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Home My WebLink About193-079RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Nny n F 9nm WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑� • Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[—] WDSPL ❑ No. of Completions: _0 1b. Well Class: Development ❑ Exploratory ❑ Service ❑� . Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Aband.: 9/19/2018 14. Permit to Drill Number/ Sundry: 193-079 / 318-149 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: July 25, 1993 15. API Number: 50-029-22374-00-00 - 4a. Location of Well (Governmental Section): Surface: 3152' FSL, 2360' FEL, Sec 36, T12N, R16E, UM, AK Top of Productive Interval: N/A Total Depth: 2005' FNL, 4580' FEL, Sec 2, T11 N, R1 6E, UM, AK 8. Date TO Reached: September 25, 1993 16. Well Name and Number: DIU MPI 2-66 9. Ref Elevations: KB: 40' GL:13.3' BF:13.3' 17. Field / Pool(s): Endicott Field Endicott Pool + 10. Plug Back Depth MD/TVD: 7,503' MD / 5,933' TVD 18. Property Designation: ADL034633 / ADLO34636 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 258840 • y- 5982293 • Zone- 3 TPI: x- N/A y- N/A Zone- Total Depth: x- 251232 y- 5977358 Zone- 3 11. Total Depth MDfFVD: • 15,203' MD / 11,505' TVD • 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: . 1,465' MD / 1,462' TVD 5. Directional or Inclination Survey: Yes LJ (attached) No Q Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 7,503' MD / 5,933' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" - - Surface 161' Surface 161' 30" Driven 13-3/8" 68# NT -80 Surface 2,872' Surface 2,739' 16" 950 sx 9-5/8" 47# NT -80 Surface 7,503' Surface 5,933' 12-1/4" 1280 sx 24. Open to production or injection? Yes ❑ No 0 • If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): �9ATE VERIFIED ( A PRODUCTION 25. TUBING RECORD SIZE DEPTH SET (MD) I PACKER SET (MD/TVD) N/A N/A I N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No � Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 � j% r �J /j CON K INUEP OP PAGE 2 REEMS 0(V "'! 0 0 2018 S it I L onl i . 28. CORE DATA Conventional Corals): Yes ❑ No ❑� , Sidewall Cores: Yes ❑ No ❑/ If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this farm, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q ` If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 1,465' 1,462' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. Formation at total depth: Lower Kekiktuk 31. List of Attachments: Plugback Schematic, Decomplete Reports Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Mana r Contact Email: Cdil1 of Q hi1COf .COm Authorized Contact Phone: 777_8389 Signature: Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item ib: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemioal, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only us 13-3/8" Duck Island Unit Well: END 2-66 Plugback Schematic Abandoned: 9/19/2018 1BIcorP Alaelca, LLC PTD: 193-079 KB Elev.: 40(/ GL Elev.: 13.3' SAFETY NOTES TREE & WELLHEAD Innovation Rig 1-12S Readings Average 230-260 PPM on A/L &Gas Injectors Tree 4-1/16" CIW Well Requires a SSSV Wellhead CIW !• OPEN HOLE /CEMENT DETAIL I I I 13-3/8" 1" Stage: 550 sx, 12# Class E / 2"a Stage: 400 sx, 15.8# Class E in 16" Hole Esff noted TOC 9-5/8" V Stage: 507 bbls, 11# Class G / 2"" Stage: 81 bbls, 15.8# Class G in 12-1/4" Hole 7" 158 bbls 15.8# Class G in 8-1/2" Hole mtopatc n 38 661s of 15.8 ppg on top of Cmt Retainer C56 lets —7 r oa 7y73' TOW 07,503' ND TOC ®f7` . •. _ - .l 95'8' Iv131ca 4--JdrR: 14,19(Y to 14,210 r' TD= 15,203 (MD) /TD= 11,50fffVD) PBTD= 7,503' (MD) / PBM = 5,933'(TVD) CASING DETAIL Size 2 Wt/Grade/Conn ID Baker3-3'6'1, Esff noted TOC pj dx,d belay (9'10112) 13,3W possibly 13,820' mtopatc n Surface •. _ - .l 95'8' Iv131ca 4--JdrR: 14,19(Y to 14,210 r' TD= 15,203 (MD) /TD= 11,50fffVD) PBTD= 7,503' (MD) / PBM = 5,933'(TVD) CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor N/A/N/A/N/A N/A Surface 131' N/A 13-3/8" Surface 68/N-80/Btrs 12.415 Surface 2,872' 0.1497 9-5/8" Production 47 / NT80S / NSCC 8.681 Surface 7,503' 0.0732 (f6p) JEWELRY DETAIL No Depth Item 1 8,000' 9-5/8" Cement Retainer (1 GENERAL WELL INFO API:50-029-22374-00-00 Initial Completion -10/2/1993 P&A'd — 9/19/2018 Revised By: CID 11/5/18 HHilcorp Energy Company Composite Report Well Name: END 2-66A Field: Endicott County/State: , Alaska (LAT/LONG): svation (RKB): API #: Spud Date: Job Name: 1811485P END 2-66A PreDdll Contractor AFE M APE $: .. QO,6 $ummarp 8/4/2018 Crew arrive at CTU 6. Start BOP Test, Baker on location, Start making up tools., R I H with Inflatable Cement retainer. set Retainer at 8000 ctm. Drop ball to set retainer. Ball on seat,Slowly pressure up to 2500psi. balloon set, Pull up to shear off. Pulled up to 7970 to PT retainer and casing.,pressure up to 1500 psi on surface. pressure slowly leaking off. Pumped up again. Took 5 bbls to reach 1500 psi. Slowly leaking off still. Rih and tag retainer to verify set. POH,Pressure fell all the way out of hole but remained positive. ending with 30 psi on the well head. RD baker tools and secured for the night. 8/5/2018 CTU crew arrive onlocation. make up 2 inch squeeze nozzle. PT PCE low and HI. Rik with nozzle,SLB Cementem on location. Tag Inflatable Cement Retainer. Circulate 100 blas to into well.,safety Ops meeting. PT lines, Start pumping 38 bbls of 15.8 Class G cement , Lay in cement on top of retainer.,Contminate and clean the cement top at 7643'. Reverse out contaminated cement. Losing 10 percent returns at beginning. 1 for 1 at end of clean out., POH. Leave 375 psi on well head. WOC 500 psi hardness estimated to be 12 hours.,WOC 8/6/2018 latternat to pressure test casino. Failed. Pumped 11.1 bbls Press up to 1525. Fell to 1155 psi in 12 minutes..,RIH with Ct and 2.7" nozzle. Tag cement at 7515' Cement plug at depth expected. 515' of cement on top of inflatable retainer.,Establish leak rate of .25 bpm at 1300. PCH RD CTU send to MPU. Wait on Leak detection logginq,Leak detection lon with LRS , Halliburton slickline and PDS. with Archer leak detection tools. �u t' 19 ZI°`�-7 4-11 L) nHilcorp Energy Company Composite Report Well Name: END 2-66A Field: Endicott County/State: , Alaska i (LAT/LONG): evation (RKB): API #: Spud Date: 9/20/2018 Job Name: 1811485D END 2-66A Drilling Contractor Innovation AFE #: AFE $: ' Vny Date) _..... 1$ .. , .., .., ary 9/15/2018 PJSM Prep and scope down Derrick. Remove Derrick cables. R/D Mezz mud lines, cutting box, blow down water and steam. Prep all rig roofs.;PJSM Walk Sub out from well 1-29. Hook up hydaulic fittings for rear tires and install. Install yoke and move to new well END 2-26A. Remove yoke and rear tires. Walk Sub onto well. Put MP #1 valves, swabs and liners back together. Spot Catwalk, Pipe Shed and Mud Mob. Begin to spot Motor Mod.;Work on inner connects as each Mod was spotted. Put MP #2 valves, swabs and liners back together. Replaced 1 wash plate. R/U 1502 hose off well for bleed Iine.;Daily Fluid Hauled to MP G&I: 0 bbls Total Fluid Hauled to MP G&L 0 bbls Daily Fluid Hauled to ORT:0 bails Total Fluid Hauled to ORT: 0 bbls Daily Fluid Hauled to Milne B-50: 0 bbls Total Fluid Hauled to Milne B-50: 0 bbls;Daily H2O from Duck Lake: 0 bbls Total H2O from Duck Lake: 0 bible Daily Metal Collected:0 Lbs Total Metal Collected: 0 Lbs Daily Fluid Lost to Formation: 0 bbls 9/16/2018 R/U pit interconnect, Hookup see lines between modules. Hookup lines in pits and test equipment (no issues). Dress shakers w/ 140's. Load pits with 290 bible mud. Spot shacks and hook up samet Build containment and set cuttings box. C/O manual crown saver. Troubleshoot drawworks Ethemat coms;R/U and tbg and bled back 114 to 1/2 bbl diesel from well to flowback tank. Shut in and allow to build back to 145 psi over 30 min. Bleed off and continue to monitor flowback @ 5 gal / 4 min 33 initial then stabilized @ 5 gal / 10 min 20 sec +/-. Set TWC and N/D tree. N/U BOP's. Scope derrick.;Rig accepted at 16:OO.;N/U BOPE;PJSM R/U Test Equip. and 5" test joint.;PJSM Test BOPE W/ 5" test joint. n Test Pree. 250 PSI low and 4,000 PSI high. Tested Annular, Choke valves 1-15, 2 7/8" X 5 1/2" Variable Upper and Lower Pipe Rams, TIW, Dart, Kill and Choke HCR, manual HCR and Choke, Super and Manual Choke, Blind Rams. Upper and lower IBOP.;Perform Koomey draw down, initial starting Press. Manifold 1,350 r PSI, Accumulater 3,000 PSI, Annular 1,375 PSI, after function Manifold 1,500 PSI, 1,550 PSI, Annular 1,500 PSI. 200 PSI increase in 25 Sec, full charge 95 GS Sec. 6 bottles Nitrogen average 2,291 PSI.;Test witnessed by AOGCC Austin MCCloud.;R/D test Equip. and break down 5" test joint.;Daily Fluid Hauled to MP G&I:0 bbls Total Fluid Hauled to MP G&l: 0 bbls Daily Fluid Hauled to ORT: 0 bbls Total Fluid Hauled to ORT: 0 aibls Daily Fluid Hauled to Milne B-50: 0 bails Total Fluid Hauled to Milne B-50: 0 bbls;Daily H2O from Duck Lake: 0 bbls Total H2O from Duck Lake: 0 bbls Daily Metal Collected: 0 Lbs Total Metal Collected: 0 Lbs Daily Fluid Lost to Formation:0 bbls Total Fluid Lost to Hole: 0 bbls 9/1 712 01 8 R/D and UO BOP test equipment. B/D all lines and svc choke, line up choke for milling operations. Clean and clear rig floor.;Service rig - Grease TDS, Blocks, Croom and prep pipeshed for picking up 5" DP.;Troubleshoot PLC communication fault issue. Clean and svc connections, Inspect for routing and install jumpers to bypass potential com line issues. PLC faulted 1x after changes then was reset without further issue. Continue with well opemfions.;PJSM MAI X/O tog' D.P. Set in Hanger and pull Hanger W/ 20K over to unseat. P/U weight 55K. Check well for flow. (Static) Pull to floor and UD Hanger and 3' Pup. Shut in IA and Prep pits for returns. P/U Wear Ring 8 314" ID and set. RILDS 4ea.;M/U BOT 9.625" Test Packer 51A4 (13.6' length). Single in hole on 5" dp F/ surface to 6,485' MD. Drift pipe 2.82'. Broke circulation @ 500'to displace out remaining 35 bbls diesel in wellbore before continuing to trip in hole.;PJSM Cont to single in hole W/ 5" D.P. F/ 6,485to 7,365' MD. P/U 175K, SLK 125K. Calculated displacement.;CBU at 7,365' MD. 168 GPM, 15-130 PSI, FO 31.7%. Max Gas 980U. Gas breaking out at surface with no gain in pit. Decision was made to displace well to 9.6 ppg 3% KCL LSND.;PJSM for displacing well W/ all personnel. Shut down monitor well. Gas cont. to break out at surface. Fluid dropping to lower rams. SIMOPS build Hi Vis Spacer.;Displace well from Seawater to 9.6 ppg 6% KCL -SND. Pump 31 bbls 9.6, 208 sec Hi Vis spacer and chase with 500 bbls 9.6 ppg 6% KCL LSND at 168 GPM ICP 23 PSI FCP 225 