline). No AL. T FL @ 9130' (1086' above perfs). SV, WV, SSV = C. MV = O. IA = OTG. 21:30 10/20/2021 ***WELL SHUT IN UPON ARRIVAL*** INITIAL T/I/O = 2400/0/0 PSI RUN 1: PERFORATE INTERVAL: 9338' - 9348', CCL TO TOP SHOT = 7.5', CCL STOP DEPTH = 9330.5' LAY DOWN FOR NIGHT. ***JOB IN PROGRESS*** 10/21/2021 ***JOB CONTINUED FROM 20-OCT-21*** RUN 2: SET HES 3.66" CBP PLUG AT 9395.0' - CCL TO ME = 12.5', CCL STOP DEPTH = 9382.5' PAD OP TOLD TO CONFIRM WITH OE BEFORE BRINGING WELL ONLINE. ***JOB COMPLETE*** Daily Report of Well Operations PBU D-01A Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:197-078 6.50-029-20054-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10670 10272 8991 8928, 9086 10270 10272 8240, 8379 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 2413 20" 34 - 2447 34 - 2447 1530 520 Insulation 237 16" 1963 - 2200 1963 - 2200 Surface 3998 13-3/8" 32 - 4030 32 - 4030 3090 1540 Intermediate 7300 10-3/4" x 9-5/8" 2000 - 9300 2000 - 8567 5210 2480 Production 9270 9-5/8" x 7" 30 - 9300 30 - 8567 6870 4760 Perforation Depth: Measured depth: 10216 - 10340 feet True vertical depth:8985 - 8997 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13cr80, L80 28 - 9142 28 - 8428 8928 8240Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S3 Packer Liner 1530 4-1/2" 9138 - 10668 8424 - 9071 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12-bbls of 10.0-ppg Class G spacer, 280-bbls 14.0-ppg Class G Cement. Final treating pressure = 1451-psi Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1163500464663 19251488 300 57602 418 1804 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Aras Worthington Aras.Worthington@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.4763 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9072 Sundry Number or N/A if C.O. Exempt: 321-202 4-1/2" Baker SB-3 Packer 9086 8379 Junk Packer Printed and Electronic Fracture Stimulation Data 5 OA Cement Repair Operations shutdown Change Approved Program 5 Surface - 6160' MD in OA Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028285 PBU D-01A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:17 pm, Jul 06, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.07.06 12:55:28 -08'00' Stan Golis (880) RBDMS HEW 7/8/2021 MGR28JUL2021 DSR-7/6/21 SFD 7/6/2021 ACTIVITY DATE SUMMARY 5/11/2021 ***WELL S/I ON ARRIVAL***(cement squeeze) DEPLOYED 4-1/2" CATCHER. PULLED BK-DGLV FROM ST# 1 @ 8,411' MD. PULLED BK-DGLV FROM ST# 2 @ 6,407' MD. SET BEK-CIRC VLV IN ST# 2 @ 6,407' MD. SET BEK-CIRC VLV IN ST# 1 @ 8,411' MD. ***WSR CONTINUED ON 5/12/21*** 5/12/2021 ***WSR CONTINUED FROM 5/11/21*** (cement squeeze) PULLED EMPTY 4-1/2" CATCHER FROM 8,946' SLM. ***JOB COMPLETE, WELL LEFT S/I*** 5/13/2021 T/I/O/OO=10/289/289/0. Pre cement job. Bleed I/A-O/A to 0psi. (Fluid) RD 3" FMC OA valve. RU 3" 5000 integral and Hardline to OA for cement job. Job Complete. Final WHP's 10/0/0/0. 5/29/2021 ***JOB STARTED ON 28-MAY-2021*** (HES OA Cement Squeeze) Initial T/I/O = 0/0/0. Pumped 12 BBL's of 10 ppg class "G" cement spacer followed by 280 BBL's of 14 ppg class "G" cement down the OA taking returns from the IA to open top tanks. Turned the well back over to LRS for TxIA circ-out. ***JOB COMPLETE ON 29-MAY-2021** ***Top of cement in OA = surface, bottom of cement in OA = 6160' MD. 280 BBL's of 14 ppg class "G" cement.*** 5/29/2021 T/I/O=0/0/0 Circ well to 2% SKL 400 / Assist Cement job (Cement Squeeze OA) Pumped 5 bbls 60/40 & 280 bbls 2% SKL 400 down OA taking returns up IA to D-29 flowline. Pumped 350 bbls 2% SKL 400 down Tbg taking returns up IA to D-29 flowline. Pump 50 bbls Surfactant/Water down OA returns up IA to flowline. HES pumped cement. Pumped 16 bbls gel pill, 445 bbls 2% SKL 400 and 100 bbls diesel at 140* down TBG taking returns up IA to OTT. *** Continued job on 5-30-21 *** 5/30/2021 *** Job continued from 5-29-21 *** Initial T/I/O= 2725/1950/265 Pumped 250 bbls diesel (350 total) down TBG up IA to OT for FP. SV,SSV closed MV 0pen CV's OTG Final T/I/O= 2400/2310/134 6/3/2021 T/I/O/OO = SSV/700/0/0. Temp = SI. Strap TOC (IAxOA cement). No AL. OA TOC @ surface. SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 11:45 6/8/2021 T/I/O= 500/350/0/0 TFS unit #2 (CMIT-TxIA) Road to location, Start rig up ***Job continued on 06/09/2021*** 6/9/2021 ***Job continued from 06/08/2021*** TFS unit #2 (CMIT-TxIA) CMIT-TxIA ***Failed*** Max applied 2750 psi with a target of 2500 psi. pumped 4.2 bbls DSL to achieve max applied psi. 1st 15 min TxIA lost 50/50 psi. 2nd 15 min TxIA lost 25/50 psi for a total of 75/100 psi in 30 min. Bled back 4 bbls DSL. Tag hung on IAC & MV @ departure. FWHP= 500/500/0/0 6/9/2021 T/I/O/OO= 580/400/0/0 (CMIT-TxIA) CMIT-TxIA **PASSED** to 2680/2670 psi. Max applied pressure= 2750 psi. Target pressure= 2500 psi. Pumped 4.0 bbls of diesel down the tbg and IA reach test pressure. 1st 15min T/IA lost 50/60 psi, 2nd 15min T/IA lost 20/20 psi, Total T/IA loss 70/80 psi in 30 min test. Bleed back 3.8 bbls. Hung fluid packet annulus sign. FWHP= 500/500/0/0 psi. SV, WV, SSV= closed IA, OA, OOA= OTG Daily Report of Well Operations PBU D-01A Daily Report of Well Operations PBU D-01A 6/11/2021 ***WELL SI ON ARRIVAL- cement squeeze*** PULL PX PRONG FROM 8951' SLM PULL BEK-CIRC VLV FROM STA #1 @ 8409' SLM (8411' MD) PULL BEK-CIRC VLV FROM STA #2 @ 6402' SLM (6407' MD) PULL BK-DGLV FROM STA #3 @ 3883' SLM (3892' MD) SET BK-LGLV IN STA #3 @ 3883' SLM (3892' MD) 6/12/2021 ***WSR CONT'D FROM 6/11/21*** ***WELL SI ON ARRIVAL- cement squeese*** SET 20/64" OGLV IN STA #2 @ 6405' SLM (6407' MD) SET DGLV IN STA #1 @ 8411' SLM (8411' MD) PULLED PX PLUG BODY FROM @ 8951' SLM (8962' MD) ***WELL SI ON DEPARTURE - JOB COMPLETE*** 6/27/2021 T/I/O=1000/0/0. Post Cement Squeeze. RD OA integral and block vavle and RU OA gate valve. Torque to API spec. ***Job Complete*** FINAL WHP's 1000/0/0 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:197-078 6.API Number:50-029-20054-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028285 Property Designation (Lease Number):10. 341H 8. PBU D-01A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10670 Effective Depth MD: 13cr80, L80 11. 5/3/2021 Commission Representative: 15. Suspended Contact Name:Aras Worthington Contact Email:Aras.Worthington@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" Baker SB-3 Packer Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9072 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8928, 8240 9086, 8379 Date: Liner 1530 4-1/2"9138 - 10668 8424 - 9071 8430 7500 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 34 - 2447 32 - 4030 32 - 4030 14. Estimated Date for Commencing Operations: BOP Sketch 1963 - 2200 Conductor 5210 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S3 Packer 10216 - 10340 8985 - 8997 4-1/2" 12.6#28 - 9142 Production 8962 8270 8962, 10272 10272 1963 - 2200 13-3/8" 10-3/4" x 9-5/8" Contact Phone:907.564.4763 Date: 2480 237 16"Insulation 1540 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 2413 20"34 - 2447 520 Surface 3090 Intermediate 7300 2000 - 9300 2000 - 8567 9270 9-5/8" x 7" 30 - 9300 30 - 8567 6870 4760 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst 1530 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2500 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. OA Cement Downsqueeze 3998 By Samantha Carlisle at 3:41 pm, Apr 19, 2021 321-202 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.19 14:44:14 -08'00' Stan Golis (880) DSR-4/19/21DLB 04/19/2021 X MGR22APR2021 10-404Yesn Required? Comm 4/22/21 dts 4/22/2021 RBDMS HEW 4/23/2021 Well Program Well: D-01A Date: 04/19/2021 Well Name:D-01A API Number:50-029-20054-01 Current Status:Not Operable; Secured; IAxOA Comms. Rig:FB/SL Estimated Start Date:May 2021 Estimated Duration:2 weeks Reg.Approval Req’std?Yes Date Reg. Approval Rec’vd: First Call Engineer:Aras Worthington 907-440-7692 Second Call Engineer:Noel Nocas 907-564-5278 Current Bottom Hole Pressure:Est. 3250 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2500 psi (based on previous SIWHPs) Max Inc:See Schematic Integrity Issues:OAxIA LLR (0.5 bpm/1000 psi) @ 6160’ MD Brief Well Summary D-01 is a Not Operable Ivishak producer with rapid IAxOA communication (LLR OA to IA ~1.5-2 bpm/2000 psi) @ ~6160’ MD that has been SI since June of 2019 due to IAxOA communication. An MIT-T passed to 2743 psi on 6/7/2019 verifying tubing/plug integrity. A CMIT-IAxOA failed to 2500 psi on 7/13/2019 with a LLR of 0.8 gpm/2500 psi (132/137 psi 1st 15 mins, 60/78 psi 2nd 15 mins), however the OAxIA Integrity Test (no leaks to surface) passed during the same test. Objective OA cement downsqueeze to repair the IAxOA Comms. Procedure Slickline 1. Set Flowsleeve in GLM @ 8411’ MD. Fullbore 1. Pump ~280 bbls of 14 ppg Class G cement down the OA with returns from the IA to cement the OA from surface to the 7” casing leak @ ~6160’ MD. Pump the following schedule at maximum rate below 2500 psi treating pressure: ¾10-bbls of 60/40 or 10 bbls neat MEOH ¾30 bbls hot (180 deg) freshwater + surfactant ¾10 bbls of weighted spacer ¾~280 bbls of 14 ppg Class G cement 2. Circulate down the tubing and out the IA with the following pump schedule to clean-out cement (~15 bbls) that will be in the IA from the OA cement job. Pump at a maximum rate under max tubing pressure of 2500 psi to ensure a good cement clean out. Hold at least 1900 psi on the IA throughout Well Program Well: D-01A Date: 04/19/2021 the circulation to keep cement from U-tubing into the IA. Trap at least 2400 psi on the IA when done circulating diesel FP to keep cement in place in the OA. ¾20 bbls viscosified SW or 1% KCl ¾600+ bbls FW, SW, or 1% KCL; Circ @ max rate until ~330 bbls away (surface to surface) ¾Pump minimum rate until cement reaches thickening time (approx. 8 hours) holding 1900 psi on the IA. ¾5 bbls of methanol ¾350 bbls heated (140F) diesel to FP tubing and IA (pump at minimum rate to allow cement time to gel and set as the IA is circulated). Keep at least 1900 psi on the IA as it is circulated and walk pressure up to ~2400 psi on the IA as diesel is circulated to surface. Trap ~2400 psi on the IA when done circulating to keep cement in place. Volumes: top MD bot MD Size ID bbls/ft.Ft. volume bbls 4-1/2” Tubing to Flow Sleeve 0 8411’4-1/2” 12.6#3.958”0.0152 8411’128 9-5/8” x 4-1/2” annulus to 1886’ MD 0 1886’ 9-5/8” 47# x 4-1/2” 12.6# 8.681” x4.5”0.0535 1886’101 7” x 4-1/2” annulus to Flow Sleeve 1886’8411’ 7” 26# x 4- 1/2” 12.6# 6.276” x4.5”0.0186 6525’121 IA Total Volume to Flowsleeve 0 8411’222 13-3/8” x 9-5/8” annulus 0 1886’ 13-3/8”68# x9-5/8” 12.415” x 9.625”0.0597 1886’113 13-3/8” x 7” annulus to XO @2427’ MD 1886’2427’ 13-3/8” 68# x 7” 12.415” x 7”0.102 541’55 9-5/8” x 7” annulus to 7” Leak @ 6160’ MD 2427’6160’ 9-5/8” 47# x 7” 8.681” x 7”0.0256 3733 96 OA Total Volume to 7” Leak @ 6160’ MD 0 6160’264 Ppg:14 ppg Class G – Mix on the fly Slurry Temperature:between 80° and 110°F API fluid loss:40 - 200 cc (20-100cc/30min) Thickening Time:Minimum 7 hours Compressive Strength:2000 psi in 24 – 60 hours Well Program Well: D-01A Date: 04/19/2021 Cement thickening time: Mix on the fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 5 Cement contamination 2 Safety 0 Minimum required thickening time:7 Special Projects 1. Strap the TOC in the OA. 2. Fill and squeeze the remaining void in the OA with well lock, squeezecrete, or similar product (if needed). Squeeze to 2500 psi. DHD/Operations 1. CMIT TxIA to 2500 psi. 2. Re-classify well as Operable. Slickline 1. Pull TTP and POP. Special Projects 1. Strap the TOC in the OA. 2. Fill and squeeze the remaining void in the OA with well lock, squeezecrete, or similar product (if needed). Squeeze to 4000 psi. DHD/Operations 1. CMIT TxIA to 2500 psi. 2. Re-classify well as Operable. Slickline 1. Pull TTP and POP. Well Program Well: D-01A Date: 04/19/2021 D-01 Current Well Program Well: D-01A Date: 04/19/2021 D-01 Proposed Cemented OA Surface to 7” Leak @ 6160’ MD Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢7'~7~.~/File Number of Well History File PAGES TO DELETE RESCAN Complete Color items- Pages: /-/7- ~z-~2/ ~'~ -' Grayscale, halftones, pictures, graphs, charts Pages: Poor Quality Odginal - Pages: D Other- pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of vadous kinds Other COMMENTS: Scanned by: ~,v~y M~r~ Date.: TO RE-SCAN Notes: Re-Scanned by: Bever~ Mildred Daretha~owell • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 • 19 c7 March 06, 2011 6 2 J 31 ' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7 Avenue Anchorage, Alaska 99501 " ;Ho Subject: Corrosion Inhibitor Treatments of GPB D Pad i ka `& (ons. Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad 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 altemate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03/04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal D -01A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -046 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -076 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 D -10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D -11B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 0-12 1800150 50029204430000 NA 1.3 . NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 1111 D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 D -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -196 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 D -20 1820440 50029207800000 NA 0.5 NA 1.70 2/i 9/2011 0-21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 208i210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -266 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 0-27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -286 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 D -29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -306 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D -31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 0-33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 ..} ~e.•, ~ + ~ ~ STATE OF ALASKA £ '~ ~'~ ~ ~I~`~ /~D~ ALA~ OIL AND GAS CONSERVATION COM~SION ~~ ~;:° ~,~ ~~~~ ~ E_. ~ REPORT OF SUNDRY WELL OPERATIONS ( qqypgy q , . ., . . J~'. .,^,~~.1J. (3~3iEl3P~~~S~~S~. 1. Operations Performed: r jt ' ` ° ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 197-078 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20054-01-00 7. KB Elevation (ft): 65.95' 9• ~Nell Name and Number: PBU D-01A 8. Property Designation: 10. Field / Pool(s): ADL 028285 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 10670' feet true vertical 9072' feet Plugs (measured) 10272' Effective depth: measured 10272' feet Junk (measured) 10272' true vertical 8991' feet Casing Length Size MD TVD Burst Collapse Structural 84' 30" 84' 84' Conductor 2447' 20" 2447' 2447' 1530 520 SurFace 237' 16" 1963' - 2200' 1963' - 2200' Intermediate 4030' 13-3/8" 4030' 4030' 3090 1540 Production 7298' 10-3/4" x 9-5/8" 2000' - 9298' 2000' - 8565' Liner 9-5/8" x 7" 9298' 8565' 6870 4760 Liner 1530' 4-1/2" 9138' - 10668' 8424' - 9071' 8430 7500 Straddle Packer 197' 7" 1684' - 1881' 1684' - 1881' Assembly Perforation Depth MD (ft): 10216' - 10266' Perforation Depth ND (ft): 8985' - 8991' 4-1/2", 12.6# 13Cr80 / L-80 9142' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): ~~~ x 4-1/2" Baker'S-3' packer; 8928 ; 7" x 4- 1/2" Baker'SB-3' packer 9086' 12. Stimulation or cement squeeze summary: Intervals treated (measured): - - ~~ k.{'" ~C.+~i ~, SRW rr' I f. ~{ t 1~, ~ . , . ~ ,<Jlj_9 Treatment description including volumes used and final p ressure: S~ '`~ (a5-o~ 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 783 27,583 890 1,800 1,300 Subsequent to operation: 1,247 30,192 556 1,500 1,250 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowtedge. Sundry Number or N/A if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 ~ N/A Printed Name Terrie Hubble Title Drilling Technologist ~ O/3 Prepared By Name/Number ~J Signature Phone 564-4628 Date Terrie Hubble, 564-a628 Form 10-404 Revised 04/2006 ~ ~1~. ~,UG ~ l 20~9 Submit Onginal Only 'r < %~, ,/ ~~ fi c~ . ~ ~'~ :~ .= : ~ . • D-01A, Well History (Pre Rig Workover) Date Summary 6/5/2009 WELL S/I ON ARRIVAL. RIH W/ 4 1/2° GR & WRP PULLING TOOL TO 9097' SLM. (UNABI F Tn. LATCH WRP) MULTIPLE RUNS W/ 3" X 10' PUMP BAILER TO 9097' SLM. (RECOVERED 1 1/2" GAL SCALE) RUN 3.805" GAUGE RING WORK TIGHT SPOTS FROM 9008' SLM TO 9097' SLM. RUN W/ 3" X 10' PUMP BAILER TO 9097' SLM. 6/6/2009 MULTIPLE RUNS WITH 3" X 10' PUMP BAILER ON WRP @ 9097' MD. RAN 2.75 HYD. BAILER W/ 3.50" X 12" BOTTOM (NO REC.) RAN 3.75" CENT. 2' X 1 7/8" STEM 3.80" LIB TO 9089' SLM. (NO IMPRESSION ON FACE) ATTEMPT TO LATCH WRP Ca~ 9097' SI M W/ 4-1/2" GR. 3J5" WFD_ _SHORTY WRP PULLING TOOL (UNABLE TO LATCH) RIH W/ 3.805" G-RING, 4-1/2" BRUSH, XO, 2.25" LIB TO 9097' SLM. (IMPRESSION OF SHEAR STUD). 6/7/2009 ATfEMPT TO PULL 4 1/2" WRP C~ 9097' SLM. MULTIPLE RUNS W/ 3" X 10' & 3 1/2" X 10' PUMP BAILERS TO 9097' SLM. RUN 3" X 10' PUMP BAILER W/ TT PIN BALL BOTTOM TO 9097' SLM. (2 1/2" PIN BENT, NO RETURNS). RUN 3.40" BELL GUIDE W/ TT PINS TO 9097' SLM. (7 TT PINS SHEARED 8" TOTAL LENGTH). RUN 2 1/2" HYROSTATIC BAILER W/ 3.5" FLAT BOTTOM TO 9097' SLM. (NO RETURNS). 6/8/2009 MULTlPLE RUNS W/ 3" X 5' PUMP BAILER TO 9097' SLM BIG CHUNKS OF SCALE RECOVEREDI RUN 3.625" CENT,3.40" BELL GUIDE W/ TT PINS. 9097' SLM. RAN 3.75" 4-1/2" GR, 3.75" WFD MODIFIED SHORT WRP PULLING TOOL (OAL 21" ) SD C~ 9097' SLM. CAN'T LATCH 4-1/2" WFD WRP. WELL S/I ON DEPARTURE. 6/11/2009 T/I/O/00 = 270/270/170/40. Temp = SI. Bleed WHPs to 0 psi (Assist CAM). No AL. TBG, OA, & OOA FL's near surface, IA FL Q 186'. Bled TP to BT from 270 psi to <1 psi in 1 hr 45 mins (gas to gas & fluid swapping). During TP bleed, IAP decreased 50 psi to 220 psi. Bled IAP from 220 psi to 0 psi in 1 hr 45 mins (all gas). Bled OAP from 170 psi to 1 psi in 1 hr 20 mins. Bled OOAP from 40 psi to 0 psi in 15 mins. Monitored for 30 mins, TP increased to 15 psi, IAP unchanged, OAP increased to 4 psi, OOAP increased to 1 psi. Final WHPs = 15/0/4/1. SV, WV = Shut. SSV, MV = Open. IA, OA, & OOA = OTG. NOVP. 6/12/2009 T/I/0=0/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Opened bleeder screw to verify 0 psi in void, bled to 0 psi. Removed internal check, installed Alemite external check. Functioned LDS, all moved freely (2"). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Opened bleeder screw to verify 0 psi in void, bled to 0 psi. Removed internal check, installed Alemite external check. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. No LDS on casing head. 6/14/2009 MIR 1 nn wPll MU WOT ~ 12S" Venturjjunk basket RIH to top of olug Tagged plua C«~ 9116' ctm. Work coil up and down cleaning off top of plug with max aump rate. POOH. Recovered 1/2 of bailer full of scale slabs that appear to have been scraped off the tubinq wall. RBIH with venturi junk basket. Tagged top of plug at 9116' ctmd. Reciprocated on top of plug. POOH. Recovered small amount of same scale. No marks on venturi. RIH with WRP pullinq tool. Sat down with 5 k# at 9119' ctmd. Could not latch plug. Attempt washina onto pluq. Could not latch, POOH. No marks on tools; Call out 7% HCL acid. RIH with 3.0" JSN assy. Acid on location held PJSM RIH Pumped acid at max rate 1 2hnm total acid pumqed 10.9 bbls 7% HCL, pumped 4.5 bbls on top of plug. POOH. Page 1 of 2 • • D-01A, Well History (Pre Rig Workover) Date Summary 6/15/2009 At surface with 3.0" nozzle. Pop off well. MU 4.5" WRP pulling tool. Open weII~,RIH with 4.5" WRP pullinq tool. Sat down Q 9119' ctm. Puh no latch. Pump fluid to wash top of plug, puh no plug. Hit down with jars, still could not latch. Tried several different stack weiahts on olua - could not latch plua. Pooh with 4.5" WRP pulling tool. MU and RIH with 3.77" venturi junk basket with tattle tail. Sat down on plug at 9118' ctmd. Wash on top of plug. POOH. Inspected junk basket shoe and found all tattle-tales broken and/or bent. Venturi recovery consisted of just the tattle-tale pins, no junk, no scale. RIH with larger OD (3.75") W RP fishinq tool with shorter skirt. Could not latch plug. POOH. MU same tool string (3.75") WRP without internal grapple. RIH to top of plug C«~ 9119' ctm, work WRP. No positive indication that the equalization sleeve has shifted. POOH. 6/16/2009 ,e00H with coil. At surface with tool strin9. Check tool strina, no marks. Perform weekly BOP test - passed. Decision made to rig down and allow slickline to attempt fishing plug. PU injector, go to well. RIH to 2000' ctm. FP with 50/50. Pooh with coil. RD CTU. 6/18/2009 T/I/0=0/260/50/80 Verification of W RP inteclrity post coil_ Pumped 6.7 bbls crude down tbg. T/IA pressured to 3000psi. T/IA lost 150/160 psi in 15 mins. Appears WRP was not equalized or ports are ~luqged post coil tbg work. Bled TxIA and slickline on location to RU. Pad-Op & PE notified upon departure. FWHP's = 0/260/50/80. SV & WV = Shut. SSV, MV, IA & OA = Open. 6/18/2009 WELL SHUT IN ON ARRIVAL. RAN 3.50" LIB TO TOP OF 4-1/2" WRP Q 9105' SLM. GOOD ~;~ IMPRESSION OF SHEAR STUD., CURRENTLY RUNNING WRP PULLWG TOOL W/O COLLETS TO `J EQUALIZE IN PROGRESS. 6/19/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/IA/OA/OOA=O/0/0/100. RIH WITH 3.66 MAX OD TOOL ~ STRING. TIED INTO TUBING TALLY DATED 6/2/1997. SET HES 4.5" FASDRILL CIBP AT 9135' IN THE MIDDLE OF THE OF THE FIRST PUP JOINT BELOW THE XN NIPPLE (9129'). CMIT TXIA TO 3500 PSI. 6/19/2009~ T/I/O/00=60/20/20/80 Temp= SI. Assist E-line. Pumped down Tbg with 35 bbls of 80°F crude to load for CMIT TxIA. 6/19/2009/'~~ PULLED 3.77" WRP C~ 9105' SLM. ALL ELEMENTS RECOVERED. DRIFTED TBG W/ 3.70" CENT & S `U~ BAILER, STOPPED C~ 9250' SLM. WELL LEFT SHUT IN, JOB COMPLETE. 6/20/2009 CMIT TXIA PASSED ON THIRD ATTEMPT. RIH WITH 3.65" MAX OD JET CUTTER. CUT 4-1/2" TUBING AT 9034' (TIED INTO TUBING TALLY DATED 6/2/1997) IN THE TOP OF THE FIRST FULL JOINT ABOVE THE PACKER. WELL LEFT SHUT IN ON DEPARTURE. FINAL T/I/O/00= 0/50/0/0. JOB COMPLETED. 