PSI. Max Gas 1,052U. Mud weight in and out 9.55 ppg. Shut down monitor well for 10 Min. Static ;PJSM for setting Packer and testing casino Set Test Packer at 7 361' Mo W/ 9 turns to right wnrk'no_ string as per Baker Rep onsite. PN 167K, SLK 127K. Set down 16K. Good set. Attempt 9 5/8" casing test pumping at .75 bpm, pumped 10 bbls, casing pressure at 1,620 PSI (no test).;Shut in and monitor Csg Press., bleeding down. Bled back 3.9 bbls. UD 5" D.P. single for even stands. Set Test Packer at 7,333' MD W/ 20k set down as per BOT Attempted testing 9 5/8" Csg at 1 bpm pumped 6.6 bbl to 1 619 Pct ( tests Ab t'„ and monitor Csg Press., bleeding down . Bled back 4.7 bbls. Still having multiple PLC faults during operations.;Monitor well. Blow down Top Drive. POOH racking back 5" D.P. Fl 7,333'to 6,827" MD. P/U 167K. Set Packer W/ 25K as per BOT. Continue having PLC faults during operations.;Close Upper Variable Rams and line up to test. Attempt to test 9 518" Csg at 6,827' MD at 1 bpm, pumped 4.4 bbls to 2,532 PSI. Press, bled down to 1,622 PSI. Bumped up Press F/ 1,622 PSI to 2,600 PSI at 1 bpm, pumped 4.4 bbls. Total pumped 8.8 bbls.;Bled back down to 1,637 PSI. Bleed back 2.9 blols. Line up surface Equip. for POOH. Continue having PLC faults during operations.;SPR at 7,328' MD (5,804' TVD) W/ 9.55 ppg MW MP #132-205 PSI, 48-227 PSI MP #2 32-200 PSI, 48-222 PSI;Daily Fluid Hauled to MP G&I: 0 bbls Total Fluid Hauled to MP G&I:0 bible Daily Fluid Hauled to ORT: 0 bbls Total Fluid Hauled to ORT: 0 bbls "c Daily Fluid Hauled to Milne B-50: 565 bbls ,(v Total Fluid Hauled to Milne B-50: 565 bbls;Daily H2O from Duck Lake: 730 bbls Total H2O from Duck Lake: 730 bbls f� Daily Metal Collected: 0 Lbs Total Metal Collected: 0 Lbs Daily Fluid Lost to Formation: 0 bbls y.1/ �v� Total Fluid Lost to Hale: 0 bbls 9/18/2018 POOH with retrievamatic packer from 6820' to 6320'. PUW 159K, SOW 115K.;Set packer with COE at 631 T. PT casing to 2500 psi for 30 minuteg--gd6d test. Pumped 4.6 blots with 4.5 bbls returned.;Cut and slip 83' of drilling line, calibrate draw works.;Service rig, grease crown and top drive.;Confinue to troubleshoot drawworks communications issues. Replace ODS ethernet switch and configure.;Rig up and FIT to 13 ppg EMW, pressure up to 1000 psi. Rig down test equipment.;Pump dry job. Slowdown top drive. POOH from 6317'to surface. UD test packer. Clean and clear rig floor.;Rig up hawk jaw. Mobilize cleanout BHA components to rig floor. Strap, tally, OD/ID components.;PJSM. M/U cleanout BHA: 8-1/2" bit, bit sub, upper mill, P x P sub, casing scraper, bit sub, (5) HWDP, Jars, (14) HWOP.;Pick up, drift and single in the hole with 5" drill pipe from 634' to 6255filling pipe every 2500'. Continue to RIH with stands from 6255' to 6949. PUW 175K, SOW 115K.;Daily Fluid Hauled to MP G&I: 135 bbls Total Fluid Hauled to MP G&I: 135 bbls Daily Fluid Hauled to ORT: 0 bbls Total Fluid Hauled to ORT: 0 bbls Daily Fluid Hauled to Milne 8-50: 0 bbls , Total Fluid Hauled to Milne B-50: 565 bbls;Daily H2O from Duck Lake: i IObbls p� p Total H2O from Duck Lake: 840 bbls ` (� Daily Metal Collected: 0 Lbs Total Metal Collected: 0 Lbs Daily Fluid Lost to Formation: 0 bola Total Fluid Lost to Hole: 0 bbls 9/19/2018 Continue trip in hole with 8.5" tricone, mill, scraper cleanout assy F/ 6,949'- T/ 7,519' MD (tag 10k, 2x). 189k up, 136k dn.;Drill 2' of cmt F/ 7,519' - T/ 7,521' MD. 420 gpm, 785 psi, 53% flow, 60 rpm, 11.4k tq, 1-3k WOB. P/U and circulate 1.5x btms up. 462 gpm, 750 psi w/ 835 units gas @ btms up. Shut on pumps and tag 2x w/ 30k set on @ 7,521' MD.;Monitor well (static). Pump dry job, B/D TDS. POOH F/ 7,521' - T/ surface. B/O and UD cleanout assy. 5 bbl loss fortrip out.;M/U Milling assy w/ MWD. Scribe and perform RFD (576/576 = 0°) using MWD to lug orientation on starter mill. RFO = 180° for face of whipstock HS. Shallow pulse test MWD (test good). WU whipstock assy w/ 3 pins (20k shear) anchor, 45k shear bolt on whipstock.;TIH w/ whipstock assy T/ 3,000' MD filling pipe every2500'. 60 fpm running speed max as per BOT rep. Easy in/out of slips.;TIH w/whipstock assy from 3,000' MD to 7486' filling pipe every 2500' Picking up working single. 60 fpm running speed max as per BOT rep. Easy in/out of slips. PUW 193K, SOW 133k.;Fill pipe. Establish circulation at 450 gpm/1150 psi. Orientate whipstock 45R. Slack off and tag up at 7524'. Set down 25K to set anchor, pickup and overpull 25K. Set down and shear off with 35K down. Pick up and obtain SPR's and parameters: 500 gpm/1380 psi, 100 rpms/11000 ft -lbs, ROTW 151 K. Mill window as per Baker from 75na to 7s?0' and drill 20' of new hole to 7540' with 500 gpm/1360 psi, 100 rpms/1 2K - 1 7Kft-lbs, WOM 305K. Work mills through window, no pumps or rotary with no issues.;Pump high viscosity sweep and circulate hole clean 500 gpm/1360 psi.;Daily Fluid Hauled to MP G&I:0 bbls Total Fluid Hauled to MP G&I: 135 bbls Daily Fluid Hauled to ORT: 0 bbls Total Fluid Hauled to ORT: 0 bbls Daily Fluid Hauled to Milne B-50: 0 bbls Total Fluid Hauled to Milne B-50:565 bbls;Daily H2O from Duck Lake: 0 bbls Total H2O from Duck Lake: 840 bbls ^ �V Daily Metal Collected: 150 Lbs Total Metal Collected: 150 Lbs Daily Fluid Lost to Formation: 0 bbls Total Fluid Lost to Hole: 0 bbls f) Jff t Schwartz, Guy L (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Friday, August 10, 2018 3:19 PM To: Schwartz, Guy L (DOA) Subject: RE: Endicott 2-66 (PTD #193-079) Reservoir Abandonment Sundry #318-149 Attachments: END 2-66 SCHEMATIC 8-10-2018.pdf Follow Up Flag: Follow up Flag Status: Flagged Mr. Schwartz, To follow up on the results of the leak detect log, there was one leak and one anomaly identified in the log. The attached schematic shows the following: anomaly @ —7,100' md, leak @ 7,743' and and TOC @ 7,510' md. The way we would like to proceed with this well is to close out the operations detailed under approved Sundry #318-149 and then address the casing integrity during the sidetrack operations. The method to address the casing integrity would resemble the following high level steps: 1. MIRU Innovation 2. ND Tree, NU BOP, BOP Test 3. Pull 'kill string' (single pup joint), RIH with 9-5/8" test packer on workstring. 4. Circ out freeze protect to tanks from 1,000' md. 5. Set test packer and test casing to 2,800psi (charted for 30 min) from 6,500' md. a. If failed, PUH and test to find good casing. b. Once passed, this will determine how high the liner lap and liner hanger/packer will need to be run. Please review and let me know if you would like additional information or if there any additional items you would like addressed. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC — Ops Engineer: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Taylor Wellman Sent: Tuesday, August 07, 2018 7:50 AM To: Schwartz, Guy L (DOA) Subject: Endicott 2-66 (PTD #193-079) Reservoir Abandonment Sundry #318-149 Mr. Schwartz, During the operations to complete the reservoir abandonment of Endicott well 2-66 (PTD #193-079), the well has failed a pressure test of the casing. The inflatable cement retainer was set and a pressure test to 1500psi had a slight leakoff which was attributed to partial leakage past the inflatable element. Cement was placed on top of the retainer and allowed to harden. The following MIT of the 9-5/8" casing failed on 8/6. The TOC was tagged at the expected depth of 7,510' md. A leak detect log was run from the TOC to surface. As soon as results of this log are available, I'll provide an update and a proposed plan for this well. Thank you and feel free to contact me with any questions or requests for more information, Taylor Taylor Wellman Hilcorp Alaska, LLC — Ops Engineer: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com Schwartz, Guy L (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Tuesday, August 7, 2018 7:50 AM To: Schwartz, Guy L (DOA) Subject: Endicott 2-66 (PTD #193-079) Reservoir Abandonment Sundry #318-149 Mr. Schwartz, During the operations to complete the reservoir abandonment of Endicott well 2-66 (PTD #193-079), the well has failed a pressure test of the casing. The inflatable cement retainer was set and a pressure test to 1500psi had a slight leakoff which was attributed to partial leakage past the inflatable element. Cement was placed on top of the retainer and allowed to harden. The following MIT of the 9-5/8" casing failed on 8/6. The TOC was tagged at the expected depth of 7,510' md. A leak detect log was run from the TOC to surface. As soon as results of this log are available, I'll provide an update and a proposed plan for this well. Thank you and feel free to contact me with any questions or requests for more information, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman(c@hilcorp.com 20' TOC @7511 Duck Island Unit Well: END 2-66 SCHEMATIC Last Completed: 10/2/1993 corp Alaakx, JLC PTD: 193-079 KB Elev.: S71 BF Bev.: 19 SAFETY NOTES TREE & WELLHEAD R= is H2S Readings Average 230-260 PPM on A/L & Gas Injectors Tree 4-1/16"CIW Well Requires a SSSV Wellhead CIW OPEN HOLE / CEMENT DETAIL 95/8" J Baur 339' Iw PNril b 13.300 oambly a/ M top mnaR . sse r4axe Jant. 4 3 ro 463 LDL arrrdy� ±7100 rel 13-3/8" 1 Stage: 550 sx, 12# Class E /2' Stage: 400s), 15.8# Class E in 16" Hole 9-5/8" 1 Stage: 507 bbls, 11# Class G / 2 Stage: 81 bbls,15.8# Class G in 12-1/4" Hole 7" 158 bbls 15.8# Class G in 8-1/2" Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top I Btm BPF 20" Conductor N/A/N/A/N/A N/A Surface 131' N/A 13-3/8" Surface 68/ N-80/ Mrs 12.415 Surface 2,872' 0.1497 9-5/8" Production 47 / NT80S / NSCC 8.681 Surface 10,056' 0.0732 9-5/8" Production 47/NT95HS/NSCC 8.681 10,056' 13,502' 0.0732 7" Liner 12.6/13Cr-80/NSCC 1 6.184 13,195' 15,200' 0.0372 TUBING DETAIL 4-1/2" Tubing L-80 3.958 Surface 3'0.0152 JEWELRY DETAIL No Depth Item 1 8,000'9-5/8"CIBP . 2 13,195' Baker Te Back Sleeve 3 13,203' 9-5/8"x7'Bajer Type 'N'Pkr w/ Flex Lock Liner Hanger 9,W Nuke Jon: 14190 b 14210 7" j 1 1 TD=15,203' (MD) /To =11,S01'(7VD) PBTD=15,179' (MD) / P91D=11,480'(TVD) Revised By: TTW 8/10/2018 WELL INCLINATION DETAIL . KOP @ SW 1 Max Hole Angle = 57 Deg. @ 9500' PERFORATION DETAIL END Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size 17,475' ±7,480' 15,926' 1 ±5,930' 5 Future 2 END 14,632' 14,65210,996' 11,013' 20 12/26/1993 Closed 3-3/8' 1 3 Notes: Tie-in to SeT dated 11/1/1993 : Perfs Info —Atlas 3-3/8" Guns at 6spf, 60 degree phasing, random orientation and GENERAL WELL INFO E �TOC API: 50-02922374-00-00 (9'10'12) 13.