6/20/2009 Assist E-line. CMIT TxIA PASSED to 3500 psi. Pressured up TxIA to 3500 psi with 69.6 bbls 80°F crude. T/IA lost 40/0 psi in the 1 st 15 mins and 0/20 psi in the 2nd 15 mins and 0/0 psi in the 3rd 15 mins for a total pressure loss of 40/20 psi in 45 min test. Bled T/IA, bled back 12 bbls. FWHP's = 80/110/20/80. Annulus casing valves tagged and left open to gauges upon departure. E-line on well at time of departure. 6/22/2009 T/I/O/00=0/0/40/80 Temp=S/I Circ ouUCMIT TxIA to 1000 psi (PASS) MIT OA to 2000 psi (PASSI Pumped 2 bbi neat meth spear, 580 bbl 1% KCI & 1 bbi neat meth, down TBG, up IA, down Poor Boy jumper to well #29 for Circ Out. Pumped 140 bbls 110° DSL down IA & U-tube IA to TBG. Pumped 5 bbls 80° DSL down Poor Boy to well #29 to flush surface line. CMIT TxIA/ Pumped 1.6 bbis DSL down TBG to bring TxIAP to test pressure. On 1st test, T/I lost 40/40 psi in ist 15 min & 20l20 psi in 2nd 15 min. Total Ioss of 60 psi in 30 min. Pass. MIT-OA/ Pumped 8.2 bbls DSL down OA to bring to test pressure. On 2nd test, OA loat 80 psi in ist 15 min & 40 psi in 2nd 15 min. Total loss of 120 psi in 30 min. Bled back 3.5 bbls from OA. Swab, Wing valves closed. SSV, Master, IA, OA, OOA valves open on departure. FWHP's= 0/0/0/0 Page 2 of 2 . • BP EXPLQRATIQN ' Page 1:ofi 5 Qperations Surnrnary R~port Legal Well Name: D-01A Common Well Name: D-O1A Spud Date: 5/15/1997 Event Name: WORKOVER Start: 6/28/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/7/2009 Rig Name: NABORS 4ES Rig Number: ~ Date From - To Hours Task Code NPT Phase aescription of Operations 7/2/2009 03:00 - 05:00 2.00 MOB P PRE Scope derrick in, Lower derrick over onto sub and secure. 05:00 - 07:00 2.00 MOB P PRE Unhook lines and prep rig for move to D-01. Spot Modules on the Pad for mobilizing. 07:00 - 09:00 2.00 MOB P PRE Move the Rig and all associated Modules from GPB J-Pad to GPB D-Pad. 09:00 - 10:00 1.00 RIGU P PRE Position the Rig on D-Pad and prepare the area around well slot D-01 for backing the Sub over. Spot the Camp. 10:00 - 14:00 4.00 RIGU P PRE Back the Sub over well slot D-01and jack up. Spot the Pipe Shed and Pits Modules. Move the Shop from GPB J-Pad to GPB D-pad. Raise and scope the Derrick at 1200 hrs. Spot the Shop and Gen Modules. Connect lines and power. 14:00 - 16:00 2.00 KILL P DECOMP RU double annulus valve on the IA. The Riq was acceoted at, 1400 hrs on 07/02/2009. Take on 120 degF seawater into the Pits. RU circulating lines to the Tree. The pressures on the annuli are IA = vac , OA = 150 psi. 16:00 - 17:00 1.00 WHSUR P DECOMP RU Lubricator with Drill Site Maintenance techs and pressure test it to 500 psi. Pull 4" Type "H" BPV. Tubing pressure = 10 psi. LD Lubricator. 17:00 - 18:00 1.00 KILL P DECOMP Level Sub and R/U Circulating lines. ' 18:00 - 18:30 0.50 KILL P DECOMP Crew change, service rig, set and test PVT's. 18:30 - 19:00 0.50 KILL P DECOMP Pressure test circulating lines to 3,500 psi. 19:00 - 21:00 2.00 KILL P DECOMP Circulate well out with 385 bbls of 120 degree seawater. 4 bpm with 830 psi initial circulating pressure, 4 bpm with 750 psi finial circulating pressure. 21:00 - 21:30 0.50 KILL P DECOMP Monitor well, 0 psi on IA and 0 psi on tubing. 21:30 - 23:30 2.00 WHSUR P DECOMP Install Cameron 4" T e"H" TWC with Cameron wellhead tech. Test from below to 1 000 psi for 10 minutes on the chart, test from above to 3 500 si for 10 minutes on the chart. 23:30 - 00:00 0.50 WHSUR P DECOMP N/D Adaptor flange and tree. 7/3/2009 00:00 - 01:00 1.00 WHSUR P DECOMP N/D Adaptor flange and tree. Inspect hanger threads. TDS threads in hanger are in good condition, 9-1/2 turns on TDS XO. Inspect LDS. Remove tree from cellar. The two barriers are the Fasdrill at 9,135' and the 4" Type "H" TWC. 01:00 - 04:00 3.00 BOPSU P DECOMP N/U Spacer spool and BOP stack, Hook up lines and turnbuckles. 04:00 - 05:00 1.00 BOPSU P DECOMP Remove 3-1/2" x 6" VBR's and install 2-7/8" x 5" VBR's. 05:00 - 06:00 1.00 BOPSU P DECOMP R/U BOP Test assemblies. 06:00 - 06:30 0.50 BOPSU P DECOMP Pre-tour checks and service the Rig. 06:30 - 07:30 1.00 BOPSU P DECOMP Finish RU test equipment. 07:30 - 12:30 5.00 BOPSU P DECOMP Pressure test BOPE per BP/AOGCC Regulations to 250 psi low and 3,500 psi high. The 2-7/8" x 5" VBR's were tested with 2-7/8" and 4-1/2" Test Joints. The Annular was tested with 2-7/8" Test Joint. The test was witnessed by the WSL and Toolpusher. The State's right to witness the test was waived by Bob Noble at 0500 hrs on 7/3/2009. There were no failures. 12:30 - 13:00 0.50 BOPSU P DECOMP PUMU Dutch system and Lubricator Extension. 13:00 - 14:00 1.00 WHSUR P DECOMP PUMU Lubricator with Drill Site Maintenance t h. T st tq 500 psi - OK. Pull 4" Type "H" TWC. The Tubing is on a vacuum. LD Lubricator and Dutch System Lubricator E~ension. 14:00 - 15:00 1.00 PULL P DECOMP PUMU Landing Joint, TIW and Hanger thread XO. Screw into the Hanger profile with 10-1/2 turns. PU power tongs to the Rig Floor. Printed: 7/29/2009 3:03:31 PM ~ • BP EXI ' Operations , , Legal Well Name: D-01 A Common Well Name: D-01A Page 2-c ~part Spud Date: 5/15/1997 Event Name: WORKOVER Start: 6/28/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/7/2009 Rig Name: NABORS 4ES Rig Number: Qate From - To I Hours Task Code NPT Phase Description of Operations 7/3/2009 ~ 15:00 - 16:00 ~ 1.00 I PULL ~ P 16:00 - 17:00 1.00 PULL P 17:00 - 18:00 1.00 PULL P 18:00 - 18:30 0.50 PULL P 18:30 - 20:00 1.50 PULL P 20:00 - 20:30 0.50 PULL P 20:30 - 00:00 3.50 PULL P 7/4/2009 00:00 - 01:00 1.00 PULL P 01:00 - 02:00 1.00 PULL P 02:00 - 03:30 1.50 PULL P 03:30 - 05:00 1.50 CLEAN P 05:00 - 06:00 1.00 CLEAN P 06:00 - 06:30 0.50 CLEAN P 06:30 - 12:00 5.50 CLEAN P 12:00 - 12:30 ~ 0.50 ~ CLEAN I P DECOMP Verify the IA is dead through 2" with Cameron rep. BOLDS. Pull the Hanoer off seat with PUW = 115K. Pull the Hanaer to the Floor with PUW = 110K. LD Hanger and Landing Joint. DECOMP Circulate bottoms up at a rate of 5.5 bpm / 550 psi. Pumped 235 bbls. RU Camco Spooling Unit. DECOMP UD 4-1/2" 12.6# -8 I with dual 1/4" control line. DECOMP Crew change, rig service, derrick inspection, set and test PVT's. DECOMP UD 4-1/2", 12.6#, L-80, IBT Completion with dual 1/4" control line. UD 52 jts, SSSV assembly, control line and 54 stainless steel bands. Heavy corrosion in pin area. DECOMP R/D control line spooler and remove from rig floor. DECOMP UD 4-1/2", 12.6#, L-80, IBT Completion. Heavy corrosion in pin area. DECOMP UD 4-1/2", 12.6#, L-80, IBT Completion. Heavy corrosion in pin area. Total of 212 joints of 4-1/2" tubing, cut joint 10.27' and 5 GLM's. DECOMP R/D 4-1/2" tubing handling equipment. DECOMP Clear and clean rig floor. Install 9-1/8" ID Wear bushing. CLEAN , BHA consists of Dress-Off Shoe, (4) Extensions, Inner Mill, Wash Over Boot Basket, XO, 7" Casing Scraper, XO, Bumper Sub, (9) 4-3/4" DC's. Total BHA Length = 315.36 CLEAN RIH with BHA #1 picking up 3-1/2" DP from pipeshed, CLEAN Pre-tour checks, set PVT and service the Rig. CLEAN Continue RIH with BHA #1 on 3-1/2" Drill Pipe ix1 from the Pipe Shed. In the hole with a total of 246 Joints of Drill Pipe (82 stands = 7660'). CLEAN PUMU 9-5/8" RTTS with SSCV with Halliburton reps. Pick up 3 more Joints of Drill Pipe (1 stand) from the Pipe Shed. Establish PUW = 127K and SOW = 110K. Set 9-5/8" RTTS with SSSV at -100' below the Rotarv Table. 12:30 - 13:00 0.50 CLEAN P CLEAN Pressure test the 9-5/8" RTTS from above to 1,500 psi for 10 charted minutes - aood test. 13:00 - 15:00 2.00 BOPSU P CLEAN Remove Flow Riser and ND BOPE and set back. The two barriers are the tested Fasdrill at 9,135' and the tested RTTS at 100'. 15:00 - 16:00 1.00 WHSUR P CLEAN Confirm the OA is dead through 2" line to the Tiger Tank. ND Tubinq Spool with Cameron rep. Prepare for installation of new s ool. 16:00 - 17:00 1.00 WHSUR P CLEAN NU new McEvoy SSH Tubing Spool with YB secondary packoff with Cameron rep. Energize it with plastic packing. 17:00 - 17:30 0.50 WHSUR P CLEAN Pressure test the Hanger void to 3,800 psi for 30 minutes with Cameron rep - good. 17:30 - 19:30 2.00 BOPSU P CLEAN Stab and NU BOPE and install Flow Riser. Test breaks to 250 psi low and 3,500 psi high pressures. Good tests 19:30 - 20:30 1.00 BOPSU P CLEAN Pull test plug and install wear bushing with 9-1/8" ID. 20:30 - 21:00 0.50 CLEAN P CLEAN P/U NES RTTS retrieval tool and latch into 9-5/8" RTTS. I no ressure underneath and release RTTS. Break and UD RTTS. 21:00 - 22:00 1.00 CLEAN P CLEAN Continue RIH with BHA #1 on 3-1/2" Drill Pipe 1x1 from the Pipe Shed. Tag up on top of tubing stub at 9,031' Printed: 7/29/2009 3:03:31 PM ~ • BP E}~PLOR,4TIQN Page 3:of 5 Qperation~ Summary Report Legal Well Name: D-01A Common Well Name: D-01A Spud Date: 5/15/1997 Event Name: WORKOVER Start: 6/28/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/7/2009 Rig Name: NABORS 4ES Rig Number: Date' Frc~m - To Hours Task Code NPT Phase Description of Operations 7/4/2009 22:00 - 23:00 1.00 CLEAN P CLEAN P/U Kelly, establish parameters, P/U 150K, S/O 120K, Rot Wt 135K, 60 rpm with 2,700 Wlbs of torque, 3-1/2 bpm with 270 psi. Wash over top of stub. dress 4-1/2" tubinp stub to 9.032'. 17' of swallow on assembly. Cleaned out to 9.049' on backside. Were able to slide over tubing stub without rotating or pumping. 23:00 - 00:00 1.00 CLEAN P CLEAN Pump 30 bbl high vis sweep around at 5-1/2 bpm with 670 psi. 7/5/2009 00:00 - 00:30 0.50 CLEAN P CLEAN Pump 30 bbl high vis sweep around at 5-1/2 bpm with 670 psi. Scale returns back with sweep. 00:30 - 04:00 3.50 CLEAN P CLEAN POOH with BHA #1 standing 3-1/2" DP in derrick. 04:00 - 05:00 1.00 CLEAN P CLEAN Stand back 4-3/4" DC's, break out and UD Dress-Off Assembly. 05:00 - 06:00 1.00 CLEAN P CLEAN Clear and clean rig floor, R/U handling equipment. 06:00 - 06:30 0.50 CLEAN P CLEAN Pre-tour checks, set PVT, service the Rig. 06:30 - 09:30 3.00 CLEAN P CLEAN Pl1MU BHA #2 with Baker Fishina rea as follows: 3-5/8" Junk Mill 8it Sub, 6 ea 3-1/8" PAC Drill Collars, 37 ea 2-7/8" PAC Drill Pi e, XO, Bumper Sub, Jars, 9 ea 4-3/4" Drill Collars, Pump Out Sub. OAL = 1606.71'. 09:30 - 12:30 3.00 CLEAN P CLEAN TIH with BHA #2 on 3-1/2" Drill Pipe from the Derrick. Stop just above the top of the Tubing Stump ~ 9,032' 4ESMD. 12:30 - 13:30 1.00 CLEAN P CLEAN Hold weekly safety meeting with the day crew. 13:30 - 14:00 0.50 CLEAN P CLEAN Continue RIH and slide into the Tubing Stump with no issues. Taq junk at 9,121'. 14:00 - 15:30 1.50 CLEAN P CLEAN PUMU a single Joint of DP and the Kelly and establish parameters: PUW = 143K , SOW = 115K , RW = 130K , 3 bpm / 700 psi , 80 RPMs with 3,000 ft-Ibs of torque (150 Amps). Get throuqh the junk at 9,121' with no problems. Taq top of the 4-1/2" Fasdrill at 9,127'. Mill the Fasdrill with 3-5K weight on mill and lose returns once it ot milled u. Rack back the Kelly and LD single that was picked up. 15:30 - 19:00 3.50 CLEAN P CLEAN Establish fill rate at 60 bbls er hour wit . RIH with stands of 3-1/2" Drill Pipe out of the Derrick to push the Fasdrill down the hole. Kelly up once we got to the perfs to continue to push the Fasdrill down the hole. Establish parameters: PUW = 163K , SOW = 115K , RW = 140K , 2 bpm / 170 psi (no returns) , 60 RPMs with 3,800 ft-Ibs of torque (180 Amps). 19:00 - 00:00 5.00 CLEAN P CLEAN POOH with BHA #2 la inq down 3-1/2" Drill pipe through pipeshed. Fill the hole at 60 bph plus pipe displacement with seawater. 7/6/2009 00:00 - 01:00 1.00 CLEAN P CLEAN POOH with BHA #2 laying down 3-1/2" Drill pipe through pipeshed. Fill the hole at 60 bph plus pipe displacement with seawater. 01:00 - 03:30 2.50 CLEAN P CLEAN UD 2-7/8" PAC DP and 3-5/8" Junk Mill Assembly. Fill the hole at 60 bph plus pipe displacement with seawater. 03:30 - 04:00 0.50 WHSUR P CLEAN Pull Wear Bushing. 04:00 - 05:00 1.00 CLEAN P CLEAN Hold weekly safety meeting with night crew, discuss BP and Nabors safety stats, emphasized personal and crew safety. 05:00 - 06:00 1.00 RUNCO RUNCMP Clear floor and RN handling equipment for running 4-1/2" 13Cr80 Vam To Com letion. 06:00 - 06:30 0.50 RUNCO P RUNCMP Pre-tour checks, service the Rig, set PVT. 06:30 - 07:30 1.00 RUNCO P RUNCMP Finish RU to run completion. RU Nabors Casing and Torque Turn equipment. Check completion jewelry with WSL and Printed: 7/29/2009 3:03:31 PM ~ • BP EXPLORATION Pag~, ~ of 5 Operations Summary Report Legal Well Name: D-01A Common Well Name: D-01A Spud Date: 5/15/1997 Event Name: WORKOVER Start: 6/28/2009 End: Contractor Name: NABORS ALASKA DRI LLING I Rig Release: 7/7/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase aescription af Operations 7/6/2009 06:30 - 07:30 1.00 RUNCO RUNCMP Baker Production rep. 07:30 - 17:00 9.50 RUNCO RUNCMP PUMU Jewelry BHA as follows: 7" x 4-1/2" Unique Machine Overshot, X Nipple with RHC, 7" x 4-1/2" Baker S-3 Production Packer and X Nipple. RIH with 4-1/2", 12.6#, 13Cr80, Vam Top Completion. MU all connections to 4,440 ft-Ibs torque with Torque Turn services. Utilizing Compensator and Jet Lube Seal Guard on all connections. Baker-Lok'd all connections below the Packer. 17:00 - 17:30 0.50 RUNCO P RUNCMP Establish PUW = 112K and SOW = 95K with 207 Joints of 4-1/2" Vam Top in the Hole. RIH with #208 and pick up #209. Observe the first set of brass shear ins o at 13' in on Joint u.,,,,, .,w...._._ .~- --___., ,.... ..~ w_...... .,~ ..... ..:.... .... .....,~ ... 17:30 - 18:30 I 1.001 RU 18:30 - 19:30 I 1.001 RU 19:30 - 20:30 1.00 R 20:30 - 21:30 1.00 R 21:30 - 23:30 I 2.00 I RU 23:30 - 00:00 0.50 7/7/2009 00:00 - 02:00 2.00 02:00 - 03:00 I 1.00 I WHSUR I P 03:00 - 05:00 I 2.001 BOPSUft P 05:00 - 06:00 1.00 WHSUR P 06:00 - 06:30 0.50 WHSUR P 06:30 - 08:00 1.50 WHSUR P 08:00 - 10:00 I 2.00 I WHSUR I P 10:00 - 11:00 1.00 WHSUR P 11:00 - 14:30 3.50 WHSUR P 9 032' with 23.5' in on Joint #209. Perform sqace out calculations - need 35' of pups for a 4' off bottom space out. RUNCMP Lay down Joint #209, #208 and #207. PU space out pups with lengths 2.07', 5.85', 9.96', 9.74' and 7.85'. P/U joint # 207. RUNCMP M/U 13" x 4-1/2" Cameron DX-2 MS / CCL Tubing Hanger. P/U 115K, S/O 96K. Land comqletion strinq and run in lock down screws, torque to 500 fUlbs. RUNCMP R/D 4-1/2" handling equipment and clear rig floor. RUNCMP Wait on truck with inhibited seawater, flat tire at the Pad 3 warehouse while taking on inhibitor. RUNCMP Reverse in 140 bbls of 120 degree seawater followed by 235 bbis of 120 degree seawater with Nalco EC1124A Corrosion Inhibitor mixed at 25 gallons per 100 bbis of seawater. 3 bpm at 550 psi RUNCMP Drop 1-7/8" Rod and Ball, R/D landina ioint and UD. . RUNCMP Pressure up on the tubing to set packer and test tubing. Pressure u to 3 500 si and hold for 30 minutes on the chart good test. Bleed tubin ressure to 1,500 si and lock in. Pressure u on the IA to 3,500 si for 30 minutes on the chart, good test. Bleed ressure off the tubin and shear the DCK valve, sheared at 2,700 psi differential. Line up and pump both ways through shear valve, 3 bpm at 1,100 psi. WHDTRE Set Cameron 4" Tvpe "H" TWC and test from above to 3,500 psi for 10 minutes on the chart, good test. Test from below to 1 000 ~si for 10 minutes on the chart. pood tesl WHDTRE Unhook lines, C/O rams to 7" rams. N/D BOP and set back on pedastal. Barriers for N/D are Rod and ball on seat with kill wt fluid, Set and tested packer, tested TWC in hanger. WHDTRE NU Adapter Flange with Cameron rep. WHDTRE Pre-tour checks, set PVT, service the Rig. WHDTRE Test Hanger void to 5,000 psi for 30 minutes - good test. NU 4-1/16" Tree and pressure test to 5,000 psi with diesel for 5 charted minutes - good test. WHDTRE Wait on Drill Site Maintenance techs to arrive on location. They were re-routed to DS 01 to help out Doyon 16 with a companion valve. WHDTRE RU Lubricator with Well Support Techs. Pressure test to 500 si - OK. Pull 4" T e"H" TWC. LD Lubricator. WHDTRE RU Little Red Services. Freeze protect the well by pumping 140 bbls of diesel down the IA taking returns up the Tubing. Printed: 7/29/2009 3:03:31 PM ~ • B'P EXPLQRATIQN Page 5 of 5 , Operations Summary R~port Legal Well Name: D-01A Common Well Name: D-01A Spud Date: 5/15/1997 Event Name: WORKOVER Start: 6/28/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/7/2009 Rig Name: NABORS 4ES Rig Number: Qate From - To Hours Task Code NPT Phase Description of ~peratit~ns 7/7/2009 11:00 - 14:30 3.50 WHSUR P WHDTRE Allow the diesel to U-Tube. 14:30 - 15:30 1.00 WHSUR P WHDTRE Set 4" Cameron Type "H" BPV and test to below for 10 minutes on the chart. Good test. 15:30 - 18:00 2.50 WHSUR P WHDTRE R/D circulating lines, N/D secondary annulus valve, secure tree and cellar. Rig released at 18:00 hours on 7/7/2009. Printed: 7/29/2009 3:03:31 PM 1 1\LL - 1.~1V V ~' /VElLHEFkD = MCEVOY 4CTkJATOR = BAKER C < . E1EV = 66.0' 3F. ELEV = 34.05' <OP = 3900' Vlax Angle = 86° @ 10308' ~atum MD = 9852' ~atum TV D = 8800' SS 16" STUB )" CSG, K55/H-40, 133# / 94#, ~D = 19.124" 1963' 2~447~ Minimum ID = 3.725" @ 9129' 4-1/2" HES XN NIPPLE 13-3/8" CSG, 68#, N-80, ID = 12.415" ~-i 4030~ D-01 A VA~ L. 1 1~~ V 1 VV . ~ V V V`W 1 V L I L. V V/1 ~ IAV ~ 1- 40 MIT-OOA 1200 PSI***CHROME TBG & NIP ***WELL ANGLE> 70° @ 9970'. 1 ? 7", 29# STR,4DDLEASSEMBLEY 1886~ 9-5/8" X 7" XO, ID =? 2221 ~ 4-1 /2" HES X NIP, ID = 3.813" ~ 2427~ 10-3/4" X 9-5/8" XO STUB - DEPTH UNKNOWN GAS LIFT MANDRELS iT MD ND DEV TYPE VLV LATCH PORT DATE 3 3892 3891 2 KGB-2 DOME BK 16 07/13/09 2 6407 6195 38 KGB-2 SO BK 20 07/13/09 1 8411 7791 30 KBG-2 DMY BK 0 07/06/09 $$97' ~-~4-1/2" HES X NIP, ID = 3.813" $J2$' ~~ 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" 4-1/2" TBG STUB (07/05/09) 17-1l2"X4-1/2" LNRTOP { I 9031' I I 9032' I 9138' PERFORATION SUMMARY REF LOG: SWS ON 05/29/97 ANGLE AT 70P PERF: 82° @ 10216' Note: Refer to Production DB for historical perf data S~ZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10216 - 10236 O 11/18/00 2-7/8" 4 10236 - 10246 O 10/27/00 2-7/8" 6 10236 - 10266 O 08/03/00 2-3/4" 4 10275 - 10340 C 05/30/97 PBTD I-~ 9894' 7" TBG, 26#, L-80, .0383 bpf, ID = 6.276" ~ 9940~ 9-5/8" CSG, 47#, N-80, ID = 8.68" 10089~ 8962~ I-14-1 /2" HES X NIP, ID = 3.813" 9046' -j 7" X 4-1/2" UNIQUE OVERSHOT ~ 9075~ 4 1/2" HES X NIP, ID = 3.813" J~86~ 7" X 4-1/2" BKR SB3 PKR, ID = 3.875" 9109~ 4 1/2" HES X NIP, ID = 3.813" g129~ 4 1/2" HES XN NIP, ID = 3.725" 9142~ 4 1/2" WLEG, ID = 3.958" 9136~ ELMD TT LOGGED 03/06/00 9152~ BAKER HMC HANGER TOP OF WHIPSTOCK @ 9228' MILLOUT WINDOW 9300' - 9315' 10272 FISH: FASDRILL PLUG PUSHm TO CIBP (07/05/09 10272 CIBP SET (03/08/00 PBTD ~~ 10586' 4 1/2" LNR, 12.6#, L-80 IBT, .0152 bpf, ID = 3.958" ~-~ 10668~ DATE REV BY COMMENTS DATE R~/ BY COMMENTS 03/07/70 ORtGINAL COMPLETION CW6.5 JLM SIDETRACKCOMPLETION 07/07/09 N4ES RWO 07/10/09 /SV DRLG HO CORRECTIONS 07/14/09 SEW/SV GLV GO 07/23/09 ?/JMD DRLG DRAFT CARRECTIONS PRUDHOE BAY UNIT WELL: D-01A PERMIT No: °~1970780 API No: 50-029-20054-01 SEC 23, T11 N, R13E, 2130' FNL & 1067' FEL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate_ ACID STIMULATION Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 58 feet 3. Address Exploratow___ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2130' FNL, 1067' FEL, Sec. 23, T11 N, R13E, UM (asp's 654096, 5958872) D-01A At top of productive interval 9. Permit number / approval number 3279' FNL, 3617' FEL, Sec. 23, T11 N, R13E, UM (asp's 651572, 5957670) 197-078 At effective depth 10. APl number 3615' FNL, 3833' FEL, Sec. 23, T11 N, R13E, UM (asp's 651363, 5957330) 50-029-20054-01 At total depth 11. Field / Pool 4003' FNL, 3813 FEL, Sec. 23, T11 N, R13E, UM (asp's 651390, 5956942) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10670 feet Plugs (measured) TD tagged 10270 CTMD (07/09/2002) true vertical 9072 feet CIBP set @ 10272 (03/08/2000) Effective depth: measured 10270 feet Junk (measured) true vertical 8991 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 84' 30" 250 sx PF 108' 108' Surface 2447' 20" 5500 sx 2470' 2470' Intermediate 4030' 13-3/8" 1600 sx Class 'G' 4054' 4045' Production 10089' 9-5/8" 2700 sx Class 'G' 10113' 8955' Liner 9940' 7" 200 sx Class 'G' 9964' 8902' Sidetrack Liner 1530' 4-1/2" 180 sx Class 'G' 9138' - 10668' 8416' - 9063' Perforation depth: measured Open Perfs 10216'- 10266', Perfs Below CIBP 10275'- 10340' true vertical Open Perfs 8976' - 8982', Perfs Below CIBP 8983' - 8988' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, TBG @ 9086' MD. Tubing Tail @ 9142' MD. Packers & SSSV (type & measured depth) 7"x 4-1/2" Baker SB3 Packer @ 9086' MD. ~!,_.:_II ¢i_ r~' ~'~)02_.., ,- . 4-1/2" HES HXO SSV @ 2212' MD. ~,,,.~,,, ~j & ..... ,., .... .. . 13. Stimulation or cement squeeze summary /~r.,chora,r, le Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or I niection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 07/05/2002 683 9380 1515 219 Subsequent to operation 07/11/2002 670 9164 845 276 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoi_ng is/~rue and correct to the best of my knowledge. Tit, : ,ssis,an, ate,u,,l,,,00, DeWayne R. Schnorr ¢', r~ , Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE D-OIA DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/0112002 ACID: AC-TIFL 07~07/2002 ACID: DRIFT/TAG 07/09/2002 ACID: ACID TREATMENT; IN]ECTIVITY TEST EVENT SUMMARY 07/O 1/02 T/I/O = 250/460/250/200 TEMP = 138 TIFL PASSED. PREP FOR ACID STIMULATION. IA FL @ 5350'. SI WELL AND IN 30 MINUTES TBG PRESSURE INCREASED TO 1900 PSI. IA REMAINED @ 460 PSI. LEFT WELL SI FOR 3.5 HOURS. WHP's = 2320/600/220/200. IA FL @ 5341' (NO CHANGE). DURING 3.5 HOURS THAT THE WELL WAS SI THE IA PRESSURE INCREASED 140 PSI TO 600 PSI. TWO WELLHEAD SAMPLES TAKEN TO DOWELL LAB. FINAL WHP's = 2320/600/220/200. 07/07/02 WELL FLOWING ON ARRIVAL. RAN 3.50" SWAGE. SAT DOWN @ 9055' SLM. RAN 3.48" LIB. SAT DOWN @ 9055'. RAN 3.50" TAPERED LIB. SAT DOWN @ 8988' SLM. METAL MARKINGS ON LIB'S. RIH W/2.50 DD BAILER WORKED DWN. TO 10125' SLM STOP DUE TO DEV. RDMO ( PRE ACID WASH ) PAD OP. WILL POP WELL 07/09/02 MIRU Unit #8. PRESSURE TEST ALL LINES AND LOAD AND KILL WELL. KILL WELL @ 4.5 BPM, PUMP 200 BBLS, LAST 50 BBLS PUMPED @ 250 PSI. RIH W/ 2.25" JSN. PERFORMED INJECTIVlTY TEST @ 4 BPM, 140 PSI, WELL ON VAC. LAY IN ACID FROM 8900' TO TAG (10,249'). JET 40 BBLS 12% DAD ACROSS PERFS FROM 10,200' TO TD. EACH PASS GOT A LITTLE DEEPER FINAL TAG @ 10270; CTMD. EVERY PASS ACROSS PERFS SEEMED TO HAVE CLEANER PU WEIGHTS AND RIH WEIGHT. PU TO 8900' AND JET REMAINING ACID BETWEEN 9150' AND 8900'. PUMPED 100 BBLS OVERFLUSH BETWEEN 8900 AND TD. WELL ON VAC. ACID TITRATION 12.4% HCL IRON < 50 PPM. POOH. RDMO. VECO TO RIG UP PBGL LINE AND WELL WILL BE POP'ed IN PM <<< JOB COMPLETED >>> FLUIDS PUMPED BBLS 1 DIESEL FOR SURFACE PRESSURE TEST 600 2% KCL WATER 75 12% DAD ACID 676 TOTAL Page 1 TREE= 4-1/2" 5M ClW :WFI LHEAD= rv'CEVOY ACTUATOR= BAKER KB. ELEV = 57.53' BF. ELEV = 34.05' .KOP = 390O' ~..M.....ax ..A...n_ 9._~..__~ .....__86 Datum MD = 9852' Datum TVD= 8800' SS 20" CSG, K55/H-40, 94#, ID= 19.124" H 2447' Minimum ID = 3.725 @ 9129' I I HES XN NIPPLE I 13-3/8"CSG, 68#,N-80, D=12.415" H 4030' D-01A SAFETY NOTES: PLUG @ 10272 2212' [--[4-1/2" HES HXO SSV I ~ LANDING NIP, ID = 3.813" I 9075' 9086' 9109' 9129' H H I-I H GAS LFT MANDRELS TYPE MA N I LA TCH J CA [Vl/ BTM CAM/ BTM CAM/ CAM/ 4 1/2" HES X NIP, ID = 3.813" 7" BKR SB3 PKI~ ID = 3.875" 4 1/2" HES X NIP, ID = 3.813" I 4 1/2" HES XN NP, ID = 3.725" I I 7-1/2"X4-1/2" LNRTOPH 9138' PERFORATION SUIVfCFk RY REF LOG: SWS ON 5-29-97 ANGLEATTOP PERF.' 83 @ 10238' Note: Refer to ProducUon DB for historical perf data SEE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10216-10236 O 11/13/00 2-7/8' 6 10236-10266 O 05/30/97 2-3/4" 4 10275-10340 C 05/30/97 2-7/8' 4 10216-10236 O 11/18/00 J9142' H 9136' J--~ 9152' H 4 1/2" TBG TAIL, WLEG I ELMD TT - LOGGED 3/6/00 J BAKER HMC HANGER I TOP OF WHPSTOCK @ 9228' MLLOUT WINDOW 9300' - 9315' 10272 H CIBP, SET 3-8-00 J I PBTD H 9894' I 7" TBG, 26¢¢, L-80, .0383 bpf, ID= 6.276" H 9940' J 9-5/8"0SG, 47#, N-80, ID =8.68" H 10089' 1 O586' 4 1/2" LNR, 12.6/~, L-80, .0152 bpf, ID = 3.958" DATE REv' BY COMIVENTS 03/07/70 ORIGINAL COIVPLETION 08/07/97 JLM SIDEFRACK COMPLETION 12/13/00 SiS-QAA CONVERTED TO CANVAS 02/07/01 SIS-MD REVISION 03/28/01 RNFYP CORRECTIONS 10668' [ PRUDHOE BAY UNIT WELL: D-01A PERMrr No: 97-0780 AR No: 50-029-20054-01 Sec. 23, T11N, R13E BP Exploration (~Ala~) __ ~,) -i D~ll~_ ON OR BEFORE ANUARY 03 2001 W C:LOP, IkM~ ~I~M-DO C ...... STATE OF ALASKA - ALASKA ,~IL AND GAS CONSERVATION C~,.,~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Operation Shutdown [] Stimulate [] Plugging [] Pull Tubing []Alter Casing [] Repair Well [] Other 5. Type~ well: Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 2130' SNL, 1067' WEL, Sec 23, T11N, R13E, UPM At top of productive interval 3279' SNL, 3617' WEL, Sec 23, T11N, R13E, UPM At effective depth At total depth 4003' SNL, 3813' WEL, Sec 23, T11N, R13E, UPM [] Perforate Acid 6. Datum Elevation (DF or KB) KBE = 57.53 feet 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-01A 9. Permit Number / Approval No. 97-0780 10. APl Number 50- 029-20054-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 10670' BKB 9O72' 10580' BKB 9O47' feet feet feet feet Plugs (measured) Junk (measured) KOP (window) @ 9300' - 9315'. 7" abandoned from 9300' to 9940'. 9-5/8" abandoned from 9300' to 10089'. 4-1/2" CIBP set @ 10272' (03/08/00) Length Size Cemented Structural Conductor 84' 30" 250 sx PF Surface 2447' 20" 5500 sx Intermediate 4030' 13-3/8" 1600 sx Class 'G' Production 10089' 9-5/8" 2700 sx Class 'G' Liner 9940' 7" 200 sx Class 'G' Sidetrack Liner 1530' 4-1/2" 180 sx Class 'G' MD TVD BKB 108' 108' 247O' 2470' 4054' 4045' 10113' 8955' 9964' 8902' 9138'-10668' 8416'-9063' Perforation depth: measured Open Perfs 10216' - 10266' Below CIBP 10275' - 10340' true vertical Open Perfs 8976' - 8982' Below CIBP 8983' - 8988' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 tubing to 9086' with 4-1/2" tailpipe to 9142'. Packers and SSSV (type and measured depth) 7" BKR SB3 Packer @ 9086'. 4-1/2" HES HXO SSV @ 2212'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed ScottLaVoie ~_ v~ t~'~~ Title TechnicalAssistant Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Date ~'/,~/~/' ~. Submit In Duplicate~ D-OIA DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/04/2001 ACID: TIFL FOR STIMULATION PREP 01/06/2001 ACID: CT ACID TREATMENT SUMMARY 01/04/01 PERFORM TIFL FOR STIMULATION PREP. PASSED INFLOW. 01/06/01 RIH AND TAG AT 10,220 (CTM). INJECTIVITY TEST- WHP-850 AT 1B/M. PUMP 56 BBLS 12% DAD ACID. WHP DECREASED AS ACID HIT THE PERFS--DEFINITE INDICATION OF STIMULATION. NEW TAG: 10,235' (CTM). OVERFLUSH W/150 BBLS 2% KCL. FREEZE PROTECT TOP OF WELL W/ 60/40 METH. ***NOTIFY PCC AND OPERATOR TO POP*** Fluids Pumped , BBLS. Description 303 303 BBLS 2 % KCL 75 75 BBLS MEOH 60 60 BBLS ACID WITH: 12% H36 HYDROCHLORIC ACID 10% A-26 XYLENE 1.5% U-74 DISPERSANT 0.6% A-261 CORROSION INHIBITOR 8 PPT A-153 INHIBITOR AID 40 PPT L-41 INHIBITOR AID 1% W-54 ANTI-SLUDGE 0.7% W-35 ANTI-SLUDGE 0.3 % F-103 SURFACTANT 20 PPT L-58 ORION STABILIZER 438 TOTAL MEMORANDUM State of Alaska Alaska Oii and Gas Conservation Commission TO: THRU: Julie Heusser, ~ ~,~ ~ Commissioner ~.-' Tom Maunder, P. i. Supervisor ,~,(.~.-O ~. DATE: April 20, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit D Pad Friday, A~)ril .2.0, 200!; I traveled to BPXs D Pad and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 20 wells and 40 components with 1 failure. The surface safety valve on well D,06 had a slow leak when pressure tested. This valve was serviced and the retest witnessed on this date. Merv Liddlow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in fair conditions. Summary:. I witnessed the semi annual SVS testing at BPXs D-Pad. PBU D Pad, 20 wells, 40 components, 1 failure 2.5% failure rate 25 wellhouse inspections Attachment: SVS PBU D Pad 4-20-01 CS ,, X, Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU D Pad 4-20-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Prudhoe/PBU / D Pad Separator psi: LPS 154 Date: 4/19 & 4/20 HPS 660 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI , PSI Trip Code Code Code Passed GAS orCYCLE D-01A 1970780 154 125 125 P P OIL , , D-03A 2001340 154 125 125 p P OIL D-04A 1871250 D-05 1700060 660 550 450 p p ' 'oIL' , D-06A 1970430 660 550 600 P 4 OIL D207A 1931570 660 550! 525 P P 4/20/0'1 OIL , D-08 1790360 D-09A 1990850' 660 550 525 p P OIL D-10 17905301 660 550 5'25 p P ' OIL D-11A 1951830: 660 550 525 p p OIL , , D-12 1800150 660, 550 530 P P OIL D-13A 2000810 ~ i . D-14A 1961530 , D-15A 1972120 D-16 1811710 660 550 500 p P OIL D-17A 1960460 D-18 1811880 " , D-20 1820440 154 125 120 p P OIL ,, D-21 1820520 154 125 125 p P OIL D-22~ 1972040 D-23A 1961880 660 550 525 p P ' OIL , , D-24 1852990 D-25A 2000240 154 125 100 P P OIL D-26A 1970870 660 550 525 p P OIL D-27 1860330 660 550 550 p P OIL , D-28A 1952130 660 550 550 P p OIL D-29 1852530 154 125 110 p P OIL ,, D-30 1960260 D-31A 1960950! 660 550 550 '~ e OIL D-33 196036'0! 660 5501 550 P e OIL , RJF 1/16/01 Page 1 of 2 SVS PBU D Pad 4-20-01 CS Wen v~'~it'l s~P~I set ! L/P I Test I Test I ! Date Number Number ] PSI ] PSI ] Trip ] Code ] Code ] Code ] Passed Wells: ~-20 Components: 40 Failures: 1 Failure Rate: . GAS or CYCLE 2.50% F'loo Day Remarks: The surface safety valve on well D-6 had slow leak when_ pressure tested. Valve was serve, ~ceA and retested same day RJF 1/16/01 Page 2 of 2 SVS PBU D Pad 4-20-01 CS PERMIT 97-078 97-078 97-078 97-078 97-078 97-078 97-078 97-078 97-078 97-078 97-078 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS ............................ NGP/DGR/EWR4-MD ~9~41-10670 NGP-DGR/EWR4 - TVD ~8598-9072 8083 '~SPE~RY GR/EWR4/ROP pEX-CN 9304-10624.9 BHC/SL /9304-10608.4 PEX-AIT ~? 9304-10650.1 PEX-SSTVD ~ 9304-10650.1 PEX-BH PROF ~9304-10650.1 7805 ~HLuM PEX-AIT/BHC MWD SRVY R SPERRY 0-8280 97-078 MMS SRVY R SPERRY 0-3970 97-078 MWD SRVY R SPERRY 9208.42-10670 10-407 'R/COMPLETION DATE @ ~/~/ /~// DAILY WELL OPS R @J~//~/~2/ TO ~/~ ~/ Are dry ditch samples required? yes no And received? Was the well cored? yes no Are well tests required? yes Well is in compliance Initial COMMENTS yes Analysis & description received? no Received? yes no Page: 1 Date: 05/24/99 RUN RECVD FINAL 09/03/97 FINAL 09/03/97 2-4 09/03/97 FINAL 09/11/97 FINAL 09/11/97 FINAL 09/11/97 FINAL 09/11/97 FINAL 09/11/97 FINAL 09/11/97 1 09/11/97 08/29/97 08/29/97 SPERR 09/29/97 no yes no T D BOX -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas E~ Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-78 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20054-01 4. Location of well at surface.._~.,~,~. 9. Unit or Lease Name 2130' SNL, 1067' WEL, SEC. 23, T11N, R13E, UPM ~,~ ................... ,Sr!t,.i.:..! r.i~:r ~ ~ ~~~ Prudhoe Bay Unit At top of productive interval ~, __/~/~ j ~ , 10. Well Number 3279' SNL, 3617' WEL, SEC. 23, T11N, R13E, UPM i .~_~;/_~;"~ I D-01A At total depth 11. Field and Pool 4003' SNL, 3813' WEL, SEC. 23, T11N, R13E, UPM ~ ........... i ~ ~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Desig~t~[~n~a~r~'d'S'e~ial No. Pool KBE = 65.95'I ADL 028285 12. Date Spudded5/25/97 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if OffshOre 116' NO' Of COmpletiOns5/28/97 6/4/97 N/A MSL, One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 10670 9072 FTI 10580 9047 FTI []Yes [--]No (Nipple) 2213' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, DIP, 4-Phase RES, AlT, CDL, CNL, DLL, MLL, DEN, Sonic 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO~-I-OM SIZE CEMENTING RECORD AMOUNT PULLED See Attached 24. Perforations open to Production (MD+TVD of Top and 125. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9142' 9086' MD TVD MD TVD 10275' - 10340' 8992' - 8997' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 130 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) June 21, 1997I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL 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. ORIGINAL , Ar~chora~- 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. Top of Sadlerochit Above KOP N/A Zone 3 9660' 8793' Zone 2C 9843' 8862' CGOC 9971' 8912' 25N 10022' 8930' POWC 10341' 8997' !31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that t~e'"~oreg~and correct to the best of my knowledge Signed DanStoltz ~(y~///~,/t~~J / '=A~7~ Title Senior Drilling Engineer Date D-01A 97-78 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number 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 WELL NAME: D-01A 23. Attachment - Casing, Liner and Cementing Record Casing ~ Hole Size Wt. Per Ft Grade Top Bottom Size Cementing Record 30" Stove Pipe Surface 84' .36" 250 Sx PF 20" 133#/94#K-55/H-413SurfacE 2447' 26" 5500 sx PF refrigeration (originally Surface - 16" , 65# H-40 . 1963' . 22001 ........ N!A ......... 22.0.0') .......................................................................... . 13-3/8" 68#/61# K-55 Surface 4030' 17-1/2" 1600 Class 'G' 10-3/4" 55.5# N-80 2000' 2427' 12-1/4"See Below · . , 9-5/8" 47# N-80 2427' 9298' 12-1/4"2700 sx Class 'G' 9-5/8" 47# L-80 Surface 1886' 12-1/4"iSee Below 7" 26# L-80 1867' 9298' N/A 200 sx Class 'G' 7" 29# L-80 1684' 1881' N/A Straddle PackerAssembly 4-1/2" 12.6# L-80 9138' 10668' 6" 180 sx Class'G Facility Date/Time 17 May 97 18 May 97 19 May 97 20 May 97 21 May 97 22 May 97 Progress Report PB D Pad Well D-01A Page 1 Rig Doyon 141 Date 22 July 97 20:00-06:00 06:00-06:15 06:15-07:15 07:15-00:00 00:00-00:30 00:30-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-07:00 07:00-08:00 08:00-12:00 12:00-12:30 12:30-16:00 16:00-16:30 16:30-18:30 18:30-00:00 00:00-00:30 00:30-02:00 02:00-05:30 05:30-06:00 06:00-06:30 06:30-09:00 09:00-10:00 10:00-12:00 12:00-12:30 12:30-13:30 13:30-15:00 15:00-20:00 20:00-00:00 00:00-00:30 00:30-02:00 02:00-06:00 06:00-09:30 09:30-10:00 10:00-10:30 10:30-11:30 11:30-18:00 18:00-22:00 22:00-23:00 23:00-00:00 00:00-00:30 00:30-06:00 06:00-07:00 07:00-08:00 08:00-09:30 09:30-12:00 12:00-12:30 12:30-13:30 13:30-15:30 15:30-19:00 19:00-21:30 21:30-22:00 22:00-23:30 Duration 10hr 1/4 hr lhr 16-3/4 hr 1/2 hr 2-1/2 hr lhr lhr lhr lhr lhr 4hr 1/2 hr 3-1/2 hr 1/2 hr 2hr 5-1/2 hr 1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr lhr 2hr 1/2 hr lhr 1-1/2 hr 5hr 4hr 1/2 hr 1-1/2 hr 4hr 3-1/2 hr 1/2 hr 1/2 hr lhr 6-1/2 hr 4hr lhr lhr 1/2hr 5-1/2 hr lhr lhr 1-1/2 hr 2-1/2 hr 1/2 hr lhr 2hr 3-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr Activity Rigged down Drillfloor / Derrick Rigged down Drillfloor / Derrick (cont...) Rig waited: Other delays Rig moved 100.00 % Held safety meeting Rigged up Rig services Fill pits with Seawater Held safety meeting Rigged up Surface lines Rigged up Surface lines (cont...) Retrieved Hanger plug Circulated at 9370.00 ft Held safety meeting Circulated at 9370.00 ft Installed Hanger plug Rigged down Xmas tree Rigged up BOP stack Held safety meeting Rigged up BOP stack Tested BOP stack Rigged up Lubricator Removed Hanger plug Rigged up Tubing handling equipment Circulated at 9370.00 ft Laid down 1286.00 ft of Tubing Held safety meeting Laid down 583.00 ft of Tubing Rigged up Tubing handling equipment Laid down 3236.00 ft of Tubing Rigged up Bottom ram Held safety meeting Made up BHA no. 1 R.I.H. to 5101.00 ft Pulled out of hole to 204.00 ft Pulled BHA Rigged up Tubing handling equipment Held safety meeting Laid down fish Conducted electric cable operations Tested Casing Made up BHA no. 2 Held safety meeting R.I.H. to 9320.00 ft Circulated at 9320.00 ft Mixed and pumped slurry - 22.000 bbl ~ Reverse circulated at 9318.00 ft Pulled out of hole to 3570.00 ft Held safety meeting Set Retrievable packer at 40.00 ft with 500.0 Rigged down BOP stack Rigged up Tubing head spool Rigged up BOP stack Tested BOP stack Pulled out of hole to 40.00 ft Facility Date/Time 23 May 97 24 May 97 25 May 97 26 May 97 27 May 97 28 May 97 PB D Pad Progress Report Well D-01A Rig Doyon 141 Page Date Duration Activity 23:30-00:00 00:00-00:30 00:30-03:30 03:30-06:00 06:00-09:30 09:30-11:30 11:30-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-03:30 03:30-04:00 04:00-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-11:00 11:00-12:00 12:00-12:30 12:30-14:30 14:30-15:00 15:00-16:00 16:00-19:30 19:30-21:00 21:00-00:00 00:00-00:30 00:30-02:00 02:00-06:00 06:00-06:30 06:30-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-01:00 01:00-03:00 03:00-06:00 06:00-07:00 07:00-08:30 08:30-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-02:00 02:00-05:00 05:00-06:00 06:00-10:30 10:30-12:00 12:00-12:30 12:30-14:00 14:00-18:30 18:30-00:00 00:00-00:30 00:30-06:00 06:00-11:30 1/2 hr 1/2 hr 3hr 2-1/2 hr 3-1/2 hr 2hr 1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 3hr 1/2 hr 2hr lhr lhr lhr 2hr lhr 1/2 hr 2hr 1/2 hr lhr 3-1/2 hr 1-1/2 hr 3hr 1/2 hr 1-1/2 hr 4hr 1/2 hr 5-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 2hr 3hr lhr 1-1/2 hr 3-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr 3hr lhr 4-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 4-1/2 hr 5-1/2 hr 1/2 hr 5-1/2 hr 5-1/2 hr Pulled BHA Held safety meeting Made up BHA no. 3 R.I.H. to 4485.00 ft R.I.H. to 9320.00 ft (cont...) Circulated at 9298.00 ft Milled Casing at 9300.00 ft Held safety meeting Milled Casing at 9322.00 ft Held safety meeting Milled Casing at 9328.00 ft Circulated at 9328.00 ft Pulled out of hole to 5675.00 ft Pulled out of hole to 929.00 ft (cont...) Pulled BHA Made up BHA no. 4 R.I.H. to 5052.00 ft Serviced Block line Held safety meeting R.I.H. to 9328.00 ft Drilled to 9335.00 ft Circulated at 9335.00 ft Pulled out of hole to 902.00 ft Pulled BHA Made up BHA no. 5 Held safety meeting Made up BHA no. 5 R.I.H. to 9320.00 ft R.I.H. to 9335.00 ft (cont...) Drilled to 9515.00 ft Held safety meeting Drilled to 9781.00 ft Held safety meeting Drilled to 9802.00 ft Circulated at 9802.00 ft Pulled out of hole to 1658.00 ft Pulled BHA Made up BHA no. 6 R.I.H. to 9802.00 ft Held safety meeting Drilled to 10121.00 ft Held safety meeting Circulated at 10121.00 ft Pulled out of hole to 2034.00 ft Pulled BHA Tested BOP stack Made up BHA no. 7 Held safety meeting Made up BHA no. 7 R.I.H. to 10121.00 fl Drilled to 10304.00 ft Held safety meeting Drilled to 10440.00 ft Drilled to 10670.00 ft (cont...) 2 22 July 97 Facility Date/Time 29 May 97 30 May 97 31 May 97 01 Jun 97 Progress Report PB D Pad Well D-01A Page 3 Rig Doyon 141 Date 22 July 97 11:30-12:00 12:00-12:30 12:30-13:30 13:30-18:00 18:00-19:00 19:00-21:00 21:00-00:00 00:00-00:30 00:30-02:30 02:30-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-10:00 10:00-12:00 12:00-12:30 12:30-13:00 13:00-15:30 15:30-18:30 18:30-20:30 20:30-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-04:00 04:00-06:00 06:00-12:00 12:00-12:30 12:30-14:00 14:00-14:30 14:30-15:30 15:30-16:00 16:00-17:00 17:00-17:15 17:15-18:00 18:00-18:30 18:30-21:30 21:30-22:00 22:00-00:00 00:00-00:30 00:30-02:00 06:00-07:30 07:30-08:00 08:00-12:00 12:00-12:30 12:30-13:00 13:00-13:30 13:30-14:30 14:30-17:00 17:00-21:00 21:00-23:30 23:30-00:00 00:00-01:00 Duration 1/2 hr 1/2 hr lhr 4-1/2 hr lhr 2hr 3hr 1/2 hr 2hr lhr 1/2 hr lhr lhr 4hr 2hr 1/2 hr 1/2 hr 2-1/2 hr 3hr 2hr 3-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 2hr 6hr 1/2 hr 1-1/2 hr 1/2 hr lhr 1/2 hr lhr 1/4 hr 3/4 hr 1/2 hr 3hr 1/2 hr 2hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 4hr 1/2 hr 1/2 hr 1/2 hr lhr 2-1/2 hr 4hr 2-1/2 hr 1/2 hr lhr Activity Circulated at 10670.00 ft Held safety meeting Circulated at 10670.00 ft Logged hole with LWD: Formation evaluation (FE) from 10670.00 ft to 9585.00 ft R.I.H. to 10670.00 ft Circulated at 10670.00 ft Pulled out of hole to 4060.00 ft Held safety meeting Pulled out of hole to 2213.00 ft Pulled BHA Held safety meeting Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations (cont...) Circulated at 9080.00 ft Held safety meeting Conducted electric cable operations R.I.H. to 10660.00 ft Ran logs on tubulars Conducted electric cable operations Pulled out of hole to 0.00 ft Held safety meeting Rigged up Casing handling equipment Held safety meeting Ran Liner to 1539.00 ft (4-1/2in OD) Ran Tubing to 1451.00 ft (2-7/8in OD) Ran Liner in stands to 7333.00 ft Held safety meeting Ran Liner in stands to 9211.00 ft Circulated at 9211.00 ft Ran Liner in stands to 10646.00 ft Washed to 10670.00 ft Batch mixed slurry - 37.000 bbl Pumped Seawater spacers - volume 70.000 bbl Displaced slurry - 69.400 bbl Functioned Liner hanger Circulated at 10586.00 ft Tested Casing Circulated at 10586.00 ft Held safety meeting Circulated at 10586.00 ft Laid down 1000.00 ft of Tubing Removed Wear bushing Repaired DV collar Held safety meeting R.I.H. to 1881.00 ft Circulated at 1862.00 ft Pulled out of hole to 0.00 ft R.I.H. to 1878.00 ft Tested Straddle / pack off tool Tested Casing Pulled out of hole to 900.00 ft Pulled out of hole to 0.00 ft Facility Date/Time 02 Jun 97 03 Jun 97 04 Jun 97 PB D Pad Progress Report Well D-01A Rig Doyon 141 Page Date Duration Activity 01:00-02:00 02:00-03:30 03:30-04:30 04:30-05:00 05:00-06:00 06:00-08:00 08:00-09:00 09:00-10:30 10:30-11:00 11:~30-12:00 12:00-12:30 12:30-15:30 15:30-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-00:00 00:00-00:30 00:30-06:00 06:00-08:30 08:30-09:00 09:00-09:30 09:30-10:00 10:00-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-19:00 19:00-19:30 19:30-20:30 20:30-21:30 21:30-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-02:00 02:00-02:30 02:30-05:30 05:30-06:00 06:00-06:30 06:30-12:00 12:00-12:30 12:30-17:00 17:00-18:00 18:00-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-02:30 02:30-03:00 03:00-06:00 1/2 hr 6hr 1/2 hr lhr lhr 2hr 1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 3hr 1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 4-1/2 hr lhr 4-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 3hr Tested Casing R.I.H. to 1913.00 ft Tested Casing Pulled out of hole to 1790.00 ft Tested Casing Tested Casing (cont...) Pulled out of hole to 0.00 ft R.I.H. to 1892.00 ft Tested Casing Tested Casing Held safety meeting Tested Casing Tested Casing Pulled out of hole to 0.00 ft Rigged up Tubing handling equipment Held safety meeting Space out tubulars Held safety meeting Ran Drillpipe in stands to 8000.00 ft Ran Drillpipe in stands to 10561.00 ft (cont...) Space out tubulars Held safety meeting Tested High pressure lines Perforated from 10275.00 ft to 10340.00 ft Reverse circulated at 8806.00 ft Circulated at 8806.00 ft Held safety meeting Flow check Laid down 7806.00 ft of 3-1/2in OD drill pipe Serviced Draw works Laid down 8806.00 ft of Drillpipe Retrieved Retrievable packer Laid down 1470.00 ft of Drillpipe Held safety meeting Held safety meeting Ran Drillpipe in stands to 752.00 ft Serviced Block line Laid down 751.00 ft of Drillpipe Installed BOP stack Rigged up Handling equipment Held safety meeting Ran Tubing to 2022.00 ft (4-1/2in OD) Held safety meeting Ran Tubing to 6930.00 ft (4-1/2in OD) Installed SCSSSV nipple assembly Ran Tubing to 9142.00 ft (4-1/2in OD) Space out tubulars Circulated at 9132.00 ft Held safety meeting Circulated at 9132.00 ft Ran Tubing on landing string to 32.00 ft Set packer at 9085.00 ft with 4000.0 psi Tested Hanger plug Removed BOP stack 4 22 July 97 Facility Date/Time PB D Pad Progress Report Well D-01A Rig Doyon 141 Page Date Duration Activity 06:00-07:00 07:00-08:00 08:00-09:00 09:00-12:00 12:00-t4:30 14:30-16:00 lhr lhr lhr 3hr 2-1/2 hr 1-1/2 hr Removed BOP stack (cont...) Rigged up Adapter spool Installed Xmas tree Tested Permanent packer Circulated at 3309.00 ft Functioned Equalising plug 5 22 July 97 RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING PBU / D-01A 500292005401 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 PAGE DATE OF SURVEY: 052897 MWD SURVEY JOB NUMBER: AK-MW-70111 KELLY BUSHING ELEV. = 65.95 FT. OPERATOR: BP EXPLORATION 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. 