@0 Initial Completion -10/2/1993 Set TOC -9/10/2012 Set Bur IBP —12/21/2012 9,W Nuke Jon: 14190 b 14210 7" j 1 1 TD=15,203' (MD) /To =11,S01'(7VD) PBTD=15,179' (MD) / P91D=11,480'(TVD) Revised By: TTW 8/10/2018 fi * OF/T�� THE STATE Alaska Oil and Gas ofALAsKA ConseIvati®n Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 t. ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, SDI 2-66 suNie Permit to Drill Number: 193-079 Sundry Number: 318-149 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. Arequest forreconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Y itS)04' Hollis S. French { Chair DATED this day of April, 2018. • 0 RECFIVED STATE OF ALASKA APR 03 2038 ALASKA OIL AND GAS CONSERVATION COMMISSION S 01 ' APPLICATION FOR SUNDRY APPROVALS AOC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown El Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑''Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: F ` 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 193-079 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑� . 6.API Number: Anchorage Alaska 99503 50-029-22374-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 458A Will planned perforations require a spacing exception? Yes ❑ No 0 DUCK IS UNIT MPI 2-66 ` 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034636 • ENDICOTT/ENDICOTT OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 15,203' ` 11,501' ' 13,820' 11,480' 590 13,820' Casing Length Size MD TVD Burst Collapse Conductor 94' 20" 131' 131' Surface 2,829' 13-3/8" 2,872' 2,739' 5,020psi 2,260psi Intermediate 10,011' 9-5/8" 10,056' 7,607' 6,870psi 4,760psi Intermediate 3,446' 9-5/8" 13,502' 10,075' 8,150psi 5,090psi Liner 2,005' 7" 15,200' 11,499' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" L-80 3' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker 9-5/8"x 7"Type'H'Packer and N/A 13,203 MD/9,836 TVD and N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory 0 Stratigraphic❑ Development❑ Service ✓❑ • 14.Estimated Date for 15.Well Status after proposed worlt: 3 Commencing Operations: 4/16/2018 OIL 0 WTRSP /.5,( WDSPL ❑ Suspended 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG El Commission Representative: 4/15/2018 GINJ ❑ Op Shutdown 0 Abandoned El 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman ?•„J Authorized Title: Operations Manager Contact Email: twellmanta7hilcorp.com Contact Phone: 777-8449 Authorized Signature: Oil Date: 3/28/2018 `� COMMISSION USE ONLY Conditions of approval: otl1 ify Commission so that a representative may witness Sundry Number: 3 )2) , I Ll9 Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: tNtl Post Initial Injection MIT Req'd? Yes ❑ No ❑ , Spacing Exception Required? Yes ❑ No 2( Subsequent Form Required: /0 4-167- oDto APPROVED BY Approved by: sCLGEr COMMISSIONER THE COMMISSION Date: 14 it,ite) 9:--o,-Ae ORIGINAL „fir", dormand ./8 Form 10-4 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate i • Et. Reservoir Abandonment Well: END 2-66 Hamm Atka.LL Date:03/22/2018 Well Name: END 2-66 API Number: 50-029-22374-00-00 Current Status: LTSI—Suspended Pad: Endicott Estimated Start Date: April 15, 2018 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 193-079 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907)947-9533 Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: WeIIEZ Input Required: Yes Maximum Expected BHP: 4,333 psi @ 10,000' TVD (Normally Pressured Zone) Current Shut-In Tbg Pressure: 590 psi Max. Predicted Surf Pressure: 590 psi (Max tbg pressure recorded w/o plug installed) Brief Well Summary: The Endicott 2-66 well was drilled in 1993 across the SW fault of the Endicott field. The target were the USZ's of the Kekituk which tested wet across the fault. The production liner was run and s_Relforatei o confirm it was wet. The well was never completed.' In 2012 the production liner was cemented with coil tubing from PBTD lo 13,539' md. An attempted pressure test of the cement plug failed which led to an LDL indicating leaks in the casing below 8,900' md. An IBP was then set at 4,025' and and pressure tested to 1500psi as reservoir isolation. z (OnCuf• Wellbore Mechanical Condition: 06/19/94 Perforated from 14,632'-14,652' md,tested wet. Did not run completion. Install dry hole tree. 9/10/12 Coil tubing lay in 53bbls of 15.8ppg balanced cement plug from PBTD (14,977' md)to est TOC at 13,820' md. 10/13/12 Slickline tag TOC at 13,539' slmd. 10/20/12 MIT failed with injectivity of 3bpm at 1152psi. 11/21/12 E-line ran leak detect log indicating anomalies at 8,900' and 9,500' md. 12/20/12 Set IBP at 4025' and and MIT-T to 1500psi passed. The perforations in the S3A2 sands of the Kekituk have a cement plug placed around them. This cement plug was confirmed with a slickline tag at 13,539'or 1,093' above the perforations. The well has a casing leak. The leak is suspected to be below 8,900' md. The run on 11/21/12 leak detect log indicated anomalies but couldn't definitively confirm leak points. Objective: The objective is to use the ASR #1 to perform a reservoir abandonment of the current formations exposed and to decomplete the well in preparation for sidetracking the well with the Innovation Rig. Saftey Note: Many wells at Endicott have high H2S readings(>250ppm)in the gas lift or gas injection system. The Endicott 2- 66 was drilled into a water wet zone and never produced since it was drilled in 1993. Standard precautions and an additional section in the Sundry Review Meeting should be highlighted to handle potential H2S, especially during the circ out and loading of the well. Procedure dp, . iit r Reservoir Abandonment Welk END 2-66 ilikerp 41. 1.2.LLDate: /22/2018 Coil Tubing 1. MIRU CT unit and spot support equipment. Fill uprights with filtered seawater. 2. Pressure test BOPE to 250psi low/2,500 high, 10 min each test. a. Each subsequent test of the lubricator will be to 2,500 psi Hi, 250 Low to confirm no leaks. 3. MU inflatable cement retainer BHA. 01 �t 4. RIH to ±8,000' md. Bring pumps online and establish injection rate down coil tubing. "Sy 5. Set inflatable cement retainer at±8,000' and as per service representative. ei 6. Shut down on the pumps and pull release from the inflatable cement retainer. 7. Pressure test casing to 1L500psi for 30min. Bleed down pressure to"500psi. JO- ex '-i r k• 8. Begin to mix cement. Once upto 15.8ppg, begin pumping cement down the coil tubingwhile g ppg, g� p p g C.t t taking returns from the IA. a. Use freshwater spacers as needed around the cement. 9. Once 1 bbl of cement has exited the coil nozzle and come up around the coil, begin to lay in cement for 37bbls. ,v Y a. Estimated TOC at 7,500' md. '''6X 10. Pick up to safety and circulate to ensure coil tubing is clean. Wash down to 7,500' and to give clean TOC and POOH. . a. Wait on cement to reach 500psi compressive strength. 11. RIH with nozzle and memory logging (CCL) BHA. 12. Tag TOC and log up from TOC-6,500' md. l a. Stop at 7,300' and and paint flag on coil. 2 �tit, k 13. Perform CMIT-TxlAto 2,500psifor 30 min (charted). r,� tT a. Contingency if the CMIT-TxIA fails. E5� ""1.MU memory logging tools (spinner, temp, pressure) and perform LDL from TOC to 4,000' md. ii. Take stop counts: 10' above TOC, every 500' up to 4,000' md. iii. Confirm with Ops Engineer prior to performing secondary cement plug to isolate casing leak. 14. MU and RIH with 5' perforating BHA. c(/ 15. Correct depth at flag and continue to RIH. Tag TOC, PU ±20', drop ball and perforate casing from r ±7A75'-7,480' md. b 0�'�s`4 16. Block in returns and confirm injectivity through perforations. POOH. 17. MU cementing BHA and RIH. 18. Tag TOC and PU. Begin mixing cement and pump ±20bbls of 15.8ppg Class G cement down the coil while taking returns from the IA. a. Use freshwater spacers as needed around the cement. 19. Once 1 bbl of cement has exited the coil nozzle and come up around the coil, begin to lay in cement for 20bbls. a. Estimated TOC at 7,226' md. 20. PU to safety and squeeze 5-10 bbls of cement behind casing. a. Estimated TOC after 10 bbls squeezed at 7,363' md. 21. Circulate coil clean and POOH. a. Wait on cement to reach 500psi compressive strength. . RU N2 unit and pressure test all lines to 250psi low/3,000psi. F----- 23. RIH pumping N2 and lifting fluids out to return tanks. Once"73bbls of wellbore fluids have been returned in tanks, SD pumps and POOH. 55(2 � a. Take into account the volume of fluid stored in the coil tubing reel for return fluids volumes. (flitr " • • Reservoir Abandonment Well: END 2-66 Hitraerp Alaska,Ur Date:03/22/2018 b. Do not pump any fluid freeze protect into the well. The N2 cap will serve as the freeze protect. 24. RD coil tubing unit. Operations & Pumping —To be coordinated as close as possible to the Innovation moving onto the well to minimize chances for freezing. Nt.+1-6 f-*•_ Q1.te9• M 1'- 25. Shoot IA FL and bleed T/IA to near Opsi. /lou) 5 o 26. RU Little Red Servicesp. Setup reverse out skid and 500 bbl returns tank and additional upright tanks as needed. 27. Pressure test lines to 3,500psi. 28. Lube and bleed in seawater until well is liquid packed. a. Volume to load (based on FL at 1,000' md): 0.0732bpf x 1,000' =73bbls Attachments: 1. As-built Schematic 2. Proposed Schematic • Duck Island Unit Well: END 2-66 SCHEMATIC Last Completed: 10/2/1993 Ham AL.ty.MCPTD: 193-079 KB Elev.:57'/BF Elev.:15' SAFETY NOTES TREE&WELLHEAD Doyon 15 H2S Readings Average 230-260 PPM on A/L&Gas Injectors Tree 4-1/16"CIW Well Requires a SSSV Wellhead CIW 20" = `=' OPEN HOLE/CEMENT DETAIL 13-3/8" 1s`Stage:550 sx,12#Class E/2nd Stage:400 sx,15.8#Class E in 16"Hole . \ i 9-5/8" 1s`Stage:507 bbls,11#Class G/2"d Stage:81 bbls,15.8#Class G in 12-1/4"Hole 13-3/8" "'• .i72: 7" 158 bbls 15.8#Class Gin 8-1/2"Hole 9-5/8"Maker CASING DETAIL Joint:443'to 60/40 463 Size Type Wt/Grade/Conn ID Top Btm BPF MeOHNVater Fluid Bottom 20" Conductor N/A/N/A/N/A _ N/A Surface 131' N/A 13-3/8" Surface 68/N-80/Btrs 12.415 Surface 2,872' 0.1497 9-5/8" _ Production 47/NT80S/NSCC 8.681 Surface 10,056' 0.0732 Sea Water 9-5/8" Production 47/NT95HS/NSCC 8.681 10,056' 13,502' 0.0732 7" Liner 12.6/13Cr-80/NSCC 6.184 13,195' 15,200' 0.0372 -+ TUBING DETAIL 4-1/2" Tubing L-80 3.958 Surface 3' 0.0152 JEWELRY DETAIL No Depth Item 1 13,195' Baker Tie Back Sleeve 2 13,203' 9-5/8"x 7"Bajer Type'H'Pkr w/Flex Lock Liner Hanger WELL INCLINATION DETAIL Q+` I"a KOP @ 500' c' Max Hole Angle=57 Deg. @ 9,500' r V PERFORATION DETAIL END Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Sae END 14,632' 14,652 10,996' 11,013' 20 12/26/1993 Closed 3-3/8" Notes:Tie-in to SBT dated 11/1/1993:Perfs Info–Atlas 3-3/8"Guns at 6spf,60 degree phasing,random orientation and m 21 gram charge. GENERAL WELL INFO J 1 131 j API:50-029-22374-00-00 Initial Completion -10/2/1993 9-5/8", • r t2i35�>s: Set TOC -9/10/2012 Set Bkr IBP–12/21/2012 Baker 3-3/8"IBP Estimated TOC pushed below ( 1012)@ 13,300'possibly 413,820 an top of cemer>t 9-5/8"Marker 4—Joint:14,19G to 14,21G 7" - '41 (7 loc.: IAA' TD=15,203'(MD)/TD=11,501'(TVD) PBTD=15,179'(MD)/PBTD=11,480'(TVD) Revised Bir:RDF 3/112618 • • Duck Island Unit II Well: END 2-66 PROPOSED SCHEMATIC Last Completed: 10/2/1993 Hilcorp Alaska,LLC PTD: 193-079 KBEJev.:57/BFEIev.:15' SAFETY NOTES TREE&WELLHEAD Doyon 15 H2S Readings Average 230—260 PPM on A/L&Gas Injectors Tree 4-1/16"CIW I I Well Requires a SSSV Wellhead CIW 20"j':., ,,-/ OPEN HOLE/CEMENT DETAIL 13-3/8" 1st Stage:550 sx,12#Class E/2nd Stage:400 sx,15.8#Class E in 16"Hole 9-5/8" 1st Stage:507 bbls,11#Class G/2nd Stage:81 bbls,15.88 Class G in 12-1/4"Hole 13-3/8" 7" 158 bbls 15.88 Class G in 8-1/2"Hole 9-5/8"Marker CASING DETAIL Bottom @ Jont:443 to two 463' Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor N/A/N/A/N/A N/A Surface 131' N/A Seawater�6. 