9208.42 8486.43 8420.48 9322.00 8586.41 8520.46 9331.61 8594.85 8528.90 9363.49 8622.11 8556.16 9395.56 8648.20 8582.25 28 22 28 16 28 53 33 35 37 35 N 88.09 W .00 N 87.09 W .43 N 75.80 W 56.51 N 66.60 W 20.98 N 58.80 W 18.85 1124.96S 2105.07W 1122.69S 2158.92W 1122.01S 2163.45W 1116.61S 2179.03W 1108.01S 2195.56W 2240.87 2275.03 2277.53 2283.88 2288.46 9427.84 8673.00 8607.05 42 0 9458.95 8695.38 8629.43 46 12 9492.16 8717.30 8651.35 51 17 9524.48 8736.25 8670.29 57 0 9556.49 8752.54 8686.58 61 47 N 52.40 W 18.61 N 64.20 W 29.60 N 74.60 W 28.08 N 83.30 W 28.03 N 83.70 W 15.03 1096.31S 2212.55W 1085.05S 2230.95W 1076.37S 2254.28W 1071.43S 2279.95W 1068.31S 2307.32W 2291.05 2294.89 2303.95 2317.36 2333.25 9588.15 8766.37 8700.42 66 24 9617.43 8777.41 8711.46 69 18 9651.73 8789.13 8723.18 70 48 9683.99 8799.72 8733.77 70 54 9715.21 8810.81 8744.86 67 30 N 87.50 W 18.10 S 86.50 W 21.41 S 79.30 W 20.21 S 72.50 W 19.91 S 67.90 W 17.56 1066.15S 2335.70W 1066.40S 2362.80W 1070.39S 2394.77W 1077.81S 2424.31W 1087.68S 2451.76W 2350.53 2368.76 2393.02 2418.22 2443.86 9747.24 8823.84 8757.89 64 30 9778.51 8837.04 8771.09 65 35 9810.73 8849.75 8783.80 68 0 9842.03 8861.75 8795.80 66 54 9873.57 8874.58 8808.63 65 5 S 63.20 W 16.35 S 58.10 W 15.20 S 51.10 W 21.31 S 51.50 W 3.71 S 52.70 W 6.68 1099.77S 2478.39W 1113.67S 2503.08W 1130.82S 2527.19W 1148.89S 2549.75W 1166.59S 2572.48W 2470.61 2497.42 2526.27 2554.77 2583.11 9904.84 8887.63 8821.68 65 35 9938.16 8900.77 8834.82 68 0 9969.51 8911.96 8846.00 70 11 10001.85 8922.80 8856.85 70 35 10032.53 8933.50 8867.55 68 35 S 46.20 W 18.96 S 40.20 W 18.05 S 35.30 W 16.20 S 34.10 W 3.71 S 30.30 W 13.31 1185.06S 2594.06W 1207.38S 2615.00W 1230.53S 2632.91W 1255.57S 2650.26W 1279.90S 2665.58W 2611.26 2641.85 2671.05 2701.29 2729.64 10065.99 8946.22 8880.27 66 41 10085.54 8953.81 8887.86 67 35 10119.73 8965.50 8899.55 72 24 10153.15 8974.24 8908.29 77 18 10183.17 8979.96 8914.01 80 41 S 29.80 W 5.84 S 29.40 W 4.97 S 29.10 W 14.06 S 28.80 W 14.69 S 26.40 W 13.78 1306.68S 2681.08W 1322.34S 2689.98W 1350.37S 2705.67W 1378.59S 2721.28W 1404.70S 2734.92W 2759.94 2777.55 2808.91 2840.36 2868.93 10213.21 8984.54 8918.58 10245.84 8988.74 8922.79 10276.40 8991.78 8925.83 10308.03 8994.23 8928.28 10340.91 8996.99 8931.04 81 48 83 24 85 11 85 54 84 30 S 23.00 W 11.77 S 16.90 W 19.18 S 12.60 W 15.19 S 8.80 W 12.18 S 3.60 W 16.32 1431 . 67S 2747 . 33W 1462 . 07S 2758.36W 1491 . 47S 2766 . i0W 1522.45S 2771.95W 1555 . 01S 2775 . 49W 2897.31 2927.34 2954.43 2981.44 3008.09 S IRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING PBU / D-0iA 500292005401 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052897 MWD SURVEY JOB NUMBER: AK-MW-70111 KELLY BUSHING ELEV. = 65.95 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 10371.77 9000.64 8934.69 81 54 S 1.20 W 11.43 1585.62S 2776.77W 10401.66 9005.29 8939.34 80 11 S 2.80 E 14.39 1615.14S 2776.36W 10433.43 9011.33 8945.38 77 54 S 5.40 E 10.81 1646.24S 2774.14W 10464.16 9017.85 8951.90 77 35 S 6.20 E 2.73 1676.12S 2771.10W 10496.11 9025.03 8959.08 76 24 S 6.90 E 4.32 1707.05S 2767.55W 3031.79 3053.54 3075.27 3095.54 3116.25 10528.09 9033.01 8967.06 74 41 S 7.10 E 5.35 1737.78S 2763.78W 10560.41 9041.57 8975.62 74 35 S 7.60 E 1.52 1768.69S 2759.79W 10591.64 9049.99 8984.04 74 5 S 7.60 E 1.60 1798.50S 2755.81W 10611.35 9055.41 8989.46 74 0 S 7.70 E .70 1817.28S 2753.29W 10670.00 9071.72 9005.77 73 41 S 8.00 E .71 1873.09S 2745.60W 3136.67 3157.09 3176.68 3189.01 3225.53 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3323.67 FEET AT SOUTH 55 DEG. 41 MIN. WEST AT MD = 10670 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 221.74 DEG. TIE-IN SURVEY AT 9,208.42' MD WINDOW POINT AT 9,322.00' MD PROJECTED SURVEY AT 10,670.00' MD RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / D-0iA 500292005401 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052897 JOB NUMBER: AK-MW-70111 KELLY BUSHING ELEV. = 65.95 FT. OPERATOR: BP EXPLORATION 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 9208.42 8486.43 8420.48 1124.96 S 2105.07 W 10208.42 8983.84 8917.89 1427.31 S 2745.45 W 10670.00 9071.72 9005.77 1873.09 S 2745.60 W 721.99 1224.58 502.58 1598.28 373.70 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. RRY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE SHARED SERVICES DRILLING PBU / D- 0IA 500292005401 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052897 JOB NUMBER: AK-MW-70111 KELLY BUSHING ELEV. = 65.95 FT. OPERATOR: BP EXPLORATION 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 9208.42 8486.43 8420.48 1124.96 S 2105.07 W 721.99 9298.77 8565.95 8500.00 1123.25 S 2147.93 W 732.82 10.83 9418.55 8665.95 8600.00 1099.84 S 2207.65 W 752.60 19.78 9587.18 8765.95 8700.00 1066.21 S 2334.83 W 821.23 68.63 9852.58 8865.95 8800.00 1154.88 S 2557.35 W 986.63 165.39 10121.57 8965.95 8900.00 1351.94 S 2706.53 W 1155.62 169.00 10649.43 9065.95 9000.00 1853.54 S 2748.34 W 1583.48 427.86 10670.00 9071.72 9005.77 1873.09 S 2745.60 W 1598.28 14.79 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 9/10/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11341 Company: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape D-01A ~ ~' -]%0~ .... 97276 PEX-AIT &BHC 970529 1 D-01A 97276 PEX-AIT 970529 I I ., D-01A 97276 PEX-CNL 970529 I 1 D-01A 97276 PEX-LDT 970529 I 1 D-01A 97276 BHC 970529 1 I , ,, D-01A 97276 PEX-BOREHOLE PROFILE 970529 1 1 ;D-01A 97276 PEX-SSTVD 970529 I 1 W-03A ~ ~"~C)Le 97367 PEX-AIT,BHC&HALS-GR 970811 1 W-03A 97367 PEX-AIT 970811 1 1 W-03A 97367 PEX-AZIMUTHALLATEROLOG 970811 I 1 W-03A 97367 PEX-CNL 970811 1 1 W-03A 97367 PEX-CNL/LDT 970811 I 1 W-03A 97367 BHC 970811 1 1 ,, W-03A 97367 PEX-SSTVD 970811 I I .,, W-03A 97367 RFT 97081 2 I I ., 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 . ce,v d WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - September 3, 1997 D-01A, AK-MW-70149 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~ Yum Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-20054-01. p, ECEWEO SEP 05 199~' Al~k_ a Oi, l & G~ Cons. C0mmi.s~ Anc~0rage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska September 3, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs D-01A, AK-MW-70153 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.' Yun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 D-01A: 2"x 5" MD Resistivity & Cramma Ray Logs: 50-029-20054-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20054-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia SEP 0 ~ 't997' 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 7, 1997 Paul K. Prince Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Prudhoe Bay Unit D-0 lA BP Exploration (Alaska) Inc. Permit No. 97-78 Sur Loc: 2130'SNL, 1067'WEL, Sec. 23, T11N, R13E, UM Btmhole Loc: 383 I'SNL, 3765'WEL, Sec. 23, T1 IN, R13E, UM Dear Mr. Prince: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated April 30, 1997 are in effect for this revision. David W. Johnston \ Chairman BY ORDER OF THE C~OMMISSION dlf/Enclosures CC' Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA -' ALASKA OIL AND GAS CONSERVATION CO,.,,vllSSION PERMIT TO DRILL 20 AAC 25.005 REVISED: 05/05/97 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 63.55' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028285 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2130'SNL, 1067' WEL, SEC. 23, T11N, R13E, UPM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 25100302630-277 3435' SNL, 3822' WEL, SEC. 23, T11N, R13E, UPM D-01A At total depth 9. Approximate spud date Amount $200,000.00 3831' SNL, 3765' WEL, SEC. 23, T11N, R13E, UPM 05/11/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028286, 1449'I No Close Approach 2560 10674' MD / 9024' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9330' Maximum Hole Angle 82° Maximum surface 2470 psig, At total depth (TVD) 8800' / 3~35~00 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 .-, IBT-Mod 1494' 9180' 8460' 10674' 9024' 164 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary0 I INALR G Total depth: measured 10130 feet Plugs (measured) -- v true vertical 9301 feet Effective depth: measured 9894 feet Junk (measured) true vertical 9083 feet Casing Length Size Cemented MD TVD Structural See Attachment Conductor ISn~erframC;diate Production Liner MAY 6 1997 ~ ~ ~.Gas Cons. Perforation depth: measured 9714' - 9716', 9730' - 9796', 9804' - 9815' Squeezed: 9615' - 9714 (3 intervals) true vertical 8868' - 8869', 8882' - 8940', 8947' - 8956' 8781' - 8868' 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: Jimi~ith,j ~, 564-5026j/~ Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that thejf'¢go~g i~/¢ruj~,/~n~l correct to the best of my knowledge Signed ¥ ~~1[~ ,J ~.------..,....,_ , Paul K. Prince Title Senior Drilling Engineer Date Commission Use Only P~lr~it. Number I APl Number A~r.o.~te J See cover ,etter ~ ~ 50- 0 ~-.(~- ¢~.O~ ~ "O [ ---- --~ ~ for other requirements Conditions of Approval: Samples Required []Yes []No Mud Log Required []Yes '[~[] No Hydrogen Sulfide Measures [~lYes [] No Directional Survey Required []Yes [] No Required Working Pressure for BOPE 1--12M; 1~3M; 1--15M; I-ll0M; I--I15M °th0~;iginal $ignea !~y by order of David W. Johnston Approved By Commissioner the commission Date ,~-- /'-~ Form 10-401 Rev. 12-01-85 Submit In Triplicate BP EXPLORA;I'ION Memorandum To: Blair Wondzell Date: May 5, 1997 From: Jim Smith Subject: D-01A Well, Kickoff Point Change The D-01A well has previously been permitted (permit # 97-78 on April 24, 1997) with a Kick Off Point (KOP) at 9608'MD. Due to additional information that has just been obtained pertaining to possible additional reserves in Zone 4, the BP geologic group has requested that the KOP be moved to a shallower depth at the top of Zone 4. This request and pertinent information attached, is submitted in application for a permit change of the KOP from 9608'MD to 9330'MD. All directional targets and objectives on this well remain the same. During the P&A operations the cement volume to be placed below the EZSV has been increased to casing capacity plus 10 bbl to squeeze, in addition there will be more 4-1/2" liner and liner cement required to place the liner top above the new KOP. Please contact me with any questions at 564-5026. Regards, Jim Smith SSD 41a .Oil .& Cas Cons. ,C0mmiss ,-., [Well Name: D-O lA Well Plan Summary Type of Well (producer or injector): ]Producer ] Surface Location: 2130'FNL, 1067'FEL, Sec. 23, T11N, R13E X=654096, Y=5958871 Target Location: 3435'FNL, 3822' FEL, Sec. 23, T11N, R13E X=651370, Y=5957510 Bottom Hole Location: 3831'FNL, 3765'FEL, Sec. 23, T1 IN, R13E X=651435, Y-5957115 [AFENumber: 14P0933 I IRig: Doyon#141 'l [Estimated Start Date: 15/11/97 [ I Operating days to complete: 122 I IMD: I 10674' I Well Design (conventional, slimhole, etc.): sidetrack high angle ultra slim hole I Objective: I Sadlerochit - Zone 2 Formation Markers: Formation Tops MD TVD(RKB) Begin sidetrack 9330 8593 whipstock out of 7" and 9-5/8" casings in top of Zone 4. Zone 3 9619 8792 Zone 2C 9771 8849 25N 10006 8933 End 24°/.'100; build 10270 8969 and turn Start Target 10270 8969 X=651370 Y=5957510 HOT 10637 9019 End Target; 10674 9024 X=651435 Y=5957115 TD 10674 9024 TD Casing/Tu bing Program: Hole Size ~2sg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD existing 20" 133# 8RD 2442' 30'/30' 2442'/2442' existing 13-3/8" 68# N-80 8RD 4000' 30'/30' 4030'/4030' existing 9-5/8" 47# L-80 BTC 1856' 30'/30' 1886'/1886' existing 7" 26g L-80 IJ4S 8054' 1886'/1886' 9940'/9069' 6" 4-1/2" 12.6g L-80 IBTMod 1494' 9180'/8460' 10674'/9024' NOTE: original KBE was 57.53', Orig KBE-BF elevation was 34.05'. Logging Program: I Open Hole Logs: I Cased Hole Logs: 6" Real Time MWD-GR and 4 Phase Resistivity starting at the beginning of the target polygon (-10270'MD) to TD, MADD pass the previous hole. Sample catchers are needed to begin catching drill cutting samples within the Zone 2 high-angle section. One run of drill pipe conveyed log~3~S~/l~. Etq/~N) required at TD for OOC and OWC oonarm~. &.' ,(~: ~' ~ '~¢ ~ ~ ~ none ~,AY 6 '199~ 10 Mud Program: [ Special design considerations I Whipstock drilling with Quikdriln. Pump two hi-vis sweeps[ after milling then same Ouikdriln solids free system to TD. Initial whipstock Mud Properties: 7" whipstock Kickoff (Zone 2) Density Viscosity LSR Yield LSRV Filtrate ph (PPG) Point 8.7-8.9 50-65 10-20 >45000 NC 8.5-9.0 Production Mud Properties:l Quikdriln in 6" below KOP Density Viscosity LSR Yield LSRV Filtrate pH (PPG) Point 8.8' 50-65 10-20 45000 NC 8.5-9.0 to 9.0 50-65 10-20 55000 NC 8.5-9.0 Keep Sand content at less than 0.25% in the production interval Hazards and Contingencies: Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics on file with AOGCC. Bottom Hole Pressure is 3350 psi at 8800'TVDss (estimated) Maximum Shut in Casing Pressure at surface is 2470 psi (assumes 0.1 psi/ft gas gradient to surface) Directional: [ KOP: 19330'MD, come off whipstock and build at 20I to 24°/100'to target, hold at high-angle to TD I Maximum H°le Angle: ]82° in Z°ne 2 t° TD I Close Approach Well: none Cement Data: Casing/Liner Lead: Sxs/Wt/Yield Tail: Sxs/WffYield Comments P&A 150/15.8/1.15 Class "G" below BAKER "K-I". Calculated at capacity plus 10 bbl to squeeze. 4-1/2" liner from none 164/15.7/1.19 Class "G"Acid resist., 10674' to 9180'MD in 30% excess on open 7" casing hole plus lap and 150' above TOL w/3-1/2" DP in hole. Contacts Name Office Home Pager James E. Smith Drilling Eng. 564-5026 345-8660 Paul Prince Drlg. Eng. Supr. 564-5589 345-6867 David Nims Drilling Supt. 564-5219 346-2026 Greg Bernaski Geologist 564-5464 346-1320 Rachael Mays Pad Engr. 564-5220 276-0138 Doug Von Tish Geophysics 564-5158 345-4294 Sperry Sun (mud plant/rig) Carl Hoeft/Pete Holtzman 659-2809 275-4015 275-7503 275-4539 11 Schlumberger wireline/DP conveyed Scott BittnedGraham Struart 659-2487 Short Well Summary Pre-Rig Operations: Note: original KBE was 57.53", BF elevation is 34.05' , 4. 5. 6. 7. 8. Rig Work: 1. 2. 3. 4. 5. Notify AOGCC prior to commencing P&A Operations. Note: The final P&A of perforations will occur later with the drilling rig. Make a chemical cut in the 3-1/2", 9.3#, L-80, 8R tubing at 9405'MD (note: refer to tubing tally summary. This cut will be in the middle of the pup joint above the sliding sleeve). Circulate and kill the well with sea water. Freeze protect well with diesel to 2000'MD. Test pack off and service lock down studs. Report results to rig supervisor as soon as possible. Install a BPV and test same. Remove the electrical lines, well house and flow lines. Prepare for rig arrival by leveling pad and digging out cellar. Please provide total well preparation cost on the hand over form. MIRU, verify pack off has been tested or retest. Pull BPV. Circulate the well to remove freeze protection and any trapped gas. Set and test TWC to 1000 psi. ND tree, NU and test BOPE. Circ. Seawater. Pull and LD 5-1/2"x3-1/2" tubing to pre-rig cut depth (-9405'MD). RIH and fish collapsed joint. RIH and recover the slick stick. Run and set a 7" BAKER "K-I" on Baker 20 setting tool (w/CCL). Set the BAKER "K-I" at 3' below a casing collar as near as possible to 9350'MD (planned KOP is 9330'MD) PU BAKER "K-I" stinger (plug catcher just above BAKER "K-i" stinger) on 3-1/2" DP. RIH to BAKER "K-I" and sting in. Establish injection rate into perforations from 9714-9815'MD. Mix and pump 31 bbls - 150sacks - of class "G" cement (calculated as open casing capacity plus 10 bbl to squeeze), displace with seawater to place cement from BAKER "K-I" to PBTD at 9894'MD. Sting out, reverse any excess cement then pump dart into plug catcher to clean DP. POOH. 6. Shut in the well and test 9-5/8"x7" casing against the BAKER "K-I" to 3500 psi for 30 minutes. If the casing leaks, a RTTS run will be made to locate and identify the leaking zone for further repairs. 7. PU Baker anchor/whipstock assembly for 7" casing and MWD. RIH and set whipstock on top of BAKER "K-I" at 30 degrees right of highside. 8. Mill out of 7" and 9-5/8" casing strings plus 25' of new formation. 9. Trip for 6" steerable BHA and drill ahead per directional plan building at 20°/100 to - 9610'MD. Change to rotational assembly for drilling Zone 3 from 9619'MD to 9771'MD, then trip for a steerable assembly to continue the build at 24°/100' to reach the target polygon at 10270'MD/8968'TVD. Trip for hold assembly and resistivity tool to continue the high angle section to TD at 10674'MD and 9024TVD. 10. Log with DPC to TD. 11. Run and cement 4-1/2" 12.6# L-80 liner to TD with 150' lap into the 7" casing. 12. Test liner top packer and liner to 3500 psi for 30 minutes. 13. Perforate liner on DP per Asset specifications. 14. Run 4-1/2" 12.6ff, L-80 tubing and completion with 5-GLM's. 15. ND stack, NU tree and test. Set BPV. 16. Secure well, release rig. ~ '~~,~~~ i Scale 1 ' 100.00 NORTH o o o o- shared. Services Drillin l Structure: PB O Pad . Well: D-O1A Field · Prudhoe Bay Location :Alaska East -> PRELIMINARY -3200 -5100 -5000 -2900 -2800 -2700 -2600 -2500 -2400 -2500 -2200 -2100 -2000 -- - :_.'70 - TARGET DATA MD In¢ Di~ ~D North E~sl ~- N~rne .... P,~slt~n -- 10674,82.18 171.8Z$024 -1701 -Z697 001,~. 651455,59571 15 10270 82.18 171.818969 -1305 -2754 DO l ~BSL 651570, 5957510 DO1ABSL D01AESL - -', I t I I -600 -- - -7C0 -- - -8C~: - -900 -- 10C;2 -- --1 i.C0 -- I I I I I I I I I I I I I I I I I I I I I I I I I I I -- 1500 A !1 -- 1600 - --17C. 0 -- --1803 -- -1900 -3200 -5100 -5000 -2900 -2800 -2700 -2600 -2500 -2400 -2500 -2200 -2100 -2000 Scale 1 ' 100.00 o 0 o o D-O1A Wp3 I 8500 - -- 8600 - 8700 - -- 8800 - -- 8900 - -- 9000 - -- 9100 - -- 9200 - -- 9300 - -- 9400 - -- 9500 - -- 9600 - 9700 1800 I I I I 1900 2000 Tie on 31.58 42.,34 59,92 Zone 3 Zone 2C 66.93 25N 75.79 Target Shared Services Drilling Sfructure ' PB D Pod Field · Prudhoe Boy Well · D-O1A Locafion 'Alaska WELL PROFILE DATA .... Point .... MD Inc Dir TVD North Tie on 9330 28.32 2.72,96 8593 -1122 End of Build 9.351 ,30.0027.3.00 8612 -1122 End of Build 9483 44.00 ,300.00 8718 - 1097 End of Build 9610 68,00 290.00 8788 -1054 KOP 9748 68.00 290.00 8840 - ] 010 ~ End of Build 10171 87,69 186.69 8961 -1207 End of Hold 10198 87.69 186.69 8962 -1234 1'0rget 10270 82,18 171.81 8969 -I.305 Target 10674 82.18 171,82 9024 -1701 East DLS (deg/lOO/t) -2164 0.00 -2174 8.00 -2248 16.00 -2343 20,00 -2465 0.00 -2751 24.00 -2754 0,00 -2754 22.OO -2697 0,00 ;2,18 ..~1~ HOlT Target [~1 2100 2200 2300 2400 2500 2600 2700 . 2800 2900 5000 5100 5200 Scale 1 ' 100.00 Vertical Section on 21 3.75 azimuth with reference 0.00 S, 0.00 E from 0lA D-01A Wp3 Vertical Section ;{KB 213.75 63.55 MD Inc. Azi, TVDss TVDrkb Rect. Coordinates Northing 9330.00 28.32 272.96 8529.65 8593.20 1122.42S 9351.02 30.00 273,00 8548.00 8611.55 1121.89S 9400.00 34.45 285.15 8589.47 8653.02 1117,63S 9483.41 44.00 300,00 8654.15 8717.70 1096.88S 9500.00 47.09 298.30 8665.77 8729,32 1091.12S 9600.00 66.06 290.62 8720.67 8784.22 1057.32S 9610.12 68.00 290.00 8724,62 8788.17 1054.09S 9619.15 68.00 290.00 8728.00 8791.55 1051.22S 9700.00 68.00 290.00 8758.29 8821.84 1025.58S 9748.49 68.00 290.00 8776,45 8840.00 1010.21S 9771.02 67.42 284.19 8785.00 8848.55 1004.08S 9800.00 66.99 276.66 8796.24 8859.79 999.25S 9900.00 68.22 250.70 8834.91 8898,46 1009.41S 10000.00 73.33 225.83 8868.29 8931.84 1058,85s 10006.04 73.74 224.38 8870.00 8933.55 1062.94S 10100.00 81.19 202.56 8890.61 8954.16 1139.03S 10171,12 87.69 186.69 8897.54 8961.09 1207.27S 10197.86 87.69 186,69 8898.62 8962.17 1233.85s 10200.00 87.52 186.25 8898.71 8962.26 1235.98S 10269.71 82.18 171.81 8905.00 8968.55 ,1305.18S 10300.00 82.18 171.81 ' 8909.12 8972.67 1334.89S 10400.00 82.18 171.81 8922.73 8986.28 1432.95s 10500.00 82.18 171.82 8936.34 8999.89 1531.01s 10600.00 82.18 171.82 8949.95 9013.50 1629.07s 10637.08 82.18 171.82 8955.00 9018.55 1665.43s 10673.81 82.18 171.82 8960.00 9023.55 1701.45s Easting 2163.78W 2174.01W 2199.65W 2247.72W 2258.07W 2333.85W 2342.59W 2350.46W 2420.90W 2463.15w 2483.06W 2509.31W 2600.18w 2679.52W 2683.63W 2733.63w 2751.38w 2754.49w 2754.73w 2753.60w 2749.32W 2735.21w 2721.11W 2707.00W 2701.78W 2696.60w Grid Coordinates Easting 651955.95 651945.72 651920.00 651871.52 651861 .O6 651784.61 651775.81 651767.89 651696.95 651654.40 651634.37 6516O8.03 651517.39 651439.07 651435.05 651386.60 651370.24 651367.66 651367.46 65137O.00 651374.87 651390.96 651407.05 651423.13 651429.10 651435.00 Northing 5957704.64 5957704.97 5957708.71 5957728,48 5957734.O3 5957766.29 5957769.34 5957772.05 5957796.25 595781O.77 5957816.49 5957820.79 5957808.8O 5957757.77 5957753.59 5957676.51 5957607.93 59575~1.29 5957579,16 595751O.OO 5957480.39 5957382,65 5957284.90 5957187,15 595715O.9O 5957115.OO DLS deg/100ft 0.00 8.00 16.00 16.00 20.00 20.00 20.00 0.00 0.00 0.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 2135.39 2140.63 2151.33 2160.79 2161.75 2175.75 2177.91 2179.90 2197.72 2208.41 2214.38 2224.94 2283.87 2369.06 2374.75 2465.79 2532.39 2556.23 2558.12 2615.04 2637.36 2711.05 2784.75 2858.45 2885.78 2912.85 Zone 3 Zone 2C 25N D01ABSL HO/T D01AESL comment 4/1/97 1:35 PM Page I of I TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 30, 1997 Paul K. Prince Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit D-01A BP Exploration (Alaska) Inc. Permit No. 97-78 Sur. Loc. 2130'SNL, 1067'WEL, Sec. 23, T11N, R13E, UM Btmnhole Loc. 3831'SNL, 3765'WEL, Sec. 23, T11N, R13E, UM Dear Mr. Prince: Enclosed is the approved application for permit to redrill the above referenced 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 determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given tor on the North Slope pager at 659-3607. David W. J'oh~ston Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. --. STATE OF ALASKA ALASK/ JILAND GAS CONSERVATION CC,. .¢IlSSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen~ [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 63.66' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028285 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2130'SNL, 1067' WEL, SEC. 23, T11N, R13E, UPM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 3435' SNL, 3822' WEL, SEC. 23, T11N, R13E, UPM D-01A At total depth 19. Approximate spud date Amount $200,000.00 3831' SNL, 3765' WEL, SEC. 23, T11 N, R13E, UPM 04/30/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028286, 1449'I No Close Approach 2560 10659' MD / 8960' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9608' Maximum Hole An,qle 82° Maximum surface 2470 psig, At total depth (TVD) 8800' / 3350 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT-Mod 1201' 9458' 8646' 10659' 9023' 154 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10130 feet Plugs(measured) ORIGINAL true vertical 9301 feet ../' Effective depth: measured 9894 feet Junk (measured) .:~ true vertical 9083 feet Casing Length Size Cemented M D TVD Structural See Attachment Conductor Surface ~''~ Intermediate Production Liner APR 24 1997 A[ask~ 0it & Gas Cons. CommiSsar' Anchorage Perforation depth: measured 9714' - 9716', 9730' - 9796', 9804' - 9815' Squeezed: 9615' - 9714' (3 intervals) true vertical 8868' - 8869', 8882' - 8940', 8947' - 8956' 8781' ~ 8868' 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 HUbble, Contact Engineer NamelNu~, b~r: Jim .Sm/Z/], 564-5026 Prepared By Name/Number: Terrie 564-4628 21' I hereby Certify that the f°['~/g~in~i~ tr/~e'/~n/ c°rrect t°the best °fmY kn°wledgesigned i.f/% . \\ V (t/ L~I {~"'~ Pau, K. Prince (~ ~~,,,_ ~ Title Senior Drilling Engineer Date Cornmission Use Only Permit Number I APl Number Approval Date ISee c°ver letterforother ~'7- ~ ,~ 50- ~ z.. ~' -- .2.. O (D S ~7~--'' ~2~ / "~~~- ~"~' requirements Conditions of Approval: Samples Required [] Yes ¢i~ No Mud Log Required~ Y~I~] :~ No Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required~ Ye~] No Required Working Pressure for DOPE [] 2M; ~ 3M; [] EM; [] 10M;lq 15M Other: Approved By 0rigina! Sianed By by order of c~=~-- _- .. ,., ,'.~..,.~,,,, Commissioner the commission Date Form 10-401 Rev. 12-01-85 [~avid W. johnston Submit In Triplicate WELL NAME: D-01 23. Attachment - Casing, Liner and Cementing Record Casing ~ Hole ....... ~.V~D De~ Size Wt. Per Ft Grade Top Bottom Size Cementing Record Top Bottom ......... 30" ........ Stove..... P.ipe Surfac6 84' 36" 250 sx PF Surface 84' 20" 133#/94#K-55/H-4CSurfacE 2447' 26" 5500 sx PF Surface 2447' refrigeration (originally Surface - 16" 65# H-40 1963' .... 2.20.0' . 2200'). 1963' 2200' 13-3/8" 68#/61# K-55 Surface 4030' 17-1/2" 1600 Class'G' Surface 4030' 10-3/4" 55.5# N-80 2000' 2427' 12-1/4" See Below 2000' 2427' 9-5/8" 47# N-80 2427' 10089' 12-1/4" 2700 sx Class 'G' 2427' 9260' 9-5/8" 47# L-80 Surface 1886' 12-1/4" See Below Surface 1886' 7" 26# L-80 1886' 9940' 12-1/4" 200 sx Class'G' 1886' 9127' ............................................................... I Well Name: ID-O1A Well Plan Summary Type of Well (producer or in~ector): [Producer [ Surface Location: Target Location: Bottom Hole Location: 2130'FNL, 1067'FEL, Sec. 23, TllN, R13E X=654096, Y=5958871 3435'FNL, 3822' FEL, Sec. 23, T11N, R13E X=651370, Y=5957510 3831'FNL, 3765'FEL, Sec. 23, TllN, R13E X=651435, Y=5957115 I AFENumber: ] 4P0933 [Estimated Start Date: [ 4/30/97 MD: 10659' ling: [Doyon #141 I [Operating days to complete: [22 [ TVDss: 8960' ]Well Design (conventional, slimhole, etc.): RKB: 63.55' sidetrack high angle ultra slim hole l Obiective: I Sadlerochit- Zone 2 Formation Markers: Formation Tops MD TVD(RKB) Begin sidetrack 9608 8836 whipstock out of 7" and %5/8" casing in Bottom Zone 3 Zone 2C 9621 8848 25N 9761 8933 End 28°/100, build 10255 8968 and mm Start Target 10255 8968 X=651370 Y=5957560 HOT 10622 9018 End Target 10659 9023 X=651435 Y=5957115 TD 10673 9023 TD Well Plan Summary Page 1 Casing/Tu bing Program: Hole ~ize Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD existing 20" 133# 8RD 2442' 30'/30' 2442'/2442' existing 13-3/8" 68# N-80 8RD 4000' 30'/30' 4030'/4030' existing 9-5/8" 47# L-80 BTC 1856' 30'/30' 1886'/1886' existing 7" 26# L-80 IJ4S 8054' 1886'/1886' 9940'/9069' 6" 4-1/2" 12.6# L-80 IBTMod 1201' 9458'/8646' 10659'/9023' Logging Program: NOTE: original KBE was 57.53', Orig KBE-BF elevation was 34.05'. l Open Hole Logs: ICased Hole Logs: 6" Real Time MWD-GR and 4 Phase Resistivity starting at the beginning of the target polygon (10255'MD) to TD. Sample catchers are needed to begin catching drill cutting samples within the Zone 2 high-angle section. One run of drill pipe conveyed logs (GR/RES/CNL/DEN/S ON) required at TD for GOC and OWC confirmation. none Mud Program: Special design considerations I Whipstock drilling with Quikdriln. Pump two hi-vis sweeps I after milling then same Quikdriln solids free system to TD. Initial whipstock Mud Properties: 7" whipstock Kickoff below Kingak Density Viscosity LSR Yield LSRV Filtrate ph (PPG) Point 8.7-8.9 50-65 10-20 >45000 NC 8.5-9.0 Production Mud Properties:l Quikdriln in 6" below KOP Density Viscosity LSR Yield LSRV Filtrate pH (PPG) Point 8.8 50-65 10-20 45000 NC 8.5-9.0 to 9.0 50-65 10-20 55000 NC 8.5-9.0 Keep Sand content at less than 0.25 % in the production interval Hazards and Contingencies: Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. B OPE and drilling fluid system schematics on file with AOGCC. Bottom Hole Pressure is 3350 psi at 8800'TVDss (estimated) Well Plan Summary Page 2 Directional: I KOP: 9608'MD, come off whipstock and build at 28°/100'to target, hold at high-angle to TD I Maximum Hole Angle: 82° in Zone 2 to TD Close Approach Well: none Cement Data: Casing/Liner P&A 4-1/2" liner from 10659' to 9458'MD in 7" casing Lead: SxsfWt~ield none Tail: Sxs/Wt~ield 73/15.8/1.15 154/15.7/1.19 Comments Class "G" below EZSV. Calculated at capacity plus 40%. Class "G"Acid resist., 30% excess on open hole plus lap and 200' above TOL w/3-1/2" DP in hole. Name Contacts Office Home Paqer James E. Smith Paul Prince David Nims Drilling Eng. Drlg. Eng. Supr. Drilling Supt. Greg Bernaski Rachael Mays Doug Yon Tish Mark Stanley Geologist Pad Engr. Geophysics Asset Drlg. Engr. Sperry Sun (mud plant/rig) Carl Hoeft/Pete Holtzman Schlumberger wireline/DP conveyed Scott Bittner/Graham Struart 564-5O26 564-5589 564-5219 564-5464 564-5220 564-5158 564-5938 659-2809 659-2487 345-8660 345-6867 346-2026 346-132O 276-0138 345-4294 277-0926 275-4015 275-7503 275-4539 Well Plan Summary Page 3 Pre-Rig Work: 1. Notify AOGCC prior to commencing P&A Operations. Note: The final P&A of perforations will occur later with the drilling rig. 2. Make a chemical cut in the 3-1/2", 9.3#, L-80, 8R tubing at 9405'MD (note: refer to tubing tally summary. This cut will be in the middle of the pup joint above the sliding sleeve). 3. Circulate and Kill the well with sea water. 4. Freeze protect well with diesel to 2000'MD. 5. Test pack off and service lock down studs. 6. Install a BPV and test same. 7. Remove the electrical lines, well house and flow lines. Prepare for rig arrival by leveling pad and digging out cellar. 8. Please provide total well preparation cost on the hand over form. Rig Work: 1. MIRU, verify pack off has been tested or retest. Pull BPV. 2. Circulate the well to remove freeze protection and any trapped gas. Set and test TWC to 1000 psi. ND tree, NU and test BOPE. 3. Pull and LD 5-1/2"x3-1/2" tubing to pre-rig cut depth (-9405'MD). 4. R/H and fish collapsed joint. Mill and recover 7" Otis Packer and tailpipe. 5. Run and set a 7" EZSV on Baker 20 setting tool (w/CCL). Set the EZSV at 3' below a casing collar as near as possible to 9628'MD (planned KOP is 9608'MD). PU EZSV stinger (plug catcher just above EZSV stinger) on 3-1/2" DP. RIH to EZSV and sting in. Establish injection rate into perforations from 9714-9815'MD. Mix and pump 15 bbls - 73sacks - of class "G" cement (calculated as open casing capacity plus 40%), drop dart and displace with seawater to place cement from EZSV to PBTD at 9894'MD. Sting out, pump dart into plug catcher, Reverse DP capacity and POOH. 6. Shut in the well and test 9-5/8"x7" casing against the EZSV to 3500 psi for 30 minutes. If the casing leaks, a RTTS run will be made to locate and identify the leaking zone for further repairs. 7. PU Baker anchor/whipstock assembly for 7" casing and MWD. RIH and set whipstock on top of EZSV. 8. Mill out of 7" and 9-5/8" casing strings plus 22' of new formation. 9. Trip for 6" steerable BHA and drill ahead per directional plan building at 28°/100 to - 10255'MD. Change to rotational assembly and continue the high angle section to TD at 10659'MD and 8960TVDss. 10. Log with DPC to TD. 11. Run and cement 4-1/2" 12.6# L-80 liner to TD with 150' lap into the 7" casing. [~, ~ ~'*~:~i~,~,': ,~_~ 12. Test liner top packer and liner to 3500 psi for 30 minutes. 13. Perforate liner on DP per Asset specifications. 14. Run 4-1/2" 12.6#, L-80 tubing and completion with 5-GLM's. Well Plan Summary Page 4 15. ND stack, NU tree and test. Set BPV. 16. Secure well, release rig. Greg West SSD Well Plan Summary Page 5 hared Services Drillin t Field · Prudfloe Boy Location: Alaska ID-O1A Wp4I 8600 - 87OO - -- ~800 - -- 8900 -- q.) 9000 - -- i~ 9100- -- e~ L 9200 - q.) 9500 - ,,. - I---- 9400 - II _ V 9500 - 9600 - 9700 - 98OO .... Point .... lie on '. KOP End of Build End of Hold ~orget i'arg~,t,: WELL PROFILE DATA MD Inc Dir ~VD No~h East DLS(deg/lO0~) 9608 29.07 274.98 8857 -1114 -2298 0.00 9610 29,00 274.50 8858 -1115 -2299 12.00 9B39 92,81 281.83 8944 -1082 -2486 28.00 9862 92,81 281,85 8945 -1078 -2508 0,00 10255 82.18 171.82 8969 -1505 -2754 28.00 10660 82.18 171.81 9024 -1701 -2697 0.00 FOR PE.~Ai-FrlNG ONLY 1900 2000 2100 2200 2500 2400 2500 2600 2700 2800 2900 5000 5100 5200 Scale 1 ' 100.00 Vertical Section on 21 4.1 6 azimuth with reference 0.00 S, 0.00 W from O1A Alaska Oil & Gas Cons. Anchorage N Shared Services DrillingI Sfrudure: PB D Pad Well: D-O1A Field · Prudhoe Bay Location: Alaska .... TARGET DATA .... MD Inc Dir TVD North East -- Name ....Position -- 10660 82.18 171.81 9024 -1701 -2697 DO1AESL 651435 , 5957115 10255 82.18 171.82 Bg6g -1305 -2754- DO1ABSL 651370 , 5957510 TRUE NORTH oo.oo East FOR PERMITTING ONLY -3000 -2900 -2800 -2700 -2600 -2500 -2400 -2300 -2200 -2100 -SO0 -- -900 - -- -1000- -- -1100- -- -12oo- A - II -1500- -- ~ -1400- - 0 -1500- _ -1600- I -1700- -- -1800- -- -1900- -- 0 0 0 0 DO 1ABSL DO 1AESL 4 I/2," -2000 D-OIAWp4 I -800 -- - -900 -- --1000 -- --110o -- --1200 - A -- --1400 Z - 0 --1500 _ Z~' --1600 _ --1700 -- --1800 -- --1900 -- -2000 -3000 -2900 -2800 -2700 -2600 -2500 -2400 -2300 -2200 -2100 Scale 1 ' 100.00 East 01A Wp4 Ical Section 214.16 63.55' MD Inc. Azi. TVDss TVDrkb 608.00 29.07 610.03 29.00 621.77 32.26 700.00 54.04 761.77 71.29 600.00 81.96 838.82 92.81 861.92 92.81 900.00 91.41 000.00 87.65 100.00 84.43 200.OO 82.5O 255.49 82.18 30O.OO 82.18 4OO.OO 82.18 500.00 82.18 6OO.O0 82.18 622.87 82.18 659.60 82.18 274.98 274.50 275.37 278.77 280,30 281,08 281.83 281.83 271.25 243.5O 215.62 187.50 171.82 171.82 171.82 171.81 171.81 171.81 171.81 8773.13 8774.90 8785.00 8841.74 8870.00 8878.83 8880.60 8879.46 8878.06 8878.89 8885.94 8897.56 8905.00 8911.06 8924.66 8938.27 8951.89 8955.00 8960.00 8836.68 8838.45 , 8848.55 8905.29 8933.55 8942.38 8944.15 8943.01 8941.61 8942.44 8949.49 8961.11 8968.55 8974.61 8988.21 9001.82 9015.44 9018.55 9023.55 Rect. Coordinates No~hlng 1113.51S 1113.43S 1112.91S 1106.05s 1096.93s 1090.04s 1082.34s 1077.61s 1073.28s 1094,91s 1158.93s 1250.36s 1305.18s 1348.83s 1446.89s 1544.95s 1643.01s 1665.43s 1701.45s Easting 2297.64W 2298.62W 2304.58W 2357.30W 2411.20W 2447.69W 2485.65W 2508.20W 2545.95W 2642.56W 2717.76W 2753.93W 2753.60W 2747.32W 2733.22W 2719.12w 2705.01W 2701.78W 2696.60W Grid Coordinates Easting 651821.95 651820.97 651815.0O 651762.16 651708.09 651671.47 651633.37 651610.73 651572.90 651476.75 651402.87 651368.56 651370.00 651377.16 651393.24 651409.32 651425.41 651429.09 651435.OO No~hing 5957710.84 5957710.91 5957711.30 5957717.10 5957725.12 5957731.28 5957738.20 5957742.47 5957746.04 5957722.46 5957656.94 5957564.80 5957510.00 5957466.50 5957368.75 5957271.00 5957173.26 5957150.90 5957115.00 DLS deg/100ff 0.00 12.00 28.00 28.00 28.00 28.00 28.00 0.00 28.00 28.00 28.00 28.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 Ve~ical Section 2211.54 2212.02 2214.94 2238.86 2261.58 2276.37 2291.31 2300.06 2317.68 2389.82 2485.02 2580.98 2626.16 2658.75 2731.98 2805.20 2878.42 2895.17 2922.06 Tiein point Zone 2C 25N HOlT TD 4 112" liner Comment 4/21/97 9:10 AM Page 1 of 1 'REE: b ..~lW WELLHEAD: McEVOY ACTUATOR: OTIS 9 5/8' 47#/[1., L-80, NSCC CSG. ~ 5 1/2' 17#/ft, L-80 BTRS TBG I I 95/8- x 7- x vER 11886' ! MAX ANGLE: 39o/78OO' N--80, SEALLOCK 4030' i3-1/2', 9.3#/ft, L-80, 8-R TUBING . TUBING ID: 2.992' CAPACITY: .0087 BBL/FT 7' 26#/It, L-80 UNER KB. ELEV =57.53' BF. ELEV = 34.05' 5 I/2"SSSV LANDING NIPPLE (OTIS RQM )(4.562' ID) 1800'1 -- 51/2'x 3 r 'CROSSOVER I 1871'1 i ~ 3 1/2" GAS LIFT MANDRELS I(McMURR ~,Y FMHO w/1' BK LATCH1 I NQ MD(BKB TVDss 6 2997' 2943' 5 5107 5084' 4 671Z 6367' 3 7812' 7248' 2 8470' 7768' 1 8908' 8185' 3 1/2' SLIDING SLEEVE I OTIS 'XA' ( 2.750' ID) 9409' SEALASSY. I 9465' PERFS (4 holes) 7' OTIS PACKER (.CL)(- '~D) I 9505' 3 1/2', 9.3 #/ft, L-80 TAILPIPE 3 1/2" "X" NIPPLE (OTIS) ( 2.750' ID) 9536' 3 1/2' 'XN' NIPPLE I ( OTIS)( 2.635' ID) 9569' 3 1/2' TBG TAIL I 9602' (BAKER WI_EG ) (ELMD)I 9587' PERFORATION SUMMARY REF: LOG: SWS - BHCS 1-31-70 PE ? 4 4 4 INTERVAL ds in 9 5/8" casi~ 9490. (4holes) · 9650-9670 · 9686-9716 Perfs i~ 7' liner. 9714 - 9716' 9730 - 9796' 9804 - 9815' OPEN/SQZ'D g: SQZ 77 SQZ '87 SQZ '87 SQZ '87 OPEN/8-23-87 SQZ/rpf '87 OPEN 8-23-87 PBTD 7' , 26#/ft, Lq]O, BTRS 9-5/8'; 47#/ft, N-80, SL DATE REV. BY 11-4-76 8-25-87 11-6-90 A. TEEL 3/15/95 MBW COMMENTS RECOMPLETION RWO PUT ON MAC REVISED PRUDHOE BAY UNIT BP Exploration (Alaska) WELL: D-01 (23-23-11-13) APl NO: 50-029-20054 SEC 23;TN 11N; RGE13E STATE OF ALASKA ALASK/-_ . IL AND GAS CONSERVATION CO. ,¢IISSION APPLICATION FOR SUNDRY APPROVAL ' [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate 11. Type of Request: [] 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 2130' SNL, 1067' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval 2037' NSL, 1909' EWL, SEC. 23, T11N, R13E, UPM At effective depth 2122' NSL, 1715' EWL, SEC. 23, T11 N, R13E, UPM At total depth 2130' NSL, 1637' EWL, SEC. 23, T11 N, R13E, UPM Type of well: ~ Development I~ Exploratory I~ Stratigraphic i---I Service 6. Datum Elevation (DF or KB) KBE = 57.53' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-01 9. Permit Number 69-121 10. APl Number 50-029-20054 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10130 feet true Vertical 9301 feet Effective depth: measured 9894 feet true vertical 9083 feet Plugs (measured) Junk (measured) ORIGINAL Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Size Cemented See Attachment Aias~a 0ii & Gas Cons. u0m.m.t~ 'Anchoraga 9714'-9718', 973o'-9798', 98o4'-9815' MD TVD .**, ,'. 2 4 1997 ~[.~_~t;~ 0il ~, uas Cons. "' ' · N ~ ' ~no,~or~ g~ 4' Squeezed: 9615 - 971 (3 inte~ats) true vertical 8868'-8869' 8882'-8940', 8947'-8956' 8781'-8868' Tubing (size, grade, and measured depth) 5-1/2", 17#, AB Mod. to 1871 '; 3-1/2", 9.3#, 8rd AB EUE to 9602' Packers and SSSV (type and measured depth) HCL Packer at 9465'; 5-1/2" BVN at 1800' 3. Attachments ~ Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation April 26, 1997 16. If proposal was verbally approved Name of approver 15. Status of well classifications as: ~ Oil [] Gas [~ Suspended Service Date approve¢ Terrie Hubble, 564-4628 Contact Engineer Name/,l~u~ber: Jim SrO, 564-5026 Prepared By Name/Number: 17. I hereby certify that th~ for~ge,inc~ is~rue/ a~/d correct to the best of my knowledge Paul K. Pdnce ~~ '~ ' Title Senior Drilling Engineer Commission Use Only Date Conditions of Ap. pr~v,¢l: Notify Commission so representative may witness o,~ec~ Oo~ Plug integrity .,/"' BOP Test ~ Location clearance . : ~P~e~,Q~'~e~/~ Mechanical Integri-'--'~y Test__ Su----~sequent form required ~ 10-__ ,,?,': Signed By Approved [:)y order of the Commission ;'~V~d W. Johnston Commissioner Form 10-403 Rev. 06/15/88 Date ~/~ ! . Su bm~ln ~,2~.~ Company: Log Date: Log No.: Run No.: Pipe Desc.: Pipe Use: Memory Multi-Finger Caliper Log Results Summary D-Ola Prudhoe Bay Alaska 50-029-20054-01 9,158' 10,570' (MD) Feb. 10, 200[~ ,~ r~ '~ ~ ~ ~ Field: 1042 State: 1 4.5" 12.6 lbO.. ~/ ~' ''~ "~) / APl No.: ~ Intvl: Horizontal Liner Bot. Log Intvl: Inspection Type- Horizontal Liner Inspection for Source of Produced Rocks COMMENTS · This Icg was run on Coiled Tubing to assess the condition of the 4.5" Horizontal Liner for potential sources of rock production. The caliper recordings indicate an area of significant damage in Jt. 27 @ 10,282' MD, where two opposing holes are recorded that measure in excess of 1" in diameter. There is also an indication of 62% cross-sectional wall loss at this location, but a significant portion of the indicated increase in overall ID may be due to "ballooning" type deformation often associated with perforated intervals. Significant deposits or ID restriction are recorded between 10,160' and 10,340'. In the interval 10,285' to approximately 10,300', just below the area where large holes are recorded, the deposits or ID restriction appears to be distributed somewhat evenly about the ID of the liner. Over the remainder of the interval, the restrictions appear as isolated acccumulations covedng less that 1/4th of the internal circumference. The remainder of the liner appears in good to fair condition, with a majodty of the maximum corrosive penetrations recorded measuring between 13% and 40% wall penetration. The distribution of maximum recorded wall penetrations and cross-sectional wall loss throughout the logged interval is illustrated in the following Body Region Analysis Overview. MAXIMUM RECORDED WALL PENETRATIONS ' PERFORATIONS (100%) Jt. 27 PERFORATIONS (97%) Jt. 29 PERFORATIONS (77%) Jt. 28 Line of Corr. (46%) Jt. 24 General Corr. (40%) Jt. 13 MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' RECEIVED 10,344' MD 10,306' MD 10,150' MD FEB 1 6 000 9,676' MD Alaska 0il & Gas Cons. Com.~issi_0_n Anchorage PERF'D INTERVAL (62%) Jt. 27 @ 10,282' MD No other areas of cross-sectional wall loss in excess of 16% recorded throughout interval logged. MAXIMUM RECORDED ID RESTRICTIONS · DEPOSITS 3.33" Min. ID Jt. 27 @ 10,289' MD DEPOSITS 3.44" Min. ID Jt. 25 @ 10,172' MD DEPOSITS 3.45" Min. ID Jt. 26 @ 10,216' MD DEPOSITS 3.49" Min. ID Jr. 24 @ 10,170' MD {Field Engineer' J. Morgan Analyst: Joey Burton Witness: Gary Nordlander ] Well: D~31 a Reid: PRUDHOE BAY Company: BP EXPLORATJON ALASKA Counb¥: USA PDS Ca[iper Overview Body Region Analysis Survey Date: Feb. 10, 2000 Tool Type: MFC40 No. 99493 Tool Size: 2.75" No. of Fingers: 40 Analysed: J. Burton Tubing: Size Weight Grade & Thread Nora. OD Nom.iD Nora. Upset 4.5 ins t2.6 ppf L~30 8TRS 4.5 ins 3.958 i~s 4.5 ins ~;~ penetration body ~:~; metal ]oss body 1% 10% 20% 40% 85% 85% Numbe~ of ioints ana~,sed (total = 35) -I~ene 0 0 19 12 2 2 Loss [0 16 8 0 1 0 Damage Con§g~ratJon ( body ) Number of ioints damaged (tota! = 35) 9 15 9 0 2 penetration body ~?e metal loss body 0 50 0 10 2O 30 Bottom of Survey = 34 l O0 Analysis Overview page 2 RECEIVED FEB ~ 6 ~000 ~¢~ska 0ii & Bas Co~s, C0mr~issior, PDS JOINT TABULATION Pipe: 4.5 ins 12.6 ppf L-80 BTRS Well: Wallthickness. Body:O.271ins Upset=0.271ins Field: Nominal ID: 3.958 ins Company: Country: Date: D-0t a PRUDHOE BAY BP EXPLORATION ALASKA USA Feb. 10, 2000 Upset iD inches inches 3.86 3.85 PUP Shallow Pitting. Lille shallow Corr. 3.86 Line Corr. 3.84 3.84 5 3.83 3.83 Sha]iow Pitting. Shallow Pitting. Shallow Pitting. Line Corr. 3.84 Shallow Corr. 3.84 3.83 3.83 3.84 Shallow Pitting. Shaflow Corr. Shallow Pitting. 3.85 tine shallow Corr. 3.83 Generat Corr. 3.81 3,80 Shallow Pittin Shallow Corr. 3.81 Shallow Corr. 3.8] Line shallow Con. 3.84 Line shallow Corr. 3.83 3.85 34 3.86 Shallow Pitting. Shallow Pitting. General Corr. 3.86 Line shallow Corn DEPOStTS~ 3.78 Line Corr. DEPOSITS, 3.49 Line Corr. DEPOSITS, 3.44 Shallow Corn DEPOSITS. 3.45 General Corr. DEPOSITS. 333 PERFORATIONS. 3.68 PERFORATINS. General Corr, DEPOSITS. 3,92 PERFORATIONS. 3.96 General Corr. 3.97 General Corr. 3.96 General Corn 3.97 General Corr. 0 3.96 General Corr. Damage Classifications Penetration / projection class, in order of damage severity Hole ~ penetraCon exceeds 85% of nominal wall thickness Ring - damage area exceeds 60% of circumference, but depth range does not exceed 2 * pipe ID Line - damage depth range exceeds 12 * pipe ID, but extends ]ess fl~an 20'>/0 of circumference General - damage depth range exceeds 2 * pipe ID and/or extends more than 20% of circumference Isolated - damage depth range does not exceed 12 * pipe ID or extend more than 20% of circumference Damage repo[ting threshold = 30 thou inches deviation in body, 70 thou in upset Modal line length = 1.050 feet. penetration body metal loss body Damage profile (% wall) 50 100 Pipe Tabulations page 1 RECEIVED FEB l 6 2000 Ahchoraga Well: D-01 a Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Country: USA Tubing;: 4~5 ins 12.6 ppf U80 BTRS PDS Caliper Sections Survey Date: Feb. 10, 2000 Tool Type: MFC40 No. 99493 Tool Size: 2.75" No. of Fingers: 40 Analysed: J. Burton Cross section for Joint 27 at depth Tool speed = 65 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 39 % Tool deviation = 99 ° 10282.44 Finger 20 Radius = 2.534 ins AREA OF MAX. X~SECT~ONAL WALL LOSS & MOST SIGNIFICANT PENETRATION HIGH SIDE = UP Cross-Sections page 1 Well: D4)'I a Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Country: USA Tubinl~: 4.5 irs 12,6 ppf b80 BTRS PDS Caliper Sections Survey Date: Feb, 10, 2000 Tool Type: MFC40 No. 99493 Tool Size: 2.75" No, of Fingers: 40 Analysed: J. Burton Cross section for Joint 29 at depth Tool speed = 68 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 86 % Tool deviation = 105 ° RECEIVED 10344.39 1 Finger 12 Penetration = 0.262 ins PERFORATION 0.262 In. = 97% HIGH SIDE = UP Cross-Sections page 2 Well: D~01a Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Countw: USA Tubing;: 4.5 ins 12.6 ppf b80 BTRS PDS CaJiper Sections Survey Date: Feb. I0, 2000 Tool Type: MFC40 No. 99493 Tool Size: Z75" No. of Fingers: 40 Analysed: ]. Burton Cross section for Joint 27 Tool speed = 67 NomirlaJ ID = 3.958 Nominal OD = 4.500 Remaining wa}l area = 100 % Tool deviation = I01 ° at depth 10289 ft [ECEgVED Finger 2 Radius = 1.546 ins MOST SIGNIFICANT RESTRICTION MIN, ID = 3,33 In. HIGH SIDE = UP Cross-Sections page 3 Well: D-01 a Field: PRUDHOE BAY Company: BP EXPLORATION ALASI<A CoLmtry: LISA Tubinsi 4,5 ins /2,69Z~ L-80 BTRS PDS Caliper Sections Survey Date: Feb, 10, 2000 Tool Type: MFC40 No. 99493 Tool Size: 2.75" No. of Fingers; 40 Analysed: J, Burton Cross section for Joint 25 Tool speed = 66 Nominal ID = 3,958 Nominal OD = 4,500 Remaining walt area = 98 % Tool deviation = 76 ° Anchora.