13-3/8" Surface _ 68/N-80/Btrs 12.415 Surface 2,872' 0.1497 9-5/8" _ Production 47/NT8OS/NSCC 8.681 Surface 10,056' 0.0732 9-5/8" _ Production 47/NT95HS/NSCC 8.681 10,056' 13,502' 0.0732 7" Liner 12.6/13Cr-80/NSCC 6.184 13,195' 15,200' 0.0372 TUBING DETAIL 4-1/2" Tubing L-80 3.958 Surface 3' 0.0152 JEWELRY DETAIL No Depth Item 1 ±8.001 a-5/8"CIBP �v� 2 13,195' . Baker Tie Back Sleeve b N` / 3 13,203' 9-5/8"x 7"Bajer Type'H'Pkr w/Flex Lock Liner Hanger TOC@t 5 WELL INCLINATION DETAIL KOP @ 500' C' 1 Max Hole Angle=57 Deg. @ 9,500' PERFORATION DETAIL END Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status Size ±7,475 ±7,480 ±5,930' _ Future 2 END 14,632' 14,652 10,996' 11,013' 20 12/26/1993 Closed 3-3/8" 9-5/8"41 '3 Tie-in to SBT dated 11/1/1993:Perfs Info—Atlas 3-3/8"Guns at 6spf,60 degree phasing,random orientation and GENERAL WELL INFO Baker 3-3/8"IBP Estimated TOC pushed below (9/10/12)@ API:50-029-22374-00-00 13,300'possibly ' 13.823 Initial Completion -10/2/1993 on top of cement • Set TOC -9/10/2012 Set Bkr IBP—12/21/2012 • 9-58'Maker ', ,4—Joint:14,197 . to 14,210 • • ' 4. 7 . TD=15,203'(MD)/TD=11,501'(ND) PBTD=15,179'(MD)/PBTD=11,480'(ND) Revised By:TTW 3/23/2018 • • STANDARD WELL PROCEDURE IfilcorpAlagka,LIR: NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets(formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H25/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure),whichever is higher.Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • 1111) Ui 0 0 co w 1— x x r r D Z X U .0 O . 1 w r to W a 0 a 0 T a N D T a a N G. X m O O O ® ®� _ ~ V C v .T. .T. U o N .L @ Ili Ill ilii 1111 u▪l — @ ill :Ilii a liii.� 1I l .ac a.: !} Illi Rio o11 pp I1410•1i--.110.0, 3 fp. • 104 N. . _._.. i • • o `m o • 'i 4 F. i r r•••.0 z w w hr7 • ..{ O N 2 N N C p„ ni Z : Z -1111 P• < C N .061. m • r�� N •• 0 U�o• p O. Z Z '` _ D C Z : 3 ;`_sa r , • • Schwartz, Guy L (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Friday,April 06, 2018 1:05 PM To: Schwartz,Guy L(DOA) Subject: RE: DIU 2-66 plug for Redrill (PTD 193-079) Attachments: END 2-66 PROPOSED SCHEMATIC 3-28-2018.pdf; STANDARD WELL PROCEDURE - NITROGEN OPERATIONS FINAL 12-08-15.pdf;Coil Tubing - Fluid Flow Diagram (Nitrogen) 11-22-15.pdf Guy, Here are the answers to your questions below. If you would like me to resubmit, let me know. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer:Alaska North Slope Team Office: (907)777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday,April 05, 2018 1:49 PM To:Taylor Wellman Subject: RE: DIU 2-66 plug for Redrill (PTD 193-079) Also, 1)Why Nitrogen lifting to evacuate fluids? Why go through all that and use CT to displace and FP.—The N2 would be used as our freeze protect in the well. The Innovation rig really doesn't want to bring hydrocarbons anywhere near our pit system. If we had a kill string in the well we could circulate it out directly to tanks. With the way the well was left without a kill string I won't have a way to easily circulate out a liquid freeze protect without putting coil tubing back on the well. 2)don't see where you are running the 2000 ft kill string in procedure. ( kill string shown in proposed schematic)—You are completely correct. I attached the wrong Proposed Schematic once I changed the methods to do the sidetrack prep. Please see the attached schematic. 3) if using N2 will need SOP sheet in the sundry—Attached. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 1 • •) From:Schwartz,Guy L(DOA) Sent:Thursday,April 05,2018 1:44 PM To:Taylor Wellman<twellman@hilcorp.com> Subject: DIU 2-66 plug for Redrill (PTD 193-079) Taylor, Same as the other well being prepped for sidetrack. Could you answer a couple of items: 1. Need the outline of the rig drilling program up to milling the window.. (ie once rig shows up to drill). - Pull 4-1/2" pup joint/"kill string" - TIH, circulate well full, dress off cement topto desired depth,TOOH p ) - TIH w/whipstock and window mill (single BHA) 2. Why are you squeezing the 9 5/8"casing at 7480 ft? -The TOC behind the 9-5/8" is below this point. The aim is to place cement between the 9-5/8" and the formation to support the casing while milling the window. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 2 • • Sundry Application Plug for Re-drill Wells Work Flow 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 Responsibl 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist 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 both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then I/ it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech 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." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. • • I !:1..,` Post Office Box 244027 tl t� Anchorage,AK 99524-4027 Hilcorp Alaska,LLC ,AUL 3 V 201`7 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 AOGCC Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 --- 01 01 Anchorage, AK 99501 I a&6' Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, CANNED S - 9 0 9n Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I"followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig • New I API_WeIINo I PermitNumberl WellName I WellNumber WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-66SD12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/5D9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/1(33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-176 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E ect Well History File CoverOge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier III IIIIIIIIIII IIII [] RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERL ~O~~BIN INCENT SHERYL MARIA WINDY Other items scannable by large scanner OVERSIZED (Non-Scannable) ~ Logs of various kinds [] Other Project Proofing Scanning Preparation ? x 30 = ~-.~'-~-~ +~ = TOTAL PAGES BY: BEVERL~CENT SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,~ YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREP~ERE FOUND: YES BY: BEVERLY ROBIN VINCENT SHERYL MARI(~ WlND~ DATE.~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON'~AL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNED BY~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~~`~ ~ ~~ FILE # Pi~[~(DCtC1//'1/~){'1 ~~S(~~/V( To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission k333 W. 7th Ave., Ste.100 # Anchorage, Alaska 99501 Voice (907) 279-1433 ~ Fax (907) 276-7542 • • bp BR Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 Mr. Jim Regg °13.-C49 j '� Alaska Oil and Gas Conservation Commission S Y I L 333 West 7 Avenue c�— Alaska 99501 C�� Anchorage, a � Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, 1; Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 2 Date: 03/28/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END2 -02 / P -18 , 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 _ 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 / 0-16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0-16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28(2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0-19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/28(2010 END2 -30B / ME -01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN-03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 END2 -44A / 0 -11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -46B / S-13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0-13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S-14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 / 0 -12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / El01 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / 0-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 ..----'7END2 -66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S -17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 • • rffaffE DEF SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Dan Kara Engineering Team Leader BP Exploration (Alaska), Inc. l' P.O. Box 196612 (� Anchorage, AK 99519 -6612 Q s"°11 Re: Endicott Field, Endicott Oil Pool, 2-66/ SD-2 Sundry Number: 311 -329 Dear Mr. Kara: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, D. -•- T. Seamount, Jr. Chair h DATED this Z day of November, 2011. Encl. • STATE OF ALASKA ( s ALASKA OIL ANT S CONSERVATION COMMISSION id CitIVED APPLICATION FOR SUNDRY APPROVAL 16 Q - 2 5 201; 20 AAC 25.280 1. Type of Request: ka nd & Gas Cons. Commis, ion l (!a�/ r ❑ lu for Redrill n Perforate New Pool ❑ Repair Well ❑ Change ved Pro Suspend � k O Plug Perforations Perforate ° ❑ Pull Tubing ❑ Time Extension Ancnorage ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 193 -079 3. Address: ® Service . ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029- 22374 -00 -00 ° 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: • END 2- 66/SD -12 - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 034633 & 034636 Endicott Field / Endicott Pool ° 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15203' • 11501' - 14977' 11298' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 20" 31' 31' Surface 2829' 13 -3/8" 2871' 2738' 5020 2270 Intermediate 13457' 9 -5/8" 13502' 10075' 6870 4760 Production Liner 2005' 7" 13195' - 15200' 9830' - 11499' , 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: None Packers and SSSV None MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Development IN Service 14. Estimated Date for . 