~e at depth 10172.28 ft Finge~ 14 Projection =43,482 ins DEPOSITS MIN. ID = 3.4 HIGH SIDE = UP Cross-Sections page 4 CALIPER JOINT TALLY SHEE-I Pipe: 4.5 ins 12.6 ppf L-80 BTRS Wall ~ickness. Body: 0.271ins Upset = 0.271ins Nominal ID: 3.958 ins Joint Depth Length Measured Type No. ID feet feet inches .1 9158.43 4.08 3.940 Pup 1 9162.51 41.83 3.953 2 9204.34 41.92 3.941 3 9246.26 41.88 3.936 4 9288.14 42.01 3.941 5 9330.15 42.23 3.937 6 9372.38 42.10 3.945 7 9414.48 42.03 3.939 8 9456.51 41.99 3.935 9 9498.50 42.3 7 3.947 10 9540.87 42.08 3.944 11 9582.95 40.45 3.948 12 9623.40 42.24 3.948 13 9665.64 42.01 3.932 14 9707.65 42.25 3.941 15 9749.90 42.17 3.931 16 9792.07 42.22 3.930 1 7 9834.29 42.18 3.934 18 9876.47 42.26 3.944 19 9918.73 42.03 3.945 20 9960.76 42.21 3.938 21 10002.97 42.08 3.946 22 10045.05 42.26 3.950 23 10087.31 41.96 3.963 24 10129.27 42.06 3.961 25 10171.33 41.44 3.946 26 10212.77 42.20 3.950 2 7 10254.97 41.97 nominal 28 10296.94 42.24 3.963 29 10339.18 4t.41 3.981 30 10380.59 42.28 3.984 31 10422.87 41.94 3.986 32 10464.81 40.31 3.987 33 10505.12 42.24 3.979 34 10547.36 unknown 3.966 Well: D-01 a Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Country: USA Date: Feb. 10, 2000 Joint Depth Length Measured Type No. ID feet feet inches Joint Tally page 1 Memory Multi-Finger Caliper Log Results Summary Company: BP Exploration (Alaska) Inc. Well: D-01a Log Date: Nov. 11, 1999 Field: Prudhoe Bay LOg No.: 1026 State: Alaska Run No.: 1 APl No.: 50-029-20054-01 Pipe Desc.: 4.5" 12.6 lb. Buttress Top Log Intvl: 9,450' Pipe Use: Horizontal Liner Bot. Log Intvl: 10,566' (MD) Inspection Type' Horizontal Liner Inspection for Source of Produced Rocks COMMENTS · This log was run on Coiled Tubing to assess the condition of the 4.5" Horizontal Liner for potential sources of rock production. The caliper recordings indicate a significant reduction in ID due to deposits or sand and gravel accumulations throughout the interval logged. Intermittent finger-motion impairment is indicated throughout a majodty of the interval 10,566' - 9,450', where the fingers appear to be experiencing temporary impaction with wellbore solids. The apparent finger motion impairments alternate to various fingers for limited time intervals throughout this interval. The caliper tool experienced an electronics failure, resulting in complete loss of coherent data in the intervals 9920' - 9916', 9910' - 9983', and 9450' - 8900' MD. Since this failure occurred pdor to reaching the tubing tail and wellbore jewelry, no correlation for accurate depth tie-in could be made. All depths presented are coiled-tubing measured depths. The unusually harsh wellbore conditions and ultimate electronics failure of the caliper tool make all of the recordings somewhat suspect. However, a majority of the recordings in the intervals where the tool was not in complete failure appear to be valid, based on recorded ID's and the likelihood of significant "gravel-like" accumulations in the wellbore. The characterization of the wellbore solids as "gravel-like" are supported by the numerous (small) gouges on one side of all of the tool housings upon removal from the wellbore, and the "gravel-like" appearance of the caliper recordings in the intervals 10566'-10414', 10409'-10396', 10393'- 10384', 10362'-10160', 10152'-10106', and 10044'-10003'. Though most of the liner wall is obscured by wellbore solids throughout the logged interval, there is a fairly definitive indication of a large hole, on the high side, @ 10,293'. This hole appears to be slightly larger than one inch in diameter, and is located within the perforated interval of the liner. There are also numerous indications of smaller holes in the interval 10450' - 10560', but accurate interpretation of these recordings is precluded by the uncertainty of the tool response when potentially immersed in loose wellbore solids. Minimum measured ID's for each joint logged are presented in the Joint Tabulation Sheet of this report, and eight cross-sectional drawings at representative locations in the liner are included in this report. Oil & G[,s Cons. Comm~r~ Anchorage I Field Engineer' J. Burton Analyst: Joey Burton Witness: Gary Nordlander I ProActive Diagnostic Se~/ices, Inc. / P.O. Box 1369, Stafford, -I7, 77497 Phone: (281) or (888) 565-9085 Fax: (28:1.) 565-~L369 E-mail: PDS@memowIog.com Prudhoe P.~ay Field Office Phone: (907) 65%2307 Fax: (907) 659-23:[4 Well: D431 a Field: Prudhoe Bay Company: BP Exploration (Alaska) Inc. Country: USA PDS Caliper Overview Body Region Analysis Survey Date: Nov. I 1, 1999 Tool l'ype: PDS 40Arm Memory Tool Size: 2.75 ins No, of Fil~gers: 40 Analysed: I, Burton Tubing: Size Weight Grade & Thread Nora. OD Nora. ID Nora,Upset 4.5 ins 12.6 pp~ i 80 Buttress 4.5 ins 3.958 ins 4.5 ins Penetration and Metal ~oss (% wall) ~ penetration body ~ metal [ass body 0 to 1 to 10 to 20 to 40 to above 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 29) Pene 22 0 0 0 0 7 Loss 29 0 0 0 0 0 Damage Con6gntation ( body ) Number of ioints damaged (total = 7) 0 0 0 0 Damage Profile (% wall) penet~a6on body ~ metal loss body 0 50 I00 27 Bottom of Survey = 35 Analysis Ovepview page Well: D-0ia Field: Prudhoe Bay Company: BIo Exploration (Alaska) Inc. Country: USA PDS Caliper Overview Upset Region Analysis Survey Date: Nov. II, 1999 Tool Type: PDS 40-Arm Memory Too[ Size: 2.75 ins No. of Fingers: 40 Analysed: I. Burton L Fubing: Size Weight Grade & Thread 4.5 ins 12.6 ppf L~80 Buttress Nora. OD Nora. ID Nom. Ul)set 4.5 ins 3.958 ins 4.5 ins Penetmfion and Me~al Loss (% wall) ~ penetration upset 2O I 0to I to 10to 20 to 40 to above 1% 10'% 20% 40% 85% 85% Number of ]ch~}2}j analysed (total - 29) Pene 29 0 0 0 0 0 Damage Configutatior~ ~lpse~ ) Number of ioints damaged (total = 6) 0 0 3 2 Damage Profile (% wall) penetration upset 0 5O / 7 27 Bottom ol Su~¥ey = 35 100 Analysis Overview page 3 PDS JOINT TABULATION Pipe: 4.5 ins 12.6 ppf L-80 Buttress Wall thickness. Body: 0.271ins Upset = 0,271ins Nominal ID: 3,958 ins Well: Field: Company: Country: Date: D-01 a Prudhoe Bay BP Exploration (Alaska) lnc, USA Nov. ti, 1999 penetration body metal loss body I4 [ 0 I7 30 33 Penetration Body .6I ID inches 0 BAD DATA. 0 BAD DATA. 0 BAD DATA. I leavy deposits. Idea:,,,, deposits. 3.04 3.04 3.04 IHeavy deposits, 3.04 IHeavy deposits. 3.03 i Heavy deposits. 2.92 IHeavy deposits. 2.92 I Heavy deposits. 2.99 IHeavy deposits. %04 IHeavY deposits. 3.02 ! BAD DAIWA & heavy deposits. 3.05 !tqeavy deposits. 2.95 l lqeavy deposits. 3.02 [ Heavy deposils. 3,06 Heavv deposils. 3.03 Heavv deposits. 3.09 !tteav¥ deposits.. 3.03 [tteavv deposits. 2.96 [Heavv deposits. 2.95 [ PERFORATIONS & heavy deposits. 3.02 PERFORATIONS & heavv ~12osits. 2.79 Heavv deposits. 3.15 [ Heaw deposits & Possible Holes. 2.93 Heavy deposits & Possible t t()tes, 2.93 ~ eavv deposits & Possible tqol~'s. 2,88 [ t teavv deposits & Possible I-toles~ 2.99 [ Heavy deposits & Possible Holes. lDamage profile (% wall) 50 I00 Damage Classifications Penetration / projection class, in order of damage severity I Iole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 50% of circumference, but deplh range does not exceed I * pipe ID Line - damage depth range exceeds 3 ~ pipe ID, but extends less than 20% of circu~nMence General - danlage depth range exceeds 1 * pipe ID and/or extends more than 20% of circumference Isolated - damage depth range does not exceed 3 * pipe ID or extend more than 20% of circumference Damage reporting threshold ~ 30 tlnou inches deviation in body, 50 thou in upset, Modal line lengtl~ = 0.178 feet. Pipe Tabulations page 1 PDS Caliper Sections Well: Field: Company: Country: Tubin D-01a Prudhoe Bay BP Exploration (Alaska) htc. USA 4.5 ins 12,6 p~j~. L-g0 Buttress Survey Date: Nov. 11, 1999 Tool Type: PDS 40-Arm Memory Tool Size: 2.75 ins No. of Fingers: 40 An alv_sed: ~ Burton Cross section for Joint 9 Toot speed = 48 Nominal ID ~ 3.958 Nominal OD = 4.500 Remaining wall area = 100 % Tool deviation: 29 ° at depth 9482 ft Finger 23 Radius = 1.548 ins HEAVY SAND/GRAVEL ACCUMULATION, Cross-Sections page 1 PDS Caliper Sections Well; D-01 a Field: Prudhoe Bay Company: BP Exploration (Alaska) Inc. Country: USA Tubing: 4.5 ins 12,60j.~f L-80 Buttress Survey Dale: Nov. 11, 1999 Tool Type: PDS 40Arm Memory Tool Size: 2.75 ins No. of Fingers: 40 Analysed: ~ Burton Cross section for Joint 15 at depth Tool speed = 49 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 100 % Tool deviation = 63 ° 9760 ft Finger 37 Radius = 1.558 ins HEAVY SAND/GRAVEL ACCUMULATION. Cross-Sections page 2 PDS Caliper Sections Well; D-01a Field: Prudhoe Bay Company; BP Exploration (Alaska) Inc. Cotlnlry: USA Tubings. 4.5 ins 12.6~ D80 Buttress SurYe¥ Date: Nov. 11, 1999 Toot Type: PDS 40-Arm Memory Tool Size: 2.75 ins No, of Fingers: 40 Analysed; J. Burton Cross section for Joint 18 at depth Tool speed = 46 Nominal ID = 3.958 Norainal OD = 4.500 Remaining wa][ area = 100 % Tool deviation = 66 ° 9870 ft Finger 38 Radius= 1.659ins HEAVY SAND/'GRAVEL ACCUMULATION. Cross~Sections page 3 PDS Caliper Sections Well: D-01a Field: Prudhoe Bay Company: BP Exploration (Alaska) Inc. Country: USA Tubin 4.5 ins 12.6 p_~ L-80 Buttress Survey Date: Nov, 11, 1999 Tool Type: PDS 40-Arm Memory Tool Size: 2.75 ins No. of Fingers: 40 Analysed: J. B LIl'toI1 Cross section for Joint 27 Tool speed = 43 Nominal ID = 3,958 Nominal OD = 4,500 Remaining wall area = 100 % Tool deviation = 68 ° at depth 10250 ft Finger 6 Radius = 1.706 ins HEAVY SAND/GRAVIL ACCUMULATION, Cross-Sections page 4 PDS Caliper Sections Well: D-01 a Field: Prudhoe Bay Company: BP Exploration (Alaska) Inc. Country: USA Tubing: 4.5 ins 12.6 ppf L-80 Buttress Survey Date: Nov. 11, 1999 Tool Type: PDS 40-Arm Memory Tool Size: 2.75 ins No. of Fingers: 40 Analysed: ). Burton Cross section for Joint 28 at depth Tool speed = 47 Nominal ID = 3.958 Nominal OD = 4.500 Remaining walt area = 100 % Tool deviation = 85 ° 10292.8 ft Finger 9 Radius = 2.148 ins LARGE PERFORATION IN AREA OF HEAVY DEPOSITS. Cross-Sections page PDS Caliper Sections Well: D-01a Field: Prudhoe Bay Company: BP E×ploration (Alaska) Inc. Country: USA Tubing: 4.5 ins 12.6 ppf L-80 Buttress Survey Date: Nov. 1 ~, 1999 Tool Type: PDS 40-Arm Memoir, Tool Size: 2.75 ins No. of Fingers: 40 Analysed: J. Burton Cross section for Joint 32 at depth Tool speed = 45 Nominal iD = 3.958 Nominal OD = 4~500 Remaining wall area ~ 1 O0 % Tool deviation = 99 ' 10460.09 ft Finger2I Radius= 1.883 ins POSSIBLE HOlE IN AREA OF HEAVY DEPOSITS BELOW PERFS, Cross-Sections page 7 PDS Caliper Sections Well: D-01 a Field: l~rudhoe Bay Company: BP Exploration (Alaska) Inc. Country: USA Tubin 4.5 ins 12.6j2pf 1-80 13u~tress Survey [Date: l ool Type: Tool Size: No, of Fingers: Analysed: Nov. 11,1999 PDS 40-Arm Memol¥ 2.75 ins 40 Budon Cross section for/oint 30 at depth Tool speed = 48 Nominal ID = 3,958 Nominal OD = 4,500 Remaining wall area = 100 % Tool deviation = 74 o 10370 ft Finger 16 Radius= 1,988ins AREA OF lESS SE\fiRE IDEPOSITS lUST BEIOVV PERF INTERVAl. PDS Caliper Sections Well: D-01 a Field: Prudhoe Bay Company: BP Exploration (Alaska) Inc. Country: USA Tubin 4.5 ins 12.6 ppf L-80 Buttress Survey Date: Nov. [ 1, t999 Tool Type: PDS 40-Arm Memory Tool Size: 2.75 ins No, of Fingers: 40 Analysed: I. Burton -~ros~' section for Joint 34 Tool speed = 45 Nominal ID = 3958 Nominal OD = 4.500 Remaining wall area = 100 % Fool deviation = 92 '~ at depth Finger 21 10512.53 ft Radius = 1.68 ins POSSIBLE HOLES IN AREA OF HEAVY DEPOSITS BELOVV PERFS. Cross-Sections page 8 PDS ALIPER JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 Buttress Wall thickness. Body: 0.271ins Upset = 0.271ins Nominal ID: 3.958 ins Joint Depth Length Measured Type No. ID feet feet inches 7 9395.10 39.70 nominal 8 9434.80 41.50 nominal 9 9476.30 39.01 nominal 10 9515.31 42.19 nominal 11 9557.50 42.12 nominal 12 9599.62 40.35 nominal 13 9639.97 42.18 nominal 14 9682.15 41.94 nominal 15 9724.09 42.13 nominal 16 9766.22 42.08 nominal 17 9808.30 42.15 nominal 18 9850.45 39.55 nominal 19 9890.00 40.00 nominal 20 9930.00 42.00 nominal 21 9972.00 44.00 nominal 22 10016.00 40.16 nominal 23 10056.16 42.15 nominal 24 10098.31 41.74 nominal 25 10140.05 42.00 nominal 26 10182.05 39.95 nominal 27 10222.00 37.00 nominal 28 10259.00 42.00 nominal 29 10301.00 42.01 nominal 30 10343.01 41.99 nominal 31 10385.00 43.00 nominal 32 10428.00 41.00 nominal 33 10469.00 41.36 nominal 34 10510.36 41.64 nominal 35 10552.00 unknown nominal Well: D-01 a Field: Prudhoe Bay Company: BP Exploration (Alaska) Inc. Country: USA Date: Nov. 11, 1999 Joint Depth Length Measured Type No. ID feet feet inches Joint Tally page 1 WELL PERMIT CHECKLISToo , Y WELL NA~.E P~ ~ ' ~//~ PROGRAM: expel dev~ redrl~servO wellbore segD ann disp para req[] ADMINISTRATION 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Y Lease number appropriate ................ Unique well name and number ............... Y Well located in a defined pool ............. Y Well located proper distance from drlg unit boundary. . . Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. . Can permit be approved before 15-day wait ........ ENGINEERING N N REMARKS A~PR DATE 14. Conductor string provided ............... ~ 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. . 17. CMT vol adequateto tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ 19. Casing designs adequate for C, T, B & permafrost .... ~ 20. Adequate tankage or reserve pit ............. ~ 21. If a re-drill, has a 10-403 for abndnmnt been approved. .Y 22. Adequate wellbore separation proposed .......... ~ 23. If diverter required, is it adequate ........... Y 24. Drilling fluid program schematic & equip list adequate .~_~ 25. BOPEs adequate ..................... ~ 26. BOPE press rating adequate; test to ~OOC3 psig.(~ 27. Choke manifold complies w/API RP-53 (Ma~ ~i . . .' . . 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. Y N N 30. Data presented on potential overpressure zones ..... ~/ N ~ Seismic analysis of shallow gas zones ........ ~/Y N Seabed condition survey (if off-shore) ...... /.. Y N Contact name/phone for weekly progress reports ~ . . . Y N [exploratory only] ~ GEOLOGY 31. 32. 33. 34. GEOLOGY: ENGINEERING: COMMISSION: JDH ~ mcm Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01/97 WELL PERMIT CHECKLISTco. Y GEOL AREA PROGRAM: expD dev~redr~servD wellbore seg~ ann disp para .reqD ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary. . N 6. Well located proper distance from other wells ...... N 7. Sufficient acreage available in drilling unit ...... N 8. If deviated, is wellbore plat included ......... N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... ].Y N 11. Permit can be issued without conservation order .... ~ N 12. Permit can be issued without administrative approval..~ N 13. Can permit be approved before 15-day wait ....... ~ N ENGINEERING REMARKS 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf cng. . Y N 17. CMT vol adequate to tie-in long string to surf cng . . . Y 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 ............ .~Y~ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .9 N 25. BOPEs adequate ............ ~ ........ ~ N 26. BOPE press rating adequate; test to ~O-O~ psig..y~ N 27. Choke manifold complies w/~I ~-53 (May 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 .... Y N/'_ 31. Data presented on potential overpressure zones ..... Y ~-- ~/ ~ 32. Seismic analysis of shallow gas zones .......... y N /~/( 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . ./ . Y N [exploratory only] GEOLOGY: ENGINEERING: ~SSION: Comments/Instructions: © 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. Sperry-Sun Drilling Services LIS Scan Utility Fri Aug 29 14:55:31 1997 Reel Header Service ns_me ............. LISTPE Date ..................... 97/08/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 97/08/29 Origin ................... STS Tape N~me ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-70149 NEUBAUER BORDES M Ci OF LMED D-01A 500292005401 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 29-AUG-97 MWD RUN 3 MWD RUN 4 AK-MW-70149 AK-MW-70149 NEUBAUER HENNINGSEN BORDES BORDES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: MWD RUN 4 AK-MW-70149 HENNINGSEN BORDES 23 lin 13E 2130 1067 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROLrND LEVEL: WELL CASING RECORD OPEN HOLE 66.00 64.40 31.90 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 9.625 1886.0 3RD STRING 7.000 9322.0 PRODUCTION STRING 6.000 10670.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH SCINTILLATION TYPE GTuMMA RAY (NGP). 4. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. A CHANGE FROM SCINTILLATION TYPE GAMMA RAY (NGP) TO DUAL GAMMA RAY (DGR) OCCURRED AT 10058'MD, 8943'TVD. 6. A PIEASURMENT AFTER DRILLING (MAD) PASS WAS PERFORMED WHILE TRIPPING OUT OF THE HOLE AFTER MWD RUN 4. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10670'MD, 9072'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 SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP -- SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHILE NOT DRILLING. ALL CURVES WITH THE EXTENTION "M" ARE MEASURED AFTER DRILLING (MAD). $ File Header Service na~ne ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPM RPS RPX RPD $ Depth shifted and clipped curves; all bit runs merged. .5000 START DEPTH STOP DEPTH 9278.5 10628.0 9340.0 10670.5 10029 . 5 10635 . 0 10029.5 10635.0 10029.5 10635.0 10029.5 10635.0 10030.5 10635.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9278.5 9279.5 9283 . 0 9288 5 9292 0 9296 0 9300 5 9307 0 9310 0 9313 0 9315.0 9317 5 9321 5 9323 5 9325 0 9327 0 9332 5 9335 0 9338.5 9355.0 9357.5 9362.0 9364 0 9375 0 9383 5 9388 0 9390 0 9393 0 9399 5 9402 5 9406 5 9417 0 9422 0 9424 0 9426 0 9431 0 9433 5 9451 0 9453.0 9462.0 9476.0 9480.5 GR 9277.5 9278.5 9282.0 9287.5 9290.5 9295.0 9300.0 9306.0 9309.5 9313.5 9315.0 9318.0 9322.0 9324.5 9326.0 9328.0 9333.0 9336.0 9339.0 9356.0 9357.5 9362.0 9364.5 9376 0 9385 0 9389 0 9391 5 9394 5 9400 5 9404 0 9408 0 9419 5 9423 0 9424 5 9426 5 9432 0 9435 0 9452 5 9454 5 9461 5 9476 5 9482 5 EQUIVALENT UNSHIFTED DEPTH --, 9484.0 9487.5 9491.5 9494.0 9503 .5 9507 0 9509 5 9513 0 9515 5 9517 5 9521 5 9527 0 9532 0 9536 0 9539 0 9541 5 9556 5 9562 0 9571 0 9592 5 9598.0 9600.5 9611.0 9621.0 9660.0 9664.0 9666.5 9669.5 9673.0 9683.0 9687.0 9694 0 9696 0 9699 0 97 03 5 9707 5 9712 0 9715 0 9726 0 9730 5 9735 5 9744 5 9772 0 9775 0 9786 0 9791 0 9803 5 9838 0 9842 0 9844 5 9937 5 9939 0 9970 0 9973 5 9978 0 9983 5 9987 0 9990 5 10006 0 10019 0 9485 9488 9492 9495 9505 9509 9511 9515 9517 9518 9521 9530 9533 9538 9542 9543 9560 9565 9574 9595 9600 9603 9613 9622 9661 9665 9668 9670 9673 9684 9688 9694 9698 9701 9706 9710 9713 9717 9726 9732 9736 9744 9773 9776 9785 9789 9801 9841 9844 9848 9937 9939 9971 9975 9979 9984 9986 9989 10005 10020 5 0 5 5 5 0 .5 0 5 5 5 0 5 5 .0 .0 .0 .0 .0 .0 .0 .0 .5 .0 .0 5 0 5 5 0 0 5 5 5 0 5 0 0 5 0 5 5 5 0 5 0 0 5 0 5 0 0 0 0 0 0 5 0 5 0 10023 0 10024 5 10030 5 10034 5 10044 0 10052 0 10058 5 10064 5 10087.0 10091 5 10094 5 10097 5 10173 0 10181 5 10184 5 10427 5 10434.5 10438 0 10447 5 10452 5 10459 0 10462 5 10468 0 10474 0 10514 0 10518 5 10528 5 10537 0 10541 0 10549 5 10559.5 10570.0 10670.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 10023.5 10026.0 10032.0 10035.0 10047.0 10053.0 10060.5 10064.5 10087.5 10091 5 10095 0 10098 5 10172 5 10180 5 10183 0 10428.0 10435 0 10438 0 10447 0 10451 0 10458 0 10462 5 10467 0 10473 0 10513 5 10518 0 10527 5 10536 0 10539.5 10550.5 10559.5 10569.5 10670.0 BIT RUN NO MERGE TOP MERGE BASE 2 9341.0 9803.0 3 9803.0 10121.0 4 10121.0 10670.0 MERGED MAIN PASS. $ 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 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RP S MWD OHFiM 4 1 68 - RPM MWD O}{MM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 8 12 16 20 24 28 Name Min Max Mean Nsam DEPT 9278.5 10670.5 9974.5 2785 ROP 10.6893 890.29 67.4444 2662 GR 15.7136 589.66 38.7821 2700 RPX 1. 6874 19. 1388 6. 52042 1212 RPS 2.1301 29.1767 8.53626 1212 RPM 2. 644 119. 922 10. 1246 1212 RPD 3.2016 46.4908 11.7459 1210 FET 0. 5218 22. 4021 4. 02223 1212 First Reading 9278.5 9340 9278.5 10029.5 10029.5 10029.5 10030.5 10029.5 Last Reading 10670.5 10670.5 10628 10635 10635 10635 10635 10635 First Reading For Entire File .......... 9278.5 Last Reading For Entire File ........... 10670.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/29 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 ....... 97/08/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 9548.0 FET 9554.0 RPD 9554.0 STOP DEPTH 10630.5 10637.5 10637.5 RPM RPS RPX RAT $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: 9554.0 10637.5 9554.0 10637.5 9554.0 10637.5 9591.0 10673.5 MAD RUN NO. MAD PASS NO. 4 MERGED MAD PASS. $ # 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 TOP 10121.0 Name Service ©rder Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD AAPI 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHlV/M 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHlV/M 4 1 68 24 7 FET MAD OHMlVi 4 1 68 28 8 MERGE BASE 10670.0 First Name Min Max Mean Nsam Reading DEPT 9548 10673.5 10110.8 2252 9548 RAT 228.076 1982.81 298.325 2166 95~1 GR 12.7697 134.545 35.2067 2166 9548 RPX 1.8905 24.875 6.73846 2168 9554 RPS 2.1822 52.4378 10.8774 2168 9554 RPM 2.3919 64.503 15.4427 2168 9554 RPD 3.1695 99.6188 22.9346 2168 9554 FET 2.9985 53.2 31.3473 2168 9554 Last Reading 10673 5 10673 5 10630 5 10637 5 10637 5 10637 5 10637 5 10637 5 First Reading For Entire File .......... 9548 Last Reading For Entire File ........... 10673.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/29 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 ....... 97/08/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NIIMBER: 2 DEPTH INCREMENT: .5000 FILE SUMM~Y VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9277.5 9739.0 ROP 9341.0 9802.0 $ LOG HEADER DATA DATE LOGGED: 26-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9803.0 TOP LOG INTERVAL (FT): 9341.0 BOTTOM LOG INTERVAL (FT) : 9803.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 28.9 - MAXIMUM ANGLE: 70.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL AIUMBER NGP 77 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): QUIKDRILN 8.70 59.0 9.0 28000 15.8 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 .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 56.2 First Name Min Max Mean Nsam Reading DEPT 9277.5 9802 9539.75 1050 9277.5 GR 24.79 589.66 46.5348 924 9277.5 ROP 11.44 251.65 57.4544 923 9241 -- First Reading For Entire File .......... 9277.5 Last Reading For Entire File ........... 9802 Las t Reading 9802 97'39 9802 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/29 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 ....... 97/08/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE ~ER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SIIMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9740.0 10058.0 ROP 9803 . 5 10120 . 5 $ LOG HEADER DATA DATE LOGGED: 26-MAY-97 SOFTWARE SURFACE 'SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 10121.0 TOP LOG INTERVAL (FT) : 9803.0 BOTTOM LOG INTERVAL (FT): 10121.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 68.6 MA_XIMUMANGLE: 65.1 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): TOOL,NUMBER NGP 77 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MI3D 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: QUIKDRILN 8.70 58.0 9.0 31000 15.4 .000 .000 .000 .000 61.0 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 .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 MK~ 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9740 10120.5 9930.25 762 9740 GR 26.33 114.11 38.7904 637 9740 ROP 13.63 890.29 55.8878 635 9803.5 Last Reading 10120.5 10058 10120.5 First Reading For Entire File .......... 9740 Last Reading For Entire File ........... 10120.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/29 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 ....... 97/08/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 CoImment 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 STOP DEPTH FET 10031 . 0 10634 . 5 RPM 10031 . 0 10634 . 5 RPS 10031 . 0 10634 . 5 RPX 10031 . 0 10634 . 5 RPD 10032 . 0 10634 . 5 GR 10058 . 5 10627 . 5 ROP 10116 . 0 10670 . 0 $ LOG HEADER DATA DATE LOGGED: 28-MAY- 97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10670.0 TOP LOG INTERVAL (FT): 10121.0 BOTTOM LOG INTERVAL (FT) : 10670.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 67.6 MAXIMIIM ANGLE: 85.9 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) : TOOL NUMBER P0743SP4 P0743SP4 6.000 6.0 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: QUIKDRILN 8.70 57.0 9.0 31000 14.8 .100 .057 .090 .120 65.6 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 ....................... Datu/n Specification Block sub-type...0 .0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 4 AAPI 4 1 68 RPX MWD 4 OHMM 4 1 68 RPS MWD 4 OHMM 4 1 68 RPM MWD 4 OHlVIM 4 1 68 RPD MWD 4 OH~iM 4 1 68 ROP MWD'4 FT/H 4 1 68 FET MWD 4 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 10031 10670 10350.5 GR 15.7136 118. 626 32.2733 RPX 1. 6874 19. 1388 6.47692 RPS 2.1301 29.1767 8. 48212 RPM 2. 644 2000 18. 1221 RPD 3. 2016 46.4908 11. 6812 ROP 10. 6893 476.04 85. 975 FET 0. 5218 22. 4021 4. 01609 Nsa~ 1279 1139 1208 1208 1208 1206 1109 1208 First Reading 10031 10058.5 10031 10031 10031 10032 101%6 10031 Las t Reading 10670 10627.5 10634.5 10634.5 10634.5 10634.5 10670 10634.5 First Reading For Entire File .......... 10031 Last Reading For Entire File ........... 10670 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/29 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 ....... 97/08/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .S000 MAD RUN ~ER: 4 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9550 5 FET 9557 5 RPM 9557 5 RPS 9557 5 RPX 9557 5 RPD 9557 7 RAT 9594.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (F?): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMIIMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 10630.0 10637.0 10637.0 10637.0 10637.0 10637.0 10673.0 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): 28 -MAY- 97 5.06 5.03 MEMORY 10670.0 10121.0 10670:0 -- 67.6 85.9 TOOL NUMBER P07435P4 P0743SP4 6.000 6.0 QUIKDRILN 8.70 57.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS4) 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 9.0 31000 14.8 .100 .057 .090 .120 .0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD 4 FT/H 4 1 68 GR MAD 4 AAPI 4 1 68 RPX MAD 4 OH~M 4 1 68 RPS MAD 4 OHMM 4 1 68 RPM MAD 4 OHMS4 4 1 68 RPD MAD 4 OHMM 4 1 68 FET MAD 4 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 65.6 Name Min Max Mean Nsam DEPT 9550.5 10673 10111.8 2246 RAT 228.076 1982.81 298.238 2159 GR 12.7697 134.545 35.0532 2160 RPX 1.8905 30.4418 6.74424 2160 RPS 2.1822 52.4378 10.9125 2160 RPM 2.3919 64.503 15.487 2160 RPD 3.1695 101.238 23.0128 2160 FET 2.9985 53.2 31.3115 2160 First Reading 9550.5 9594 9550.5 9557.5 9557.5 9557.5 9557.5 9557.5 Last Reading 10673 10673 10630 10637 10637 10637 10637 10637 First Reading For Entire File .......... 9550.5 Last Reading For Entire File ........... 10673 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UAIKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/08/29 Origin .... ~ .............. STS Reel Name ................ UAYKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * . . ****************************** * ............................ * * ....... SCHLUMBERGER ....... * * ............................ * ****************************** RECEIVED SEP 1 1 1997 Alaska Oil & Gas Cons. Commis.sior: Anchorage COMPANY NAME : BP EXPLORATION WELL NAIVE : D- O1A FIELD NAIVE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMB~ : 500292005401 REFERENCE NO : 97276 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION WELL NAME : D-O1A FIELD NAFiE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API ~ER : 500292005401 REFERENCE NO : 97276 LIS Tape Verification Listing Schlumberger Alaska Computing Center i0-SEP-1997 10:25 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/09/10 ORIGIN · FLIC REEL NAME : 97276 CONTINUATION # : PREVIOUS REEL : CO~ · B.P. EXPLORATION, D-O1A, PRUDHOE BAY, API #50-029-20054-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/09/10 ORIGIN · FLIC TAPE NAME : 97276 CONTINUATION # : 1 PREVIOUS TAPE : COMME~Ff · B.P. EXPLORATION, D-O1A, PRUDHOE BAY, API #50-029-20054-01 TAPE HEADER Prudhoe Bay OPEN HOLE WIRELINE LOGS WELL NAME: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NOFIBER : LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: RUN 1 97276 H. KIRKBY J. SALLEE TOWNSHIP: RANGE: FNL: FSL : FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING D-O1A 500292005401 BP Exploration SCHLUMBERGER WELL SERVICES 9-SEP-97 RUN 2 RUN 3 23 liN 13E 2130 1067 65.95 64.45 31.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 7.000 9298.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 3RD STRING PRODUCTION STRING CONTAINED HEREIN IS THE DATA ACQUIRED ON BP EXPLORATION WELL D-O1A ON 29-MAY-97. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSZON · oo~col DATE · 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUt4MARY LDWG TOOL CODE AIT BCS CNT SDN $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 10641.0 9300.0 10605.0 9300.0 10622.0 9300.0 10635.0 9300.0 BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: .......... EQUIVALENT UNSHIFTEDDEPTH .......... AIT BCS CNT SDN ............................ RUN NO. PASS NO. blERGE TOP MERGE BASE ................... THIS FILE CONTAINS THE CLIPPED AND EDITED DATA FROM THE ARRAY INDUCTION TOOL (AIT) , BOREHOLE COMPENSATED SONIC TOOL (BCS) , AND PLATFORM EXPRESS COMPENSATED NEUTRON TOOL (CNT) AND LITHO-DENSITY TOOL (SDN) . NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL. 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 10~SEP-1997 10:25 PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELE~ CODE (HEX) DEPT FT 645392 O0 000 O0 0 1 1 1 4 68 0000000000 GR AIT GAPI 645392 O0 000 O0 0 1 1 1 4 68 0000000000 TENS AIT LB 645392 O0 000 O0 0 1 1 1 4 68 0000000000 TEND AIT LB 645392 O0 000 O0 0 1 1 1 4 68 0000000000 f4RES AIT 0H~645392 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMAIT DEGF 645392 O0 000 O0 0 1 1 1 4 68 0000000000 DEV AIT DEG 645392 O0 000 O0 0 i 1 1 4 68 0000000000 CNTC CNT CPS 645392 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 645392 O0 000 O0 0 1 1 1 4 68 0000000000 FCNTCNT CPS 645392 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 645392 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT 645392 O0 000 O0 0 1 1 1 4 68 0000000000 NRATCNT 645392 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 645392 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNT PU-S 645392 O0 000 O0 0 1 1 1 4 68 0000000000 DT BCS US/F 645392 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 645392 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 645392 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 645392 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 645392 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN 0H~645392 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUP~ SAMP ELE~ CODE (HEX) MINVSDN OH~ 645392 O0 000 O0 0 1 1 1 4 68 0000000000 FINORSDN OH~ 645392 O0 000 O0 0 1 1 1 4 68 0000000000 AFiO AIT OPiM~645392 O0 000 O0 0 1 1 1 4 68 0000000000 AF20 AIT OH~ 645392 O0 000 O0 0 1 1 1 4 68 0000000000 AF30 AIT OPIUM 645392 O0 000 O0 0 1 1 1 4 68 0000000000 AF60 AIT 0H~4~645392 O0 000 O0 0 1 1 1 4 68 0000000000 AF90 AIT Oh?4~ 645392 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10652.000 GR.AIT -999.250 TENS.AIT FiRES.AIT -999.250 MTEM. AIT -999.250 DEV. AIT CFTC. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT NTRAT. CNT -999.250 NPHI.CNT -999.250 CPHI.CNT CAL1.SDN -999.250 DRHO.SDN -999.250 PEF. SDN MSFL.SDN -999.250 MINV. SDN -999.250 RINOR.SDN AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT DEPT. 9300.000 GR.AIT 60.615 TENS.AIT MRES.AIT 0.030 MTEM. AIT 32.000 DEV. AIT CFTC. CNT 541.737 FCNT. CNT 495.041 NCNT. CNT NRAT. CNT 3.117 NPHI.CNT 36.538 CPHI. CNT CAL1.SDN 6.464 DRHO.SDN 0.702 PEF. SDN MSFL.SDN 0.051 MINV. SDN 0.038 ~4NOR.SDN AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT 1892.000 TEND.AIT -999.250 CNTC. CNT -999.250 CRAT. CNT -999.250 DT.BCS -999.250 RHOB.SDN -999.250 AFiO.AIT -999.250 AF90.AIT 1013.000 TEND.AIT 29.391 CNTC. CNT 1533.125 CRAT. CNT 34.048 DT. BCS 10.000 RHOB.SDN 0.038 AFIO.AIT -999.250 AFgO.AIT 521.545 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1299.263 1554.318 2.998 66.500 4.330 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: **** FILE HEADER **** FILE NAFIE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER: 2 EDITED CASED HOLEMAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUB~rzARY LDWG TOOL CODE START DEPTH CArT 9300.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (M~ASUREDDEPTH) STOP DEPTH 9188.0 BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... CNT ....... THIS FILE CONTAINS THE CLIPPED AND EDITED DATA FROM THE PLATFORM EXPRESS COMPENSATED NEUTRON TOOL (CNT) . NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL. THE DATA IN THIS FILE WAS ACQUIRED ONLY OVER THE CASED-HOLE SECTION OF THIS LOGGING RUN. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 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 ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~ SAMP ELEM CODE (HEX) DEPT FT 645392 O0 000 O0 0 2 1 1 4 68 0000000000 TENS AIT LB 645392 O0 000 O0 0 2 1 1 4 68 0000000000 TEND AIT LB 645392 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH AIT GAPI 645392 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS 645392 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS 645392 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CAlf CPS 645392 O0 000 O0 0 2 1 1 4 68 0000000000 NCNTCNT CPS 645392 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNT 645392 O0 000 O0 0 2 1 1 4 68 0000000000 1FRAT CNT 645392 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNT PU-S 645392 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNT PU-S 645392 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9300.000 TENS.AIT 1013.000 TEND.AIT 1299.263 GRCH.AIT CNTC. CNT 1554.318 CFTC. CNT 541.737 FCNT. CNT 495.041 NCNT. CNT CRAT. CNT 2.998 NRAT. CNT 3.117 NPHI.CNT 36.538 CPHI.CNT DEPT. 9188.000 TENS.AIT 551.000 TEND.AIT 1192.361 GRCH.AIT CNTC. CNT 1049.769 CFTC. ClFT 246.404 FCNT. CNT 257.781 NCNT. CNT CRAT. CNT 4.349 NRAT. CNT 4.776 NPHI.CNT 61.513 CPHI.CNT 60.615 1533.125 34.048 64.452 1108.746 57.958 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUM~ER: TOOL STRING NLrM~ER: PASS--ER: DEPTH INC~: FILE SUMIVLA~Y FILE HEADER FILE NUMBER 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 1 0.5000 VEArDOR TOOL CODE START DEPTH STOP DEPTH AIT 10660.0 9300.0 BHC 10660.0 9300.0 PEX 10660.0 9300.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIldE CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPP~R) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 29-MAY-97 8C0- 609 1100 28-MAY-97 1530 29-MAY-97 10670.0 10660.0 9304.0 10624.9 1800.0 TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: AMS PEX AIT $ AUX. MEAS. SONDE PLATFORM EXPRESS ARRAY INDUCTION TOOL AMS-A HILTB-DTB AIT-H 122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 9298.0 9305.0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRILN MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) : 58.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 207.0 RESISTIVITY (0H~94) AT TEMPERATURE (DEGF) : MUD AT FiEASURED TEMPERATURE (MT): O. 100 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): 0.100 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 120 MUD CAKE AT (BHT) : 68.0 68.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 6. 000 TOOL STANDOFF (IN): 0.5 REMARKS: RIG: DOYON 141 HOLEFINDERRUNON BOTTOM OF AITH TWO STANDOFFS ON AITH FOUR STANDOFFS ON SONIC MAXIMUM DEVIATION 85.9 DEGREES MAXIMUM DOGLEG SEVERITY29.6 DEGREES/IOOFT DRILL PIPE CONVEYED LOGGING DEPTH REFERENCE: TIED INTO ORIGINAL D-O1A LOGS DATED 2-28-70 (SWS OPEN HOLE LOGS) AT CLIENTS REQUEST. SONIC CHECKED IN CASING READING 57 US/M CEMENT VOLUME BASED ON 4.5" PRODUCTON CASING CALIPER OPENED ONCE TOOLS MOVING OFF BOTTOM THIS IS THE RAW (OPEN HOLE) MAIN PASS AIT/BHC/PEX DATA PRESENTED AT 0.5' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 140 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 7 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) DEPT FT 645392 O0 000 O0 0 3 1 1 4 68 0000000000 GR AIT GAPI 645392 O0 000 O0 0 3 1 1 4 68 0000000000 TENS AIT LB 645392 O0 000 O0 0 3 1 1 4 68 0000000000 HTElVAIT LB 645392 O0 000 O0 0 3 1 1 4 68 0000000000 FIRES AIT 0H~645392 O0 000 O0 0 3 1 1 4 68 0000000000 MTEMAIT DEGF 645392 O0 000 O0 0 3 1 1 4 68 0000000000 GDEVAIT DEG 645392 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC PEX CPS 645392 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC PEX CPS 645392 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT PEX CPS 645392 O0 000 O0 0 3 1 1 4 68 0000000000 RCNTPEX CPS 645392 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA PEX 645392 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR PEX 645392 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH PEX PU 645392 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI PEX PU 645392 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR PEX PU 645392 O0 000 O0 0 3 1 1 4 68 0000000000 DT BHC US/F 645392 O0 000 O0 0 3 1 1 4 68 0000000000 TT1 BHC US 645392 O0 000 O0 0 3 1 1 4 68 0000000000 TT2 BHC US 645392 O0 000 O0 0 3 1 1 4 68 0000000000 TT3 BHC US 645392 O0 000 O0 0 3 1 1 4 68 0000000000 TT4 BHC US 645392 O0 000 O0 0 3 1 1 4 68 0000000000 HCAL PEX IN 645392 O0 000 O0 0 3 1 1 4 68 0000000000 RHOZ PEX G/C3 645392 O0 000 O0 0 3 1 1 4 68 0000000000 HDRA PEX G/C3 645392 O0 000 O0 0 3 1 1 4 68 0000000000 PEFZ PEX 645392 O0 000 O0 0 3 1 1 4 68 0000000000 DPHZ PEX PU 645392 O0 000 O0 0 3 1 i 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 10 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) O0 000 O0 0 3 1 1 4 68 0000000000 HMIN PEX OH~4~ 645392 HFiNO PEX OHT4~ 645392 O0 000 O0 0 3 1 1 4 68 0000000000 RXOZ PEX OP~4~ 645392 O0 000 O0 0 3 1 1 4 68 0000000000 RX08 PEX OH~ 645392 O0 000 O0 0 3 1 1 4 68 0000000000 AFiO AIT OH~ 645392 O0 000 O0 0 3 1 1 4 68 0000000000 AF20 AIT OH~ 645392 O0 000 O0 0 3 1 1 4 68 0000000000 AF30 AIT OH~ 645392 O0 000 O0 0 3 1 1 4 68 0000000000 AF60 AIT OH~4M 645392 O0 000 O0 0 3 1 1 4 68 0000000000 AFgO AIT OH~ 645392 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10660.000 GR.AIT 58.235 TENS.AIT 1856.000 HTEN. AIT MRES~AIT 0.025 MTEM. AIT 216.527 GDEV. AIT -999.250 CNTC. PEX CFTC. PEX 1716.588 RCFT. PEX 1590.560 RCNT. PEX 3094.295 TNRA.PEX RTNR.PEX 1.936 TNPH. PEX 18.745 NPHI.PEX 20.727 NPOR.PEX DToBHC 88.800 TT1.BHC 548.800 TT2.BHC 368.400 TT3.BHC TT4oBHC 357.600 HCAL.PEX 4.090 RHOZ.PEX -999.250 HDRA.PEX PEFZ.PEX -999.250 DPHZ.PEX 60721.211 HI4IN. PEX 0.088 H~NO.PEX RXOZ.PEX 0.786 RXO8.PEX 0.788 AFiO.AIT 2.398 AF20.AIT AF30~AIT 3.843 AF60.AIT 6.227 AF90.AIT 6.248 DEPT. 9300.000 GR.AIT 60.615 TENS.AIT 1013.000 HTEN.AIT FiRES.AIT 0.030 MTE~.AIT 32.000 GDEV. AIT 29.391 CNTC. PEX CFTC. PEX 541.737 RCFT. PEX 495.041 RCNT. PEX 1533.125 TNRA.PEX RT1FR.PEX 3.117 TNPH. PEX 34.048 NPHI.PEX 36.538 NPOR.PEX DT. BHC 66.500 TT1.BHC 423.600 TT2.BHC 301.600 TT3.BHC TT4.BHC 297.600 HCAL.PEX 6.464 RHOZ.PEX 4.330 HDRA.PEX PEFZoPEX 10°000 DPHZ.PEX -101.824 HI~IN. PEX 0.038 HPINO.PEX RXOZ.PEX 0.051 RXO8.PEX 0.049 AFIO.AIT 0.124 AF20.AIT AF30.AIT 0.137 AF60.AIT 0.071 AF90.AIT 0.191 455.019 3123.645 1.841 18.504 532.400 -999.250 0.128 2.653 1299.263 1554.318 2 998 33 877 423 200 0 702 0 038 0 251 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 11 **** FILE HEADER **** FILE NAM~ : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~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 1 0.2500 RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INC~: FILE SUA~/~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 10660.0 9300.0 BHC 10660.0 9300.0 PEX 10660.0 9300.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VEATDOR TOOL CODE TOOL TYPE ......................... AMS AUX. Z4EAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION TOOL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 29-MAY-97 8C0- 609 1100 28-MAY-97 1530 29-MAY-97 10670.0 10660.0 9304.0 10624.9 1800.0 TOOL NUMBER AMS - A HILTB -DTB AIT-H 122 6.000 9298.0 9305.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 12 BOREHOLE CONDITIONS MUD TYPE: QUIKDRILN MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) : 58.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 207.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEAS~ TEMPERATURE (MT): O. 1 O0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 100 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 120 MUD CAKE AT (BHT) : 68.0 68.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 6. 000 TOOL STANDOFF (IN): O. 5 REMARKS: RIG: DOYON 141 HOLEFINDER RUN ON BOTTOM OF AITH TWO STANDOFFS ON AITH FOUR STANDOFFS ON SONIC MAXIMUM DEVIATION 85.9 DEGREES MAXIMUM DOGLEG SEVERITY29.6 DEGREES/iOOFT DRILL PIPE CONVEYED LOGGING DEPTH REFERENCE: TIED INTO ORIGINAL D-O1A LOGS DATED 2-28-70 (SWS OPEN HOLE LOGS) AT CLIENTS REQUEST. SONIC CHECKED IN CASING ~ING 57 US/M CEMENT VOLU~EBASED ON 4.5" PRODUCTON CASING CALIPER OPENED ONCE TOOLS MOVING OFF BOTTOM THIS IS THE RAW (OPEN HOLE) MAIN PASS AIT/BHC/PEX DATA 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 24 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 13 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.25 9 65 FT 11 66 42 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 NUM~ SAMP ELEM CODE (HEX) DEPT FT 645392 O0 000 O0 0 4 1 1 4 68 0000000000 AFiO AIT 0~645392 O0 000 O0 0 4 1 1 4 68 0000000000 AF20 AIT OHIVlM 645392 O0 000 O0 0 4 1 1 4 68 0000000000 AF30 AIT OHPIM645392 O0 000 O0 0 4 1 1 4 68 0000000000 AF60 AIT 0~645392 O0 000 O0 0 4 1 1 4 68 0000000000 AF90 AIT OI4Fil~ 645392 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10660.000 AFIO.AIT 2.398 AF20.AIT AF60.AIT 6.227 AF90.AIT 6.248 2.653 AF30.AIT 3. 843 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 14 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER 5 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 NUMBER: 1 TOOL STRING NUM~ER: 1 PASS NUM~ER: 1 DEPTH INCREM~J~f: 0.1667 FILE SUMMARY VENDOR TOOL CODE START DEPTH AIT 10660.0 BHC 10660.0 PEX 10660.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIFIE CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH 9300.0 9300.0 9300.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. ~4EAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION TOOL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 29-MAY-97 8C0- 609 1100 28-MAY-97 1530 29-MAY-97 10670.0 10660.0 9304.0 10624.9 1800.0 TOOL NUMBER ........... AMS-A HILTB-DTB AIT-H 122 6.000 9298.0 9305.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 15 BOREHOLE CONDITIONS MUD TYPE: QUIKDRILN MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) : 58.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 207.0 RESISTIVITY (OB~4~) AT TEMPERATURE (DEGF) : MUD AT f~=ASURED TEMPERATURE (MT): 0.100 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 0.100 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 120 MUD CAKE AT (BHT) : 68.0 68.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 6. 