1� e , 10 15. Well Status after proposed work: Commencing Operations: f � ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR figt'7itrael Commission Representative: ❑ WAG ❑ SPLUG ViSuspende*,10 ‘.. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564 -4102 Printed Name n Kara Title Engineering Team Leader } }} Prepared By Name /Number: Signature f gpi, Aow4 Phone 564 - 5667 Date / /��r 11 Terris Hubble, 564 -4628 Commission Use Only w Con ions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ( Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: / � 26 MC.. Z 1. c. 1/O 4- i r-- / 4/ 1 4,. A 4,6_ / 1 / 04 ct P.. e#. F 7f/)dt? Ai d - f ;f 7 h see / 4 1.(..);44.‘.3-3- / 0 Ito J • f 1-.13 co -- Subsequent Form Required: / _ u co -- V ` 1 / APPROVED BY 1 Approved By: / COMMISSIONER THE COMMISSION Date 6 Form 1 �+ ; ,iteld 01 /611 b „ ry ..41,-._ _ , G /0 3 /° f ( Submit In Duplicate ,deft°44 /12.24 • • Summary of Proposed Work BP Exploration Alaska Inc (BPXA) Re -plug Reservoir and Suspend Program Endicott 2 -66 PTD 93 -79 API No. 50- 029 -22374 Present Well Condition The well was drilled to a depth of 15,200' MD, and is cased as follows: Casing Size Weight Grade Depth Cementing Record (MD) Conductor 20" 131' Drive down Surface 13- 68# NT -80 2872' l stage: 550 sx, 12# Class E 3/8" 2nd stage: 400 sx, 15.8# Class E Intermediate 9 -5/8" 47# NT- 80/NT -95 13,502' 1 stage: 507 bbls 11# Class G 2nd stage: 81 bbls 15.8# Class G Production 7" 29# L -80 13Cr -80 15,200' 158 bbls 15.8# Class G The operation to re -plug the reservoir of the well is scheduled to be performed approximately November 2011. The rationale for suspending the well is that End 2 -66 may be used as a water-source well for future projects and thus BP wishes to preserve the wellbore for possible future use. V - In June 1994 the perfs were squeezed and post squeeze PBTD was tagged at 14,977' SLM. The procedure below outlines the steps to perform reservoir plugging and suspension: Procedure to Suspend End 2 -66: 1. Service and pressure test tree n / 2. Re- perforate (depths TBD) 4- jc 'c .v►,... BHP 1A4-4t S°w, "1 3. RU SL, tag PBTD (expected @ 14,977' MD) and SBHPS • 4. RU CTU, squeeze perforations, leave TOC @ -44,000' MD — -37 Bee, eµT ��r � ZSbow.: 5. Pressure test the cement plug to 1 psi — ( A 71/P !0 3i1i • • End 2 -66 Permit No. 93 -79 API No. 50- 029 -22374 Current Status Surface I • / 3' Pup Joint of 4 -W 20" Conductor @ 131' MD Tubing • Diesel to 1050' (62 bbls) Crude in OA down to -1700' MD (100 bbls) Sea w/ w Water 02 scavenger • 13 3/8 ", 68 #, NT -80 @ 2872' (70 Water w/ 2000' M D) MD Cemented w/ 550 sx Class E 12.0 ppg (1 stage) & 400 sx Class G @15.8 ppg (2 stage) Cmt to surface. Sea Water to PBTD j Top of 7" @ 13,195' MD 9 5/8 ", 47 #, NT -80/95 @ 13,502' MD Cemented w/ 507 bbls Class G 11 ppg & 81 bbls Class G 15.8 ppg Diesel j Cement Bond Log 11/1/93: Good bond to .� — 14,400' MD, Poor bond to 13,700' MD, No Cement above 13,700' MD Cement Crude Perfs 14,632' - 14,652' MD (Squeezed 6/19/94) Sea Water PBTD @ 14,977' MD (tagged 6/22/94) 7 ", 29 #, 13 Cr -80 @ 15,200' MD Cemented w/ 158 bbls Class G 15.8 ppg .037 8�� • • End 2 -66 Permit No. 93 -79 API No. 50- 029 -22374 Proposed Status Surface I 3' Pup Joint of 4 -Y" 20" Conductor @ 131' MD Tubing Diesel to —2000' (62 bbls) Crude in OA down to —1700' MD (100 bbls) 4 Sea Water 13 3/8", 68 #, NT -80 @ 2872' E D 12.0 ppg (1 stage) & 400 sx Class G @15.8 ppg (2 stage) Cmt to surface. Top of 7" @ 13,195' MD 9 5/8", 47 #, NT -80/95 @ 13,502 MD Cemented w/ 507 bbls Class G 11 ppg & 81 bbls Class G 15.8 ppg Cement to —14,000' MD Diesel Cement Bond Log 11/1/93: Good bond to 14,400' MD, Poor bond to 13,700' MD, No Cement Cement above 13,700' MD Crude Perfs 14,632' — 14,652' MD (Squeezed 6/19/94) Sea Water PBTD @ 14,977' MD (tagged 6/22/94) 7 ", 29#, 13 Cr -80 @ 15,200' MD Cemented w/ 158 bbls Class G 15.8 ppg • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art / or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 I/ form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve ✓ D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accu racy. Thanks, Steve D. file: / /F: \Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 10/6/2011 Page 1 of 1 • Maunder, Thomas E (DOA) From: Daniel, Ryan [Ryan.Daniel @bp.com] Sent: Thursday, May 12, 2011 3:06 PM To: Maunder, Thomas E (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA) Cc: Cismoski, Doug A; Kara, Danny T Subject: RE: Endicott 2- 66/SD12 (193- 079) - -water supply well ?? Good Afternoon Tom, BP plan to submit a sundry and suspend this well in the near future. Let me know if you have any other questions. Ryan Daniel t i F 4 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, May 04, 2011 8:28 AM To: Daniel, Ryan; Cismoski, Doug A Cc: Schwartz, Guy L (DOA); McMains, Stephen E (DOA) Subject: Endicott 2- 66/SD12 (193- 079) - -water supply well ?? Ryan and Doug, Would you look into the history and potential forward plans for this well? This is one that seems to be lurking just below the radar. I had asked some questions in 2009 when it popped up as a waste disposal well out there. I requested information and got some reports regarding perforating and possible testing for water in 1993. So far as we over here can tell, the perforations may have been squeezed although the cement was cleaned out and the well does not have any tubing in it. Thanks in advance. Tom Maunder, PE AOGCC 5/16/2011 Page 1 of 1 ~ ~ ll~aund~r, Thorn~s E (QOA~ Fram: F~reble, Gary B (SAIC) [Gary.Preble~bp.com] Sent; VNeeinesday, August 05, 2Q09 2:1~ PM To: Maunder, Thomas E (DOA) sub~ct: RE; Q1u 2-ss-sQ-1z (1g3-Q79} St~ve NfcM~in~ c~li~d m~ ~b~ut it ~~veral w~eic~ ~~o ~~d r~qu~~~d th~t !~ubmit the ~crr~dry. ~rom; Maunder, Thomas E (QQA) [maitto<torn.maunderCc~ataska.gt~v] S~nt: Wednesday, August QS, 2049 X:~2 PM To: Preble, Gary B(SATC) ~,~«~~'~.•~~~,{;; ~[~E. :~4' ~~~c~. Subjectc ~I~I 2-66-SE~-12 (193-0?9} Gary, You just s~bmitted a 404 regarding s~ueeze work cqmpieted on this well in Jun~ 19~?4. What promptec! submitting the doeum~nt? Is this thre weft that was invotved with thp im~are~~er vrraste dis~ZOSa['? Thartks in adv~nce. Tom Maund~r, P~ AOGCC ~ o~ s~~.~c.sS ~\ ~E-- c~\ ~ Sc~s .'~p~~c-- Pc~i~S~.~ c~s v.Sa~€c-sv4 P 1 w ~ ~.\ ~ ` ~o~l SJbN:., ~c~ . ~~, ~ _c, ~ ylCo~n~~c~..~-~ ` c~~ sE.~t Lt~ ~ w~~~ '"1~~~- ~~s, `l~~ ~~~ ~-l~~ ~QQ~rov~c~ ~~~~c-~ore~..~E ~i.> c~~~-- s(~v~.~ S ~ ~s'~- ~ ~~ -- c~ ~ ~-,ld `-~ oc-~-~ ~ E~`~`~c~~ ~ . ~~ ~ ~' ~ p ~ ~ ct~v..-~c~~ ~~ s~.~w~~ ~`l c~.~l-~~~.s wE~.\ ~.. ~ ~~~~ ~_ ~~ ~i ` ~ cf~C?~. ~~~ `~~,~`'~ ~C~p~ c-~ S`J ~'~~ c~.~- ~p ~-s ~ c-~ w~~~ ~ \ ~ V~< S~t~.~ ~~ ~ ~~ ~ ~~ ~ ~ ~,~C~~ ~ ~3 ~ ~~ ~1C~~~ ~.~ ~ ~ 5~~~~~ v.~ 0~~.- ~iC``~p~` ~~` ~ ~~~ `~ ~ ~ C.~C.~C ~~-~- vv.1C~~ p \~`'~-~ ~C "~ ~~ ~ \ ~J ~ ~ ~ i ~ ~ ~ ~~c~,~SC~ ~~~ ~ ~o c~v~-~ ~. ~ ~'~ ~ C~.~~ C G G - ~ .~- ~~-~-- ~~E ~ ~ \ ~~-- ~ ~~ ~ t~ ~ ~` ~ ~ b ~ ~ ~~ \ C..~~~~~ w ~ ~ t S ~ S ~~,..~i~~. ~~C ~~~,~~5~ ` ,~ V~r~C,~ ~ ~k~~~ ~s ~~ c~~~~~ 5~'~ ~~~~ ~c~.~ ~ ~-J~~ ~ '~~ Jt-E ~~~5 v~~~v~ ~ ~ ~c~~~c. _ ~ ~ ~- c~ e~ ~ ~ ~~-.`~ h ~ g~~~z~~~ ~l~ `~~, STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OP~RATIONS ~ ~~~~~~~~~~~ (~' ~" ~ ;~ e "Ii ~ i'S {tJ , ~ .... .~ 1. Operations Abandon ~ Repair Well ~ Plug PerForations ulate~ Qt ~~ . ~,~p~~=~~~~~ ~ ~~~~ ~ ' Performed: ~ ' Alter Casing ~ Pull Tubing ~ Perforate New Pooi ~ ~5 Waiver~ Time ~~ension Change Approved Program ~ Operat. Shutdown~ Perforate ~ Re-enter Suspended Well~ '"' "'°`~~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: Development [! Exploratory ~ 193-0790 0 3. Address: P.O. Box 196612 Stratigraphic ~~ Service ~, 6. API Number: Anchorage,AK 99519-6612 50-029-22374-00-00~ 7. KB Elevation (ft): 9. Well Name and Number: 56 KB 2-66/SD-12 ~ 8. Property Designation: 10. Field/Pool(s): ~ ADLO-034636 Endicott Field/ Endicott Oil Pool 11. Present Well Condition Summary: Total Depth measured 15203 , feet Plugs (measured) None true verticai 11501.28 feet Junk (measured) None Effective Depth measured 15179 feet true vertical 11479.59 feet Casing Length Size MD TVD Burst Collapse Conductor 94 20" Surface - 131 SurFace - 131 Surface 2829 13-3/8" 68# NT-80 Surface - 2871 Surface - 2738 5020 2270 Intermediate 13457 9-5/8" 47# NT80/NT95 Surface - 13502 Surface - 10075 6870/8150 4760/5080 Liner 2005 7" 29# 13CR80 13195 - 15002 9830 - 11499 8160 7020 Perforation depth: Measured depth: see attached - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) none 0 - 0 0 - Packers and SSSV (type and measured depth) none 0 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: si Subsequent to operation: si 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Dev~elopment ~"" Service ~- Daily Report of Well Operations X 16. Well Status after proposed work: water sun~lv well Oil ~ Gas ~ WAG ~ GINJ ~ WINJ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ~ N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature e Phone 564-4944 Date 7/31/2009 ~ s Form 10-404 Revised 04/2006 Submit Original ~' ~~~415 I~t~ ~~~~ a ~ 2oos ~I5 ~~~~~~( 2-66/SD-12 193-079 PERF OTTACHMENT i Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 2-66/SD-12 12/26/93 PER 14,632. 14,652. 10,995.57 11,012.97 2-66/SD-12 6/19/94 SQZ 14,632. 14,652. 10,995.57 11,012.97 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO S7RADDLE PACK, OPEN OH OPEN HOLE • TO: LITTLEFIELD • LOCATION: ANCh•~RAGE FROM: WARREN/ SEVCIK D A T E: 6/18-19/94 WELL: 2-66 OPERATION: CT WSO SQUEEZE / SD-12 Initial Weil Statu SIWHP IAP OAP GLP FLP FLT si si si si si °F 250 "500" 0 N/A NiA N/A TIME DEPTH f t RATE B PM CTP s i WHP s i STG V OL OUT NOZZLE BBLS RETURN REMARKS 23 : 04 2 0 4 6 0 STATIC WHP FROM MAN. TRAII.ER. 23 :12 19 7 / 2 194 0 4 7 0 2 START PUMPING DOWN COIL. 23:13 2 3550 500 4 2 3:17 2 3 6 7 0 510 12 CRACK CHOKES. GAS. 23:42 2500 2/0 500 60 SHUTDOWN. CLOSECHOKES. 23:45 0 460 6/i9 0:04 5000 0 530 450 WT CHECK 7.4 MLB. 0:24 7000 0 450 WT CHECK 10.2 ML.B 0:49 98 77 0/ 2 510 4 5 0 6 0 1tFSUME PUNiPING• 0:51 10000 2 500 WT G~CK 14 MLB. BLEED WHI' TO 480 PSI. 1: 09 120 8 0 2 4 8 0 9 9 WATER TO SURFACE. 1:17 13000 2 480 114 WT CI~CK 19S MLB. 1: 30 14 314 2 3 40 0 5 00 13 9 CLOSE CHOKE. 1: 32 14545 2 5 10 14 3/0 COME OFF PUMP. 1: 40 1415 4, 0 4 3 0 WT 25 MLB. NO CORREC"TION MADE. P/U TO 14,900 1:50 14900 2 4 20 5 PAINT FLA r. START COOLING SUMP 10 LBS IJNDERBALANCED. 1:52 " 2 3230 420 10 WASH UP ACROSS PERFS. 24.5 MLB. 1:58 14600 2 3220 440 23 Increase WHP and wash down. MIRU BJS. 2:08 14900 2 440 41 Increase WHP to 460 si. 2; 27 " 2 440/590 7 7 Close choke. Ease off um . 2:29 " 0 480 79 2:30 " 420 check h drostatics. OK. 2:33 " 0 410 79 resume pumping. Leave chokes closed to check in'ectivit . I NII~I ~illl I~ ~~ I~11 ~II ~~ ~A ~) ~II BP243123 Well: •6 Operation: wS0 Date: ~~8-19/94 TIME DEPTH RATE CTP WHP STG OUT BBLS REMARKS f t B PM s i s i V OL NOZZLE RETURN 2:35 " 2 680 8 3 looks like we have had some lu in 2: 3 8 " 2 7 6 0 8 7 open choke and maintain 450 si. Order acid. 3:15 " 2 3320 450 163 still 50 psi downsVeam of chokes. 3:32 " 2 450 197 Wash u to 14,300 ft. 3:43 14371 2 3320 450 219 Incr. WHP to SQO si. 3:45 14292 2 500 222 RIH• 3:58 14901 2 249/0 Close chokes and shut down. 3: 5 9 " 5 6 0 Hook BJ u to acid ori. 4:12 ~ 430 4:20_. 430 4:30 " 420 Bring BJ on line. Acid on location. H drate chemicals. 4:40 " 2 3448 450 15 Circualting. 58 PSI DS. of chokes. "OA" = 100 si. 5: 20 " 2/ 0 4 7 0 9 5 Chemicals hydrated. Shut down to check h drostatics. 5:22 470 5:24 470 5:26 14901 1 1370 550 1/0 Back on line. BJ mix CMT. 5: 27 " 1.1 15 5 0 5 5 0 1 on acid Chokes o n. 5:31 14892 1.5 2158 550 6 head for erfs. 5:35 14676 1.5 2122 550 11/0 Acid awa . 5:46 14610 2 3425 550 20 58 si DS. of chokes 21 5:47 " / 1 22 Red. rat. cllose chokes. " 1 465 23 " 1 S 0 0 7 6 0 2 4 0 acid to nozzle RIH. 14632 1520 800 25 1 5:51 14653 1 1550 820 26 2 5:52 14670 1 1500 800 27 3 CMT to WT. Acid acdon. POH. 5:53 14642 1 1560 830 28 4 5:54 14615 1 890 29 5 5:55 14610 /0 910 SD. Soak.. 5:56 " 720 5:57 " 640 Resume um in . 5:58 14620 1 700 3U 6 5:59 14633 1 1550 800 31 7 6:00 14652 1 850 32 8 6:01 14663 1 1620 890 33 9 rih to14,670 6:02 14656 1 950 34 10 6: 04 14 6 3 3 1 9 8 0 3 5 1 1 "acid" awa . RIH, 6:05 1740 1040 36 I~II~~~~IIIIIfi~~ I1~~II~II~~IIIIIIII 2' BP243124 Well:•6 Operation: WSO Date: 0~8-19/94 TIME DEPTH RATE CTP WHP STG OUT ' BBLS REMARKS f t B PM s i s i V OL NOZZLE RETURN 6:06 14717 /1.5 1800 1060 37 incr. rate. 14838 1060 39 6:09 14900 1.5 2673 1100 41 6;12 " 1.5 2687 1 130 45 6:15 " 1.5 1170 50/0 (; 28 4 5 0 resume pumping open chokes at 550 si. 6: 3 3 " 2 3 3 2 0 5 5 0 6 45 si DS of chokes. 6:38 5 min fluid loss = 46.5 6•45 " 2 3310 550 29 40 si DS of chokes. 6: 4 8 2 3 5 15 min loss = 46.7 7: 0 2 " 2 3 310 5 5 0 6 8 30 min loss = 48 ML.. Change out crews. 7:10 " 2/ 0 5 5 0 7 8/ 0 shut down Nowcam. 7:12 14901 1.25 1910 550 0 FW ~ ' start freshwater 7:25 0.6 1320 15/0 start cement 7:27 1.5 2120 5 ooh 24k 7•30 14800 11/0 back to FW 7:33 14750 2.0 3800 2 ark 7:46 1.3 1500 23/0 0 back to SW CMT to nozzle 1SW 1 2 2 7:49 3 3 -- ooh 25.6k 4 4 7:50 14700 1550 S 5 7:51 14672 1572 6 6 7:52 14640 1600 7 7 7:52 14615 1620 8 8 lf 7:53 14576 1650 9 9 7:54 14520 1660 10 10 close choke 7:55 14455 0.5 630 1 1 1 1 CMT awa 7:57 14255 480 400 12 7:58 14200 0.75 520 620 13 ark g;02 1470 1000 14 8:02 0 1000 1000 15 sd um monitor ~ 8:18 1. 0 9 7 0 9 7 0 resume um ooh 8• 22 1410 0 17 0 0 10 0 0 17 maintain 1000# circ out as 8:24 14000 1850 18 ark 8:40 3 6 inc wh 8:44 0.5 1770 1500 38 o en choke 8:45 0 1500 1500 39 sd BJ monitor. 27cc/54 min 8:50 1.0 1490 1490 resume um 9•06 2300 53 inc wh 9:09 0 2000 2000 5 6 sd, monitor 9:15 1.0 2000 2000 resume um , inc wh 9:17 0 2500 2500 5 8 sd, monitor 9:31 1.0 2500 2500 resume um inc wh 3 I~~~~~~~~~~II~I~~~~~~~I~~I BP243125 ~ ~~ Well: `~-66 Operation: WSO Date: ..; I8-19/94 TIME DEPTH RATE CTP WHP STG OUT BBLS REMARKS ft BPM si si VOL NOZZLE RETURN 9:36 0.6 3200 3000 61 o n choke woric out as 9•39 0 3000 3000 63/0 sd monitor-stiil ass 9•44 'ft bleed wh as 55 cc 1:52 9•45 1.5 320Q 1500 circ out as at reduced wh 10 • 16 4 3 still asss , et show on road 10:17 1.5 3300 1500 44/0 sd sw to rev 10 • 20 1. 8 0 18 0 0 1 be in LRO rih 64 cc/2:24 10:32 14300 1.7 2400 21 10:56 14530 1.5 2180 61 11:00 14550 2150 68 71 cc/3:08 11:18 14650 2300 99 11:35 14744 2360 128 77 cc/3:44 12:05 14901 1.6 2000 177 ~U I2;25 p 1950 212/0 clean, sd um , monitor 12•29 1950 1950 'ft sw to 'et 12:31 1.7 3700 1500 1 ooh, 'et ass 12:47 14000 35 RIH, 'et ass 13:02 14750 0 1500 1500 61 /0 sd, sw to rev I3:04 1.8 0 1900 1 be in final RO RIH 13:08 14901 2050 5 ark 13:36 0 2200 2200 60 0 monitor 13:40 2200 2200 'ft sw to 'et 13:42 1.7 3500 1500 1 start corr inhib down ct 14 • 02 3 4 corr inhib noz 14:08 4 2 ooh 14•25 14580 70/0 sw to sw 14:45 13100 0 1500 1500 34 0 sd sw to rev 14:53 I6:31 12600 11800 0.6 0.5 1500 1900 1500 1900 4 43 maintain ress on BS finish fixing problems fitting excess i e on reel 16:57 8500 2.0 0 2000 2 sw to diesel dn bs 17:40 17:48 1600 1.5 0.5 2200 73 90 ark, 40% as in rerns close choke, too much gas in returns, ooh. Red rate to min 18:i0 surf 0 2i20 2130 95 sd um ooh 18:12 bleed down 18:21 dis lace ct to sw 18:45 displace ct to N2 (to cut extra ct of 19:10 bleed down 19:20 be in RD 20:10 off location 4 i~lial~qlll~~pl~ll~~~~~~~~l~ll BP243126 • • ~ We11: ~~~-66 Operation: WSO Date: 0~18-19/94 TIME DEPTH RATE CTP WHP STG OUT BBLS REMARKS ft BPM si si VOL NOZZLE RETURN s A Ran in m in and bleedi as off welihead. SIWHP after bleeding gas was 430 psi. Injectivity was 2 BPM at 510 psi. Started cooling sump and observe pe plugging. Ordered acid and coMinued circulating. Reciped 10 bbl 15 % HCt across the perfs, but it just made the plugging worse. Post acid injectivity was 1.5 BPM at 1170 psi. Pumped cemerrt as shown bebw and displaced across perts hoiding 550 psi on choke. Increased pressure to i 000 psi and ver'rfied no bss. increased to maximum 3000 psi over 80 min while circ out gas and held tite. Circ out additional gas, then LRO'd to flag @ 14901'. Jetted to 14000' and back to flag. RO'd one more time until ciean. Circ'd in 70 bbis sw w/ ox en scaven r and left in liner. Reversed in 5 I ie I ' Note: There's also a fair amouM of gas left in weilbore~ NOTE: Recerrt squeezes have had considerable trouble with leaks. Tried a conservative ramp-up on this job. The infiow will tell all, but final pressure test and live cell results indicate that the sbw ramp up may be helping. OPERATIONAL SUMMARY: CMTTO WEIGHT: 05a2 CMT ON PERFS: 07a2 SQZ PRESSURE ATTAINED: 09:36 START REVERSE OUT: 10:17 REVERSE OUT COMPLETE: 12:05 15.8 ppg Class "G cement including Lab thickening time: 7 hrs, 25 min 170 BHCT 0.48 % FL-33 Lab fluid loss: 46.8 CC 0.1 %CD-32 Field fluid loss: 48 CC 0.53 % R-11 Live cell loss: 77 CC . . . _. .... -. _ ~,~ « 0.2 % S-400 rie~a Ari nRer carce: ~~o 1 HS FP-6L Live ceil .cake: 2 3~$ " 11 BBL pumped BBL recovered 7•5 ACID SUMMARY 15%HCI 0.5%NE41 0.5 % ACI - 274 3% Ferrotrol 210 1 % H Tem 382 ~ Cost Code: AFE 684875 9335-070•730 II II TD Tag: 15154 CTD ~I 5 I~Ii~I~~IIIII~IIN~IiI~i I~a~18~II~II BP243127 ...•~~- ~ # We~.. ~-66 Operation: WSO Date. ~u/18-19/94 TIME DEPTH RATE CTP WHP STG OUT BBLS REMARKS ft BPM si si VOL NOZZLE RETURN FLUIDS PUMPED BBLS. DESCRIPTION 143 Circ while RIH. 344 SW Circulate Sum , rtns to surface. 11 15°~HG 78 SW Overflush Acid and Dis lace Coil 15 Effluent Water Preflush 11 C1ass "G" Ceme~ 23 Effluent Water Postflush 107 Sea Water Di IacemeM 212 Sea Water Jettin and Reversin 70 Seawater w/ 20 al Corr inhib 7726 110 Diesei to 15U0' FP BOTTOM-HOLE ASSEMBLY Tool Strin Descri tions O.D. I.D. L e n t h C o m m e n ts Coiled Tubin Connector 2.2" 0.5' Nozzle 3.5" 0.5' Combo Nozzle. 7/8" ball. TOTAL LENGTH 1.0' _ _ 6 INI~~I ~111118~qIaIIaIII~I~~II~IINII BP243128 • • Maund+~r Thornas E t~OA From: Hubble, Terrie L [Terrie.Hubble@bp.com) Sent: Thursday, August 30, 2007 2:45 PM To: Kirchner, Carolyn J Cc: Maunder, Thomas E(DOA); Preble, Gary B(SAIC}; Stewman, Sondra D Subject: FW: Endicott 2-16/SD-12 (193-079) Hi Carolyn, ~ ~dv ~ ~ ~`~ ~~ a-~~ ls~-~a,~-4. I don't think we have met and just by way of introduction I am one of two Drilling Technical Assistants... The other being Sondra Stewman. We are often the first line of contact with questions on wells from the AOGCC. I know that John McMullen left you a voice message in regards to this coming your way. First, I have to apologize to you (and Tom Maunder) for not getting on this request sooner. My only excuse is that I am so darn swamped all the time. I finally took some time today to go back through my list of things that needed my attention to only find that this one had slipped through the cracks and should have been forwarded on to someone in your group long ago. Please see what you can find in regards to this water production testing that was to have been done back in 1993 or 1994. If you are able to find documentation for this testing, Gary Preble can assist you in getting it over to Tom. Thanks, and again I apologize for losing track of this request from the State. Terrie Hubble -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, May 16, 2007 10:50 AM To: Hubble, Terrie L Subject: Endicott 2-16/SD-12 (193-079) Hi Terrie, An old well that I have some questions on. According to our file, the well was dry in the objective formation, however "high quality water sands" were penetrated. A sundry (193-360) was obtained in December 1993 to perforate and test the water production. There is a follow up 404 in the file from late F'ebruary 1994 indicating that the well was perforated in late December 1993. That is the last information in the file. Could you please check BP's file to see if there is any information about tests? If this is not your area, would you please forward on? Thanks much. Call or message with any questions. Tom Maunder, PE AOGCC 1 PERMIT 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 mmmmmmmmmmmmmmmm 5872 ~ 5873~-~ 5920/' 5985~--~' DRY DITCH 407 DAILY WELL OP FINAL WELL&''''~' R FINAL WELL~''''' .... R BD/GR DGR/EWR4 DGR/EWR4 AOGCC Individual Geological Materials T DATA_PLUS m mmmmmmmmmmm, Well Inventory T 2410-15123 OH/FINALS T 4490-15121 RFT OH/MWD OH-MWD · DPR T 12282-13196 13911-15201, S 12430-15203 ~ COMP DATE: 10/02/93 ~ 7/25/93 TO 10/02/93 08/10-12/93 8/28-9/25/93 /'13896-15150 MD ~F/9064-9805 TVD t~' 12286-13227 T-WTF ~W ~ DIL/SFL/SP ( PHSR)~3473-15075 DP/NP/DPR/GR DP/NP/DPR/GR DP/NP/GR DP/NP/GR DPR/GR DPR/GR EXLOG-IFE ~/13896-15150 MD ~'13896-15150 TVD C.L"13896-15150 MD ~"13896-15150 TVD LL~ 13896-15150 MD ~13896-15150 TVD ~388-11504 TVD LDT/CNL(POR&RAW)~'~2600-15048 MUD ~9388-11504 TVD MUD ;~~2640-15203 MD MUD J12420-12762 MD c/ccs MUD Page: 1 Date: 09/29/95 RUN DATE_RECVD ~/01/1993 ~/01/1993 12/06/1993 23-5 02/02/1994 11/02/1993 11/15/1993 11/15/1993 11/05/1993 11/05/1993 11/05/1993 1 09/13/1993 1 09/13/1993 10/04/1993 11/05/1993 11/05/1993 11/05/1993 11/05/1993 11/05/1993 11/05/1993 11/05/1993 10/04/1993 11/05/1993 11/05/1993 11/05/1993 11/05/1993 1 01/24/1994 10/04/1993 1 08/04/1994 AOGCC Individual Well Geological Materials Inventory Page: 2 Date: 09/29/95 PERMIT DATA T DATA_PLUS RUN DATE/_RE C~D 93-079 SBT/GR/CCL mm m mmmmmNmmmmmmmmmmmmmmmmmmm ~~1~340-15148 11/12/1993 93-079 SSTVD ~/13473-15075 10/04/1993 Are dry ditch samples required? ~ no And received? ~ ~~o Was the well cored? yes ~__~Analysis & description receivedt_ "__-~ Are well tests required? yes~eceived? .'