000 TOOL STANDOFF (IN): 0.5 REMARKS: RIG: DOYON 141 HOLEFINDER RUN ON BOTTOM OF AITH TWO STANDOFFS ON AITH FOUR STANDOFFS ON SONIC MAXIMUM DEVIATION 85.9 DEGREES MAXIMUM DOGLEG SEVERITY29.6 DEGREES/IOOFT DRILL PIPE CONVEYED LOGGING DEPTH REFERENCE: TIED INTO ORIGINAL D-O1A LOGS DATED 2-28-70 (SWS OPEN HOLE LOGS) AT CLIENTS REQUEST. SONIC CHECKED IN CASING READING 57 US/M CEMENT VOLUME BASED ON 4.5" PRODUCTON CASING CALIPER OPENED ONCE TOOLS MOVING OFF BOTTOM THIS IS THE RAW (OPEN HOLE) MAIN PASS AIT/BHC/PEX DATA 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 16 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.166 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHA1V ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 645392 O0 000 O0 0 5 1 1 4 68 0000000000 RHOZ PEX G/C3 645392 O0 000 O0 0 5 1 1 4 68 0000000000 H~RA PEX G/C3 645392 O0 000 O0 0 5 1 1 4 68 0000000000 PEFZ PEX 645392 O0 000 O0 0 5 1 1 4 68 0000000000 DPHZ PEX PU 645392 O0 000 O0 0 5 1 1 4 68 0000000000 H~IN PEX OH~4~ 645392 O0 000 O0 0 5 1 1 4 68 0000000000 H~iNO PEX OH~4~ 645392 O0 000 O0 0 5 1 1 4 68 0000000000 RXOZ PEX OH~4~ 645392 O0 000 O0 0 5 1 1 4 68 0000000000 RX08 PEX OPHv~I645392 O0 000 O0 0 5 1 1 4 68 0000000000 HCNT PEX CPS 645392 O0 000 O0 0 5 1 1 4 68 0000000000 HCFT PEX CPS 645392 O0 000 O0 0 5 1 1 4 68 0000000000 HGR PEX GAPI 645392 O0 000 O0 0 5 1 1 4 68 0000000000 RHFT PEX CPS 645392 00 000 O0 0 5 1 1 4 68 0000000000 RHNTPEX CPS 645392 O0 000 O0 0 5 1 1 4 68 0000000000 HTNP PEX PU 645392 O0 000 O0 0 5 1 1 4 68 0000000000 H1VPOPEX PU 645392 O0 000 O0 0 5 1 1 4 68 0000000000 TT1 BHC US 645392 O0 000 O0 0 5 1 1 4 68 0000000000 TT2 BHC US 645392 O0 000 O0 0 5 1 1 4 68 0000000000 TT3 BHC US 645392 O0 000 O0 0 5 1 1 4 68 0000000000 TT4 BHC US 645392 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10660.000 RHOZ.PEX -999.250 HDRA.PEX -999.250 PEFZ.PEX DPHZ.PEX 60721.211 H~IN. PEX 0.088 H~iNO.PEX 0.128 RXOZ.PEX RXO8.PEX 0.788 HCNT. PEX 3123.645 HCFT. PEX 1716.588 HGR.PEX RHFT. PEX 1590.560 PJ{NT. PEX 3094.295 HTNP.PEX 18.745 HNPO.PEX TT1.BHC 548.800 TT2.BHC 368.400 TT3.BHC 532.400 TT4.BHC -999.250 0.786 58.235 18.504 357.600 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 17 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .006 SERVICE . FLIC VERSION · O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUF~WlARY FILE HEADER FILE NIIM~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. 1 1 1 0.0833 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 10660.0 9300.0 BHC 10660.0 9300.0 PEX 10660.0 9300.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TDDRILLER (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 29-MAY-97 8C0-609 1100 28-MAY-97 1530 29-MAY-97 10670.0 10660.0 9304.0 10624.9 1800.0 TOOL NUMBER ........... LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 18 AMS PEX AIT $ AUX. MEAS. SONDE PLATFORM EXPRESS ARRAY INDUCTION TOOL AMS - A HILTB-DTB AIT-H 122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 6. 000 9298.0 9305.0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRILN MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) : 58.0 MUD PH : 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 207.0 RESISTIVITY (OP~V~) AT TEMPERATURE (DEGF) : MUD AT f~F~ASURED TEMPERATURE (MT): 0.100 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 1 O0 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 120 MUD CAKE AT (BHT) : 68.0 68.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 6. 000 TOOL STANDOFF (IN): O. 5 REMARKS: RIG: DOYON 141 HOLEFINDER RUN ON BOTTOM OF AITH TWO STANDOFFS ON AITH FOUR STANDOFFS ON SONIC MAXIMUM DEVIATION 85.9 DEGREES MAXIMUM DOGLEG SEVERITY 29.6 DEGREES/iOOFT DRILL PIPE CONVEYED LOGGING DEPTH REFERENCE: TIED INTO ORIGINAL D-O1A LOGS DATED 2-28-70 (SWS OPEN HOLE LOGS) AT CLIENTS REQUEST. SONIC CHECKED IN CASING READING 57 US/M CEMENT VOLUFIE BASED ON 4.5" PRODUCTON CASING CALIPER OPENED ONCE TOOLS MOVING OFF BOTTOM THIS IS THE RAW (OPEN HOLE) MAIN PASS AIT/BHC/PEX DATA AT O. 0833' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 19 ** 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 645392 O0 000 O0 0 6 1 1 4 68 0000000000 HCAL PEX IN 645392 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10660.000 HCAL.PEX 4.090 ** END OF DATA ** **** FILE TRAILER **** FILE NA~IE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 20 **** FILE H~ER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RU-i~ NUMBER: TOOL STRING NU~BER: PASS NUMBER: DEPTH INC~: FILE SU~9~ARY FILE HEADER FILE~ER 7 RAW OPEIVHOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 10660.0 10326.0 BHC 10660.0 10326.0 PEX 10660.0 10326.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPH~) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. ~EAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION TOOL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: 29-MAY-97 8C0-609 1100 28-MAY-97 1530 29-MAY-97 10670.0 10660.0 9304.0 10624.9 1800.0 TOOL NOWi~ER AMS - A HILTB -DTB AIT-H 122 6.000 9298.0 9305.0 QUIKDRILN LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 21 MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) : 58.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 207.0 RESISTIVITY (OH~ff~) AT TEMPERATURE (DEGF) : MUD AT FIEASURED TEMPERATURE (MT): O. 100 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 100 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 120 MUD CAKE AT (BHT) : 68.0 68.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 6. 000 TOOL STANDOFF (IN): O. 5 REMARKS: RIG: DOYON 141 HOLEFINDER RUN ON BOTTOM OF AITH TWO STANDOFFS ON AITH FOUR STANDOFFS ON SONIC MAXIMUM DEVIATION 85.9 DEGREES MAXIMUM DOGLEG SEVERITY 29.6 DEGREES/IOOFT DRILL PIPE CONVEYED LOGGING DEPTH REFERENCE: TIED INTO ORIGINAL D-O1A LOGS DATED 2-28-70 (SWS OPEN HOLE LOGS) AT CLIENTS REQUEST. SONIC CHECKED IN CASING READING 57 US/M CEMENT VOLUME BASED ON 4.5" PRODUCTON CASING CALIPER OPENED ONCE TOOLS MOVING OFF BOTTOM THIS IS THE RAW (OPEN HOLE) REPEAT PASS AIT/BHC/PEX DATA ACQUIRED AT 0.5' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 22 TYPE REPR CODE VALUE 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 ** 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 645392 O0 000 O0 0 7 i 1 4 68 0000000000 GR AIT GAPI 645392 O0 000 O0 0 7 1 1 4 68 0000000000 TENS AIT LB 645392 O0 000 O0 0 7 I 1 4 68 0000000000 HTENAIT LB 645392 O0 000 O0 0 7 1 1 4 68 0000000000 FIRES AIT OH~4~ 645392 O0 000 O0 0 7 1 1 4 68 0000000000 14TEMAIT DEGF 645392 O0 000 O0 0 7 1 1 4 68 0000000000 GDEVAIT DEG 645392 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PEX CPS 645392 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PEX CPS 645392 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PEX CPS 645392 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PEX CPS 645392 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PEX 645392 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PEX 645392 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PEX PU 645392 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PEX PU 645392 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PEX PU 645392 O0 000 O0 0 7 1 1 4 68 0000000000 DT BHC US/F 645392 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10660.000 GR.AIT 47.647 TENS.AIT 1888.000 HTEN. AIT 14RES.AIT 0.026 MTEM. AIT 229.231 GDEV. AIT -999.250 CNTC. PEX CFTC. PEX 1165.157 RCFT. PEX 1088.487 RCNT. PEX 3110.098 TNRA.PEX RTNR.PEX 2.850 TNPH. PEX 32.034 NPHI.PEX 33.959 NPOR.PEX DT. BHC 88.900 DEPT. 10326. 500 GR.AIT 36. 356 TENS.AIT 1748. 000 HTEN. AIT f4RES~AIT O. 027 MTEM. AIT 210. 357 GDEV. AIT 84. 517 CNTC. PEX CFTC. PEX 1306.830 RCFT. PEX 1369.495 RCNT. PEX 3273.374 TNRA. PEX RTNR.PEX 2.283 TNPH. PEX 26.200 NPHI.PEX 26. 736 NPOR.PEX DT. BHC 97.3 O0 483.013 3139.732 2.710 31.703 648.512 3074.156 2.349 25.704 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 23 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION · O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUFiBER : DEPTH INCREME2TT : FILE SUF~L%RY FILE HEADER FILE~ER 8 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 10660.0 10326.0 BHC 10660.0 10326.0 PEX 10660.0 10326.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIM~ LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 29-MAY-97 8C0-609 1100 28-MAY-97 1530 29-MAY-97 10670.0 10660.0 9304.0 10624.9 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 24 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. ~EAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION TOOL $ 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~) 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) : TOOL NUMBER AMS - A HILTB-DTB AIT-H 122 6. 000 9298.0 9305.0 QUIKDRILN 8.70 58.0 9.0 207.0 0.100 68.0 0.100 68.0 0.120 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE 'CORRECTION (IN): 6. 000 TOOL STANDOFF (IN): O. 5 REMARKS: RIG: DOYON 141 HOLEFINDER RUN ON BOTTOM OF AITH TWO STANDOFFS ON AITH FOUR STANDOFFS ON SONIC MAXIMUM DEVIATION 85.9 DEGREES MAXIMUM DOGLEG SEVERITY 29.6 DEGREES/iOOFT DRILL PIPE CONVEYED LOGGING DEPTH REFERENCE: TIED INTO ORIGINAL D-O1A LOGS DATED 2-28-70 (SWS OPEN HOLE LOGS) AT CLIENTS REQUEST. SONIC CHECKED IN CASING READING 57 US/M CE~iENT VOLUME BASED ON 4.5" PRODUCTON CASING CALIPER OPENED ONCE TOOLS MOVING OFF BOTTOM THIS IS THE RAW (OPEN HOLE) REPEAT PASS AIT/BHC/PEX DATA ACQUIRED AT 0.25' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 25 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 42 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 645392 O0 000 O0 0 8 1 1 4 68 0000000000 AFiO AIT 0I{M~645392 O0 000 O0 0 8 1 1 4 68 0000000000 AF20 AIT OH~4~ 645392 O0 000 O0 0 8 1 1 4 68 0000000000 AF30 AIT OHIO4 645392 O0 000 O0 0 8 1 1 4 68 0000000000 AF60 AIT OH~ 645392 O0 000 O0 0 8 1 1 4 68 0000000000 AF90 AIT OH~4~ 645392 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 10660.000 AFiO.AIT 2.342 AF20.AIT AF60.AIT 6.338 AF90.AIT 6.097 DEPT. 10326.750 AFIO.AIT 3.242 AF20.AIT AF60.AIT 8.799 AF90.AIT 7.862 2.574 AF30.AIT 3.280 AF30.AIT 4. 051 5. 474 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 26 **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUAEqARY FILE HEADER FILE NUM~ER 9 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 10660.0 10326.0 BHC 10660.0 10326.0 PEX 10660.0 10326.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TItlE 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 29-MAY-97 8C0-609 1100 28-MAY-97 1530 29-MAY-97 10670.0 10660.0 9304.0 10624.9 1800.0 TOOL NUMBER AMS - A HILTB-DTB LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 27 AIT $ ARRAY INDUCTION TOOL AIT-H 122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 9298.0 9305.0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRILN MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) : 58.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 207.0 RESISTIVITY (OPL~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 1 O0 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 0.100 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 120 MUD CAKE AT (BHT): 68.0 68.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 6. 000 TOOL STANDOFF (IN): 0.5 REMARKS: RIG: DOYON 141 HOLEFINDER RUN ON BOTTOM OF AITH TWO STANDOFFS ON AITH FOUR STANDOFFS ON SONIC MAXIMUM DEVIATION 85.9 DEGREES MAXIMUM DOGLEG SEVERITY 29.6 DEGREES/iOOFT DRILL PIPE CONVEYED LOGGING DEPTH REFERENCE: TIED INTO ORIGINAL D-O1A LOGS DATED 2-28-70 (SWS OPEN HOLE LOGS) AT CLIENTS REQUEST. SONIC CHECKED IN CASING READING 57 US/M CEMENT VOLU~ BASED ON 4.5" PRODUCTON CASING CALIPER OPENED ONCE TOOLS MOVING OFF BOTTOM THIS IS THE RAW (OPEN HOLE) REPEAT PASS AIT/BHC/PEX DATA ACQUIRED AT O. 1667' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 28 ** 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 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME 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 645392 O0 000 O0 0 9 1 1 4 68 0000000000 RHOZ PEX G/C3 645392 O0 000 O0 0 9 1 1 4 68 0000000000 HDRA PEX G/C3 645392 O0 000 O0 0 9 1 1 4 68 0000000000 PEFZ PEX 645392 O0 000 O0 0 9 1 1 4 68 0000000000 DPHZ PEX PU 645392 O0 000 O0 0 9 1 1 4 68 0000000000 H~IN PEX OH~4 645392 O0 000 O0 0 9 1 1 4 68 0000000000 H~NO PEX OH~M 645392 O0 000 O0 0 9 1 1 4 68 0000000000 RXOZ PEX OHIO4 645392 O0 000 O0 0 9 1 1 4 68 0000000000 RX08 PEX OH~ 645392 O0 000 O0 0 9 1 1 4 68 0000000000 HCNT PEX CPS 645392 O0 000 O0 0 9 1 1 4 68 0000000000 HCFT PEX CPS 645392 O0 000 O0 0 9 1 1 4 68 0000000000 HGR PEX GAPI 645392 O0 000 O0 0 9 1 1 4 68 0000000000 RHFT PEX CPS 645392 O0 000 O0 0 9 1 1 4 68 0000000000 R3{NTPEX CPS 645392 O0 000 O0 0 9 1 1 4 68 0000000000 HTNP PEX PU 645392 O0 000 O0 0 9 1 1 4 68 0000000000 PiNPOPEX PU 645392 O0 000 O0 0 9 1 1 4 68 0000000000 TT1 BHC US 645392 O0 000 O0 0 9 1 1 4 68 0000000000 TT2 BHC US 645392 O0 000 O0 0 9 1 1 4 68 0000000000 TT3 BHC US 645392 O0 000 O0 0 9 1 1 4 68 0000000000 TT4 BHC US 645392 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 29 DEPT. 10660.000 RHOZ.PEX DPHZ.PEX 60721.211 H~IN. PEX RXO8.PEX 1.515 HCNT. PEX RHFT. PEX 1088.487 RHlVT. PEX TT1.BHC 548.800 TT2.BHC DEPT. 10326.834 RHOZ.PEX DPHZ. PEX 26.588 PiMIN. PEX RXOS.PEX 0.906 HCNT. PEX RHFT. PEX 1414.311 RHNT. PEX TT1.BHC 598.800 TT2.BHC -999.250 HDRA.PEX 0.073 H~NO.PEX 3139.732 HCFT. PEX 3110.098 HTNP.PEX 367.200 TT3.BHC 2.211 HDRA.PEX 0.495 HPiNO.PEX 3074.646 HCFT. PEX 3186.743 HTNP. PEX 399.600 TT3.BHC -999.250 PEFZ.PEX 0.122 RXOZ.PEX 1165.157 HGR.PEX 32.034 HNPO.PEX 532.400 TT4.BHC 0.008 PEFZ.PEX 0.392 RXOZ.PEX 1318.546 HGR.PEX 25.865 HNPO.PEX 596.000 TT4.BHC -999.250 1.514 47.647 31.703 358.400 2.419 0.906 39.976 26.194 40O.000 ** END OF DATA ** ~*** FILE TRAILER **** FILE NAM~ : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : 001C01 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUFIBER 10 RAW OPElVHOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING ArUM~ER: 1 PASS NI]M~ER : 2 DEPTH INCRESIENT: 0.0833 FILE SUM~Hh~Y VENDOR TOOL CODE START DEPTH ........................... AIT 10660.0 BHC 10660.0 PEX 10660.0 STOP DEPTH 10326.0 10326.0 10326.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 30 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E CIRCULATION ENDED: TI~E 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. M~AS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION TOOL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 29-MAY-97 8C0-609 1100 28-MAY-97 1530 29-MAY-97 10670.0 10660.0 9304.0 10624.9 1800.0 TOOL NUMBER ........... AMS - A HILTB -DTB AIT-H 122 6.000 9298.0 9305.0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRILN MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) : 58.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 207.0 RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT AiEAS~ TEMPERATURE (MT): O. 100 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 100 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 120 MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 6. 000 TOOL STANDOFF (IN): O. 5 RIG: DOYON 141 HOLEFINDER RUN ON BOTTOM OF AITH TWO STANDOFFS ON AITH FOUR STANDOFFS ON SONIC MAXIMUM DEVIATION 85.9 DEGREES MAXIMUM DOGLEG SEVERITY 29.6 DEGREES/i OOFT 68.0 68.0 68.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 31 DRILL PIPE CONVEYED LOGGING DEPTH REFERENCE: TIED INTO ORIGINAL D-O1A LOGS DATED 2-28-70 (SWS OPEN HOLE LOGS) AT CLIENTS REQUEST. SONIC CHECKED IN CASING READING 57 US/M CEMENT VOLU~E BASED ON 4.5" PRODUCTON CASING CALIPER OPENED ONCE TOOLS MOVING OFF BOTTOM THIS IS THE RAW (OPEN HOLE) REPEAT PASS AIT/BHC/PEX 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 645392 O0 000 O0 0 10 1 1 4 68 0000000000 HCAL PEX IN 645392 O0 000 O0 0 10 i 1 4 68 0000000000 ** DATA ** DEPT. 10660.000 HCAL.PEX 4.022 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 32 DEPT. 10326.584 HCAL.PEX 5.880 ** END OF DATA ** **** FILE TRAILER **** FILE NAMIE : EDIT ~010 SERVICE · FLIC VERSION : O01CO1 DATE · 97/09/10 MA3fREC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 11 RAW CASED HOLEMAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREFIENT: 0.5000 FILE SDIv~r~%RY VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 9300.0 9184.0 BHC 9300.0 9184.0 PEX 9300.0 9184.0 $ LOG HEADER DATA DATE LOGGED: 29-MAY-97 SOFTWARE VERSION: 8C0- 609 TIME CIRCULATION ENDED: 1100 28-MAY-97 TIME LOGGER ON BOTTOM: 1530 29-MAY-97 TD DRILLER (FT) : 10670.0 TD LOGGER (FT) : 10660.0 TOP LOG INTERVAL (FT) : 9304.0 BOTTOM LOG INTERVAL (FT) : 10624.9 LOGGING SPEED (FPHR) : 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 33 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION TOOL $ TOOL NUMBER AMS-A HILTB-DTB AIT-H 122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 9298.0 9305.0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRILN MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) : 58.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 207.0 RESISTIVITY (OHM~I) AT TEMPERATURE (DEGF) : MUD AT MF~%SURED TEMPERATURE (MT): O. 100 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 1 O0 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 120 MUD CAKE AT (BHT) : 68.0 68.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 6. 000 TOOL STANDOFF (IN): 0.5 REMARKS: RIG: DOYON 141 HOLEFINDER RUN ON BOTTOM OF AITH TWO STANDOFFS ON AITH FOUR STANDOFFS ON SONIC MAXIMUM DEVIATION 85.9 DEGREES MAXIMUM DOGLEG SEVERITY 29.6 DEGREES/i OOFT DRILL PIPE CONVEYED LOGGING DEPTH REFERENCE: TIED INTO ORIGINAL D-O1A LOGS DATED 2-28-70 (SWS OPEN HOLE LOGS) AT CLIENTS REQUEST. SONIC CHECKED IN CASING READING 57 US/M CEMENT VOLU~E BASED ON 4.5" PRODUCTON CASING CALIPER OPENED ONCE TOOLS MOVING OFF BOTTOM THIS IS THE RAW (CASED HOLE) MAIN PASS AIT/BHC/PEX DATA ACQUIRED AT O. 5' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 34 ** 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 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 ELE~ CODE (HEX) DEPT FT 645392 O0 000 O0 0 11 1 1 4 68 0000000000 TENS AIT LB 645392 O0 000 O0 0 11 1 1 4 68 0000000000 HTENAIT LB 645392 O0 000 O0 0 11 1 1 4 68 0000000000 GR AIT GAPI 645392 O0 000 O0 0 11 1 1 4 68 0000000000 CNTC PEX CPS 645392 O0 000 O0 0 11 1 1 4 68 0000000000 CFTC PEX CPS 645392 O0 000 O0 0 11 1 1 4 68 0000000000 RCFT PEX CPS 645392 O0 000 O0 0 11 1 1 4 68 0000000000 RCNT PEX CPS 645392 O0 000 O0 0 11 1 1 4 68 0000000000 TNRA PEX 645392 O0 000 O0 0 11 1 1 4 68 0000000000 RTNR PEX 645392 O0 000 O0 0 11 1 1 4 68 0000000000 NPOR PEX PU 645392 O0 000 O0 0 11 1 1 4 68 0000000000 NPHI PEX PU 645392 O0 000 O0 0 11 1 1 4 68 0000000000 TNPH PEX PU 645392 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 9300.000 TENS.AIT 1013.000 HTEN. AIT 1299.263 GR.AIT CNTC.PEX 1554.318 CFTC. PEX 541.737 RCFT. PEX 495.041 RCNT. PEX TNRA.PEX 2.998 RTNR.PEX 3.117 NPOR.PEX 33.877 NPHI.PEX TNPH. PEX 34.048 60.615 1533.125 36.538 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 35 DEPT. 9184.500 TENS.AIT CNTC.PEX 984.270 CFTC. PEX TNRA.PEX 4.583 RTNR.PEX TNPH.PEX 67.537 468.000 HTEN.AIT 226.095 RCFT. PEX 5.381 NPOR.PEX 1220.418 GR.AIT 244.646 RCNT. PEX 64.361 NPHI.PEX 62.677 975.145 68.795 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .011 SERVICE : FLIC VERSION . O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .012 SERVICE : FLIC VERSION . O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 12 RAW CASED HOLEMAIN PASS Curves and log header data for open hole logs run into casing. PASS NUM~ER: 1 DEPTH INC~: 0.1667 FILE SUM~IARY VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 9300.0 9184.0 BHC 9300.0 9184.0 PEX 9300.0 9184.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIFiE CIRCULATION ENDED: TIf4E LOGGER ON BOTTOM: TDDRILLER (FT): TD LOGGER(FT): 29-MAY-97 8C0-609 1100 28-MAY-97 1530 29-MAY-97 10670.0 10660.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 36 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 9304.0 10624.9 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. SONDE PEX PLATFORM EXPRESS AIT ARRAY INDUCTION TOOL $ TOOL NUMBER AMS - A HILTB-DTB AIT-H 122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 9298.0 9305.0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRILN MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) : 58.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 207.0 RESISTIVITY (OP~4~) AT TEMPERATURE (DEGF): MUD AT f4F~S~ TEMPERATURE (MT): O. 1 O0 MUD AT BOTTOM HOLE T~PERATURE (BHT): MUD FILTRATE AT (MT): O. 1 O0 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 120 MUD CAKE AT (BHT): 68.0 68.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 6. 000 TOOL STANDOFF (IN): 0.5 RIG: DOYON 141 HOLEFINDER RUN ON BOTTOM OF AITH TWO STANDOFFS ON AITH FOUR STANDOFFS ON SONIC MAXIMUM DEVIATION 85.9 DEGREES MAXIMUM DOGLEG SEVERITY29.6 DEGREES/iOOFT DRILL PIPE CONVEYED LOGGING DEPTH REFERENCE: TIED INTO ORIGINAL D-O1A LOGS DATED 2-28-70 (SWS OPEN HOLE LOGS) AT CLIENTS REQUEST. SONIC CHECKED IN CASING READING 57 US/M CEM~VT VOLUM~ BASED ON 4.5" PRODUCTON CASING CALIPER OPENED ONCE TOOLS MOVING OFF BOTTOM THIS IS THE RAW (CASED HOLE) MAIN PASS AIT/BHC/PEX DATA ACQUIRED AT 0.1667' SAMPLE RATE. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE: 37 LIS FORMAT DATA ** 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 i 0 66 1 ** SET TYPE - CHAN ** NA~iE SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 645392 O0 000 O0 0 12 1 1 4 68 0000000000 HCNTPEX CPS 645392 O0 000 O0 0 12 1 1 4 68 0000000000 HCFT PEX CPS 645392 O0 000 O0 0 12 1 1 4 68 0000000000 HGR PEX GAPI 645392 O0 000 O0 0 12 1 1 4 68 0000000000 RHFT PEX CPS 645392 O0 000 O0 0 12 1 1 4 68 0000000000 RPiNTPEX CPS 645392 O0 000 O0 0 12 1 1 4 68 0000000000 HTNP PEX PU 645392 O0 000 O0 0 12 1 1 4 68 0000000000 H1VPO PElf PU 645392 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 9300.000 HCNT. PEX 1555.064 HCFT. PEX 540.924 HGR.PEX RHFT. PEX 483.461 RHNT. PEX 1548.806 HTNP. PEX 34.746 HNPO.PEX DEPT. 9184.834 HCNT. PEX 981.475 HCFT. PEX 230.364 HGR.PEX RHFT. PEX 214.875 R3{NT. PEX 1044.582 HTNP. PEX 66.270 HNPO.PEX 58. 728 34.172 59. 319 61. 839 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1997 10:25 PAGE 38 ** END OF DATA ** **** FILE TRAILER **** FILE NA~I~ : EDIT .012 SERVICE · FLIC VERSION · O01CO1 DATE : 97/09/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~fE : EDIT DATE · 97/09/10 ORIGIN · FLIC TAPE NAME : 97276 CONTINUATION # : 1 PREVIOUS TAPE : CO~2TT : B.P. EXPLORATION, D-O1A, PRUDHOE BAY, API #50-029-20054-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/09/10 ORIGIN : FLIC REEL NA~IE '. 97276 CONTINUATION # : PREVIOUS REEL : co~l~r : B.P. EXPLORATION, D-O1A, PRUDHOE BAY, API #50-029-20054-01