?~~'~'* Well is in compliance ~ Initial COMMENTS State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage AK 99501-3192 ·., The Oil and Gas Conservation Commission will release confidential well data to authorized state employees of the Department of Natural Resources, Division of Oil and Gas (DNR/DOG). All data is copied and inventoried and given to the DNR/DOG employee who is responsible for the data as it leaves the premises. Well Permit Number Well Name Item Pages Comment 1) Form 407 (front & back) Formation picks Daily well operations Survey Core analysis Core description Production tests (DSTs) I Digital data Well log Mnemonic Run # Intervals Scale Comments Mud log \ ~ '2~ C ~ ~-- ] ~""~c~ 2~- q-' ti/) ~ ~ .. ..... ~ ........... , ...... ";' 'x r,, .~, '..' ' ' .'~ , ' ' .......... ~'"~ ............ · ..... ~ ~,',' ........ ~ ,,,~.,.,. ,. ~,, .' ,,'v .-, ' "'" ' ,'.~ , .................. ' "':' ~."~dersigned, DN, .R/D9Q elgptloy.q'~'~ccepts receip,.t Of the a-~/'/9,'Ii~c~.denfial data. ' ' '' '.'::'" ,! '~" '1,I l! '~-- (.l~.~', ' i.' d'Q/ . . r '.. ~', ~ '.~-~,. . , · .. , ..... , . ;. ~ -, ,~-r~. ..... ~ ,., .c~-,..e. ": ', .,.:. ,.,.:. , ... " ~ ';.!:,"V I:~ ~. ~'~.:: '" .. " ........ ~; ........ · AO~ 'C....empl0.1;)!cas~ si e}1 ~~,"1~ v~ri~, lxam.,f,.e, ten. ~eg,"'pJ~ data.' ..... . . . Fax Transmittal Cover Sheet From: Kent Richter Division of Oil and Gas Alaska Department of Natural Resources 3601 "C" Street Anchorage, Ahska Phone - (907) 762.2138 Fax · (907) ~62.4360 BP's Duck Island U MPI Number of Sheets_l Fax to:AOC~CC &TTN: lmrry C, mnt API# 0292237400 Permit # 93-0079-0 RECEIVED JUN 21 0il & 6as Co~ .Com~i~0n I request the following well data to be prepared for me to pick up as soon as possible. Thanks for your help. Well History, Completion Report, Core descriptions and analyses; Production test summaries and production detail reports; D~onal Survey and As*built, Permit, Resistivity Log,~$onic. LoSMWD.Los~Mud Log~Horizon Picks. Kent Richter ."-)3 "'C, 79 9 3 - 07 9 93-079 93 - 079 93'-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-0'79 93-079 93-079 93-079 93-079 93-079 93-0'79 93'-079 93-079 93-079 93-079 93-079 93-079 93 -079 93 -0 '79 93-079 D.A TA A O G 'S C Geol ogi'cal i v i d u a 1 t:. e. r' i' a 'I s "F D A'F A ._F' I.. Ij S We 1 '1 I n ye ri t cD r' y 5872 5873 5920 5985 DRY DITCH 40 '7 DAILY WELL OP FINAl... WELL FINAl.. WELL SD/~R DGRIEWR4 DGR/EWR4.(ND) DIL/SFL/SP(PHSR) DP/NP/DPR/mR DP/NP/DPR/GR DP/NP/GR DP/NP/GR DPR/GR DPR/GR EXL, OG-IFE LDT/CNL(POR&RAW) NUD MUD M LID MUD P F: C / C C L RFT RFI" '"'~24'10 .... 15!23 4490- 'i5'i21 ~/~' 13911-15°0i, 12430-15203 '~c. or,.iP DATE: R C.,H/F INAL. S R F"T' OH/'MWD OH-MWD: DPR I 0/02/93 7125/93 TO 10102/93 0 81 1 o ,* 1 219 3 8/28-9/25/93 .~';~ 13896-15150 MD I., 9064-9805 TVD L 1228'6-13227 TVD L 13473-15075 L 13896-15150 MD L 13896-15150 TVD L. 13896-15150 MD L 13896-'15150 TVD L. 13896-15150 MD L 13896 .... 15150 'TVD L 9388,-11504 TVD L 2600-15048 L 9388-11504 TVD L 12840-15203 MD L 12420-12762 MD L 9260-9529 TVD L. I4.550 .... 14.770 L, 13984-15084 L 13984.-15084 F' a 9 e · 1 Da'tie: 04/~."4..,," R I.J N !3 A "1' E .__R E C V D ............... ~ ............... 0 'i/0 1/" 1 :g93 01/0 1/I 99. '-':: 12/06./' 1993 23- 5 02/0 211994 'i 1/0 2,/ 'i 993 I 1,/I 5/1993 11/~s/1993 1 i/05/1993 11/05/'1993 11/0511993 1 09/1 .3/1993 1 09/13/i99~ 10/04./1993 1~/o5/1993 11/o5/1993 1 ~/o5/199~ 11/os/1993 11/o5/199~ ~/os/~9~3 11,/o5/1993 !o/oz,/1993 'l ~/o5/~99~ 'I I/O5/~99~ 11/0511993 1~/o5/199~ 1 ol/24,/ 10/OZ, 1 '1993 1 08/Oa/1994 A O,'3 C ,'3 .11. n d ~' v ~' d u a "1 \,,/e 1 1 G e o '1 o g 'i' c a "1 H a 't: e r' 'i' ,.z~ '1 s Z n v e n t o r' y PERNZT D.ATA T DATA.._P 1.. I. S Page ,'. 2 Date' 0a./2,.'1./'95 RI.N DATE.~R ECVD 93---079 SBT/"GR/Cr"L L. 'i 33~0-- 'i 514.8 i 1/'12/'I99.3 93--079 SSTVO L. 13LI. 73~. 15075 10/' 04. / 'I 991~.'. Ar'e dr'y d"¥tch samp'les r'eclu~'r'ed? And r'ece'f ved? ~no Was 1:he we'1'1 cor'e.d? yes no Ar'e we'l'l tests r'equ'i'r'ed? yes Wel"l ~s '~n comp'l-i'ance COMH EN'TS Anal ys~s & descr"fpt::'ion r'ece'i'ved,? ~ Rece", red ?//~es no yes no 1. Operations performed: Operation shutdown"' Pull tubing. 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3151' NSL, 2360' WEL, Sec. 36, TI2N, R 16E At top of productive interval 1790' SNL, 4408' WEL, Sec. 2, TIIN, R 16E At effective depth 1876' SNL, 4689' WEL, Sec. 2, TIIN, R16E At total depth 1878' SNL, 4689' WEL, Sec. 2, TIIN, R16E 2. Present well condition summary Total depth: measured true vertical .' ? STATE OF ALASKA AL,*.:.:~KA OIL AND GAS CONSERVATION COMMIS,... ~;N '"'/""'.j~ REPORT OF SU. R¥ WELL Stimulate Plugging. Alter casing Repair well 5. Type of Well: Development, Exploratory Stratigraphic Service .. RECEIVED [~,IAR -'i 1994 & Gas Cons. Commission . Anchorage Perforate x "~ Other 6. Datum elevation (DF or KB)'~ KBE = 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-66/SD- 12 MPI 9. Permit number/approval number 93-79/93-360 10. APl number 50- 029-22374 11. Field/Pool Endicott Oil Pool 15203 feet 11505 feet Plugs (measured) Effective depth: measured true vertical 15179 feet 11484 feet Junk (measured) Casing Length Size Structural Conductor 94' 20" Surface 2829' 13-3/8" Intermediate 13457' 9-5/8" Production Liner 2005' 7" Perforation depth: measured 14632'- 14652' Cemented Measured depth True v~.~l depth BKB Driven 131' 131' 550 sx "E"/400 sx "G" 2871' 2738' 1280 sx Class "G" 13502' 10075' 770 sx Class "G" 15200' 11499' true vertical (Subsea) 10996'- 11013' Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaae Production or Injection Data - OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation I16. Status of well classification as: Oil Gas Suspended 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~"~~C ,, .~*"~ ..~~ Title Senior Technical Assistant II Form 10-~ Rev 06/15/88 ~" Service Water Su_~. l_v Well SUBMIT IN DdPLI~;ATI~ Endicott Production Engineering Department . ~ Initial Perforations DATE: 12/26/93 WELL N~: 2-66/SD-12 RECEIVED BP EXPLORATION REP: KIMMET/HOBBS .. SERVICE COMPANY: ATLAS ,'.~'.~...z2:a Oil & Gas Cons. Commission Anchorage NOTE: INSURE THAT THE WELL SITE AREA, WELL HOUSE AND PRODUCTION TREE ARE KEPT FREE OF CRUDE OIL, EQUIPMENT LEAKS OR TRASH. CLEAN UP ANY CRUDE/HYDRAULIC OIL LEAKS BEFORE LEAVING THE JOB SITE. DATE/TIME OPERATIONS SUMMARY , I I .. 1609 RU. Post radio silence signs at the entrance to the island and adjacent to the well site.. 1620 ESTABLISH RADIO SILENCE AND ARM GUNS (Notify rig~ security). 1624 WHP = 0 psig. IAP = 0 psi#. OAP = 0 psig. " 1655. RIH with Gun gl (20 feet): .!80.3.. Tie in to SBT dated 11/1/93. All of the depths listed below are from .... .... ,, . ....... the cased .hole reference log. SIWHP = 0 psig. ' ' ,. 1812 '-'~' .... Hang gun #1 Top Shot at 14632' MDBKB. 1813 Shoot gun #1 from 14632-14652' ,MDBKB. SIWHP = 0 psi#. 1915, SI well and POH. SIWHP = 0 psi#. Confirm all shot, s fired. 1920 .... End ·radio silence. 1.945 '. RD. LEAVE SI. .. "' PERFORATION. SUMMARY: GUN INTERVAL(SBT) ,. CBL DEPTH FEET 1, 14632-14652 20 SUBZONE All intervals were shot using 3 3/8 guns at 6 spf, 60 degree phasing, random orientation, and 21 grams charge. i BP EXPLORATION DATE: 01/24/94 T~ 85436 BP/ENDICOTT MAGNETIC TAPES W/LISTING 2-66/SD-12 OH__/MWD: DPR/DEN/NEU/GR ~3911-15201 1600BPI Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4424. ~AKER REF~1242 Sonya Wallace Petrotechnical Data Center 09/26/93 API#500292237400 'ARCO AMOCO EXXON UNOCAL State of Alaska Jeanne Haas Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 .. ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 9950I. USA Date: 20 January 1994 RE: Transmittal of Data ECC #: 6077.01 Data: NONE Dear Sir/Madam, Refere~c~: BP 2-66/SD-12 MPI ~ ~ . ~ ~? END I COTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL PFC/CCL FINAL BL/ PFC/CCL FINAL RF Run # 1 Run # I Received by: Date: Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson AOGCC Individual Well Geological Materials Inventory Page: Date' PERMIT 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 93-079 re dry DATA T DATA_PLUS SCALE -- BD/GR L 13896-15150 MD 5 DGR/EWR4 L 9064-9805 TVD 2&5 DGR/EWR4(MD) L 12286-13227 TVD 2&5 DIL/SFL/SP(PHSR) L 13473-15075 2&5 DP/NP/DPR/GR L 13896-15150 MD 2&5 DP/NP/DPR/GR L 13896-15150 TVD 2&5 DP/NP/GR L 13896-15150 MD 2&5 DP/NP/GR L 13896-15150 TVD 2&5 DPR/GR L 13896-15150 MD 2&5 DPR/GR L 13896-15150 TVD 2&5 EXLOG-IFE L 9388-11504 TVD 2 LD~/NL(RAW&PORO) L 2600-15048 2&5 MUD L 12420-12762 MD 2 MUD L 12640-15203 MD 2 MUD L 9260-9529 TVD 2 MUD L 9388-11504 TVD 2 RFT L 13984-15084 5 SBT/GR/CCL L 13340-15148 5 SSTVD L 13473-15075 2&5 407 R COMP DATE: 10/02/93 DAILY WELL OP R 7/25/93 TO 10/02/93 FINAL WELL R 08/10-12/93 FINAL WELL' R 8/28-9/25/93 -~&eT~a~W. DRY CUTTINGS S 12430-15203 5872 T 2410-15123 OH/FINALS 5873 T 4490-15121 RFT 5920 T 12282-13196 OH/MWD ditch samples required? Cyes_~ no And received? Was the well cored? yes ~Analysis & Are well tests required? yes ~Received? Well is in compliance ~t~ Commonts ~eA R f'9'/~/~ : description received? 1 01/06/94 DATE_RECVD mmNmmmmmmm 11/05/93 09/13/93 09/13/93 10/04/93 11/05/93 11/05/93 11/05/93 11/05/93 11/05/93 11/05/93 11/05/93 10/04/93 11/05/93 11/05/93 11/05/93 11/05/93 10/04/93 11/12/93 10/04/93 11/15/93 11/15/93 11/05/93 11/05/93 11/02/93 01/01/93 01/01/93 12/06/93 STATE OF ALASKA ,~' , .$KA OIL AND GAS CONSERVATION COMMI,. ..)N APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation Shutdown ~ Re-enter suspended well Alter casing ~ Repair well Plugging ~ Time extension Stimulate ~ Change approved program Pull tubing ~ Variance ~ Perforate X Other ~ 1. Type of Request: 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3151' NSL, 2360' WEL, Sec. 36, T12N, R16E At top of productive interval 1790'SNL, 4408'WEL, Sec. 2, T11N, R16E At effective depth 1876' SNL, 4689' WEL, Sec. 2, T11N, R16E At total depth 1878' SNL, 4689' WEL, Sec. 2, T11N, R16E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service 15203 feet Plugs (measured) 11505 feet BKB 6. Datum elevation (DF or KB) \. KBE -- 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-66/SD- 12 MPI 9. Permit number 93-79 10. APl number 50-029-22374 11. Field/Pool Endicott Oil Pool Effective depth: measured 15179 feet Junk (measured) true vertical 11484 feet BKB Casing Length Size Cemented Structural Conductor 94' 20" Driven Surface 2829' 13-3/8" 550 sx "E"/400 sx "G" Intermediate 13457' 9-5/8" 1280 sx Class "G" Production 2005' 7" 770 sx Class "G" Liner Perforation depth: measured 14632'- 14652'(subsea) true vertical 10996'. 11013'(subsea) Measured cl~ 131' 2871' 13502' 15200' Truj~/~j~rtical depth 131' 2738' 10075' 11499' R £CrclVF..D Tubing (size, grade, and measured depth) none Packers and SSSV (type and measured depth) none DEC ;5 0 1993 Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal × Detailed operations program BOP sketch 14. Estimated date for commencing operation I 15. Status of well classification as: December 1993 16. If proposal was verbally approved Oil ~ Gas Suspended Name of approver R. Douglass 12/26/93 Date approved Service Water Supply Weft 17. I hereby~.c.c.c.c.c.c.c.c.ca~ that the foregoing is true and correct to the best of my knowledge. Signed Title E=nlcr T,cc,,';,n~,c,; A;~c, tcc, t !! - FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- /,(O~( bi,tj ..... Approved by order of the Commission David W. J~)hrt~tQri Form 10-403 Rev 06/15/88 Commissioner I Approval No.~'3 ,.. ~ ~, ~ Date f///,/'¢ V SUBMIT IN TRIPLICATE BP Exploration Endicott Field Well 2-66/SD-12 Temporary Well Test Proposal The recently completed Sag Southwest exploration well, 2-66/SD-12 which was drilled from the Endicott MPI, has been determined to be a dry hole. However, significant footage of high quality water-bearing sand was encountered, providing an opportunity to utilize the well as a source of supplemental injection water for the Endicott Field. This would be especially important during the summer months when seawater is unavailable due to high turbidity levels resulting from fresh water runoff, wave action from summer storms, and increased planktonic activity. Maximizing available injection water will become increasingly important in limiting GOC movement in gas flooded zones, and in maintaining pressure in waterflood intervals. To maximize water production from this well, a downhole pump will likely be utilized. ~"" In order to properly design the pump, additional data are required including natural dl~..~ well productivity, dissolved gas quantity and composition, and water chemistry. The most effective way to obtain these data would be through performing a well test, utilizing the existing Endicott Iow-flow test separator, with the produced fluid processed through the Endicott facility. Currently, 9 5/8" casing has been set, and a 7" production liner is cemented across the productive horizon. No tubing has been installed. Therefore, a well test would involve producing up the 9 5/8" casing. Analysis of cuttings and log data confirm that no hydrocarbon is present deeper than 13,986' md (10,399' TVDSS, or the base of the 3C5 sand), with only scattered tar shows existing below this point. Cement bond logs indicate excellent bond across the Kekiktuk sands, so there is little likelihood of behind pipe channeling. The test would involve perforation of the water-bearing 3A sand in order to obtain an estimate of the interval's productivity. During the flow test, production logging tools will be placed downhole to simultaneously obtain flow rate, pressure,, and temperature measurements. A pressurized downhole fluid sample will also be obtained. It is anticipated that this temporary testing will be completed within a 3-4 day time period. The specific interval to be perforated is specified below and highlighted on the attached log (depth referenced to the 11/01/93 SBT GR). Subzone Depth (mdbrt) Footage. 3A3 14632 - 14652 20 These perforations will be made using 3 3/8" Alpha Jet guns at 6 spf and 600/120° phasing. A lubricator will be installed and pressure tested to 3000 psi for this work. RECEIVED DEC 3 0 199;5 Gas Cons. Commission Anchorage An outline of the proposed testing procedure is provided for your reference: Well Preparation 1. Test 9 5/8" casing to 4000 psi to ensure mechanical integrity (COMPLET£D 1~J8/93, with test to 4400 psi}. 2. Install jumper to well 2-68 surface flowline. Ensure well 2-68 is shut-in at the SSV and SSSV. Zone 3A Test (3-4 days) NOTE: · . . · · · The well is currently ~200 psi overbalanced (displaced with 9.9 ppg brine and freeze protected t0'1500' With 100 bblS dead crude = {[10,9'56 - 1500] * 0.515 + [1500 * 0.397]} = 5465 psi; 3A3 pressure from RFT data = 5262 psi). .. Rig up lubricator and pressure test to 3000 psi. Rig up e-line and perforate the 3A3 sand, from 14632" md.to 14652' md uSing 3 3/8" Alpha Jet guns at 6 spf and 60°/120° phasing. Attempt to kick off well to tanks (with the estimated 200' psi overbalance, well' is not expected to flow without N2 displacement). N2 lift with coil as necessary to initiate and maintain flow. Rig up e-line to obtain downhole spinner, temperature and'pressure readings. Obtain production logs across perforated interval to .evaluate fluid contributions. Hang pressure gauge above perforated interval during well test' to.evaluate the well's productivity index. Obtain a well test, flowing the well to the MPI Iow flow test separator. The IOw flow separator is recommended in order to effectively meter the expected Iow quantities of dissolved gas. RIH with e-line to obtain downhOle pressur, iZed fluid sample. At.least One .sample should be obtained once flow has stabilized.:." ' . · .~ ........ Obtain surface liquid and gas samples for analysis.-:"". ..... :" ' "" .... " Shut well in and freeze protect to 1500' with. dead .crude, ensUring'that well remains overbalanced. ..... . . · . ,. .: .... . '.". ".;..:,..... ~,.,', .... '... ,......~..'., , . · ..... RECEIVED' DEC ~0 199~ Alaska Oil & Gas Cons. Commission Anchorage 1 , , , ! ' '~' I - , .. I .~1 hi-J- . II , k ,i ~L --I ~ I~II~ , ~ ~ "Jl~.j I' -I' t ~ '' · ~..~.. ..... .i · 1., ! i' M i ,, [ ~,,. D I:t I I--I_1 I~1 G WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. At'm: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs - 2-66/SD 12 AK-MF-930919 December 2, 1993 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: Paul Radzinski, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 One LDWG Formatted LIS Tape with Verification Listing. Date 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256- · Fax (907) 563-7252 A Baroid Company INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 11/18/1993 PAGE: 1 93-079 BD/GR 93-079 DGR/EWR4 93-079 DGR/EWR4(MD) 93-079 DIL/SFL/SP(PHSR) 93-079 DP/NP/DPR/GR 93-079 DP/NP/DPR/GR 93-079 DP/NP/GR 93-079 DP/NP/GR 93-079 DPR/GR 93-079 DPR/GR 93-079 EXLOG-FET.~ 93-079 EXLOG-FET~ ~~ 93-079 93-079 EXLOG-IFE-- 93-079 LDL/NL(RAW&PORO) 93-079 RFT 93-079 SBT/GR/CCL 93-079 SSTVD 93-079 407 93-079 DAILY WELL OP 93-079 FINAL WELL 93-079 FINAL WELL 93-079 5872 93-079 5873 5"MD,13896-15150 R1,2&5"TVD,9064-9805 R1,2&5",12286-13227 2&5",13473-15075 2&5"MD,13896-15150 2&5"TVD,13896-15150 2&5"MD,13896-15150 2&5"TVD,13896-15150 2&5"MD,13896-15150 2&5"TVD,13896-15150 2"MD,12420-12762 2"MD,12640-15203 2"TVD,9260-9529 2"TVD,9388-11504 2"TVD,9388-11504 2&5",2600-15048 5",13984-15084 5",13340-15148 2&5",13473-15075 COMP DATE: 10/02/93 7/25/93 TO 10/02/93 08/10-12/93 8/28-9/25/93 OH-DIT/2410-15123 RFT,14490-15121 INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 11/18/1993 PAGE: SUMMARY Are well tests required? Yes was well cored? Yes /~ If yes, was the core a is & description received? Yes Are dry ditch samples required? ~_~ No ~ ~-~~\~e~, COMMENTS: ., (" STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION C IvlMISSlON WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Wall Classification of Service Well OIL [] GAS [] SI,JSPENDED [] ABANDONED [] SERVICE BI Water Supply Well 2. Name of Operator~ ?. Permit Number BP Exploration ~j)., 93- 79 3. Address-~. ~{. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 . so- 029-22374 4. Location of well at surface """ ................. ~L 9. Unit or Lease Name 3151' "$L, 2360' WEL, SEC. 36, T12", FI16E '": ''! i~'i::;: ; ':'~; i--.~ ~toCA~l Duck Island Unit/Endicott At Top Producing Interval .. /, .OY '_ ~ j_ ___ , --..- I YL~FI'ED { 10. Well Number 1804' SNL, 3956' WEL, SEC. 2, T11N, R16E :~,'-:.'~ { ..,~.,~ :'.~ff.:~ 2-66/SD-12 _../~.g.-~,..._~..,~ .~'~"' ~~j,, I1. Field and Pool 2005'At TotalSNL,Depth4580, WEL, SEC. 2, T 11N, R16E ....... ' ..... ~'.~,~~ End/coif Field/Endicoff Pool 5. Elevation in feet (indicate KB, DF, etc.) p. Lease Designation and Serial No. KBE = 56' ! ADL 34636 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Suep. or Aband. 115. Water Depth, if offshore 116. No. of ComPletions 7/25/93 9/25/93 -lZ)TfTgE /d //~,-//~,ffi 6-12' MSL feet USE lOne 17. Total Depth (MD+TVD) t8. Plug Back Depth (MD+TVD] 19. Directional'Sut've'y {20. Depth where SSSV set F1. Thickness of Permafrost 15203' MD/11505' TVD 15179' MD/11484' TVD YES [] NC) []! None feet MD 11465'(Approx.) 22. Type Electric or Other Logs Run Run #1 RFT/GR Run ~2 DIUGR/CNL/LDT Run ~L3 DIL/GR/CNL/LDT 23. CASING, LINER AND CEMENTING FtECOI~ SE'rTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I'rOM HOLE SI2~ CEMB'V{IqG RECORD AMOUNT PULLED 20" Struct. Drive 37' 131' 30" Drive 13-3/8" 68# NT-80 42' 2871' 16" 550 sx "E"/400 sx Class "G" 9-5/8" 47# NT80/NT95 45' 13502' 12-1/4" 1280 sx Class "G" 7" 29# 13CR80 13195' 15200' 8-1/2" 770 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) None SIZE DEPTH SET (MD) PACKER SET (MD) None None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Not on production Date of Test Hours Tested PRODUCTION FOR OIL-BBL ~,S-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I iFIow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL 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. RECEIVED NOV 1 5 199,~ Alaska 0il & 6as Cons. Commission Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and 9ravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Base HRZ 12667' 9419' Top Kekiktuk 13920' 10362' Top Zone 3B 14226' 10652' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ,, I INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and 10g on all types of lands and leases in Alaska. " Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals 'for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". R E C E IV E D Form 10-407 HOV 1 5 199 ~,~s~ ULL & Gas Cons. Commission Anchorage MPI 2-66/SAG DELTA 12 After open hole logs determined the well to have non economic hydrocarbons, the decision was made to convert the well to a water supply well for the Duck Island unit. After running and cementing the 7" liner, the well was displaced to 9.9 ppg brine (Kill Weight Fluid). The well was freeze protected and the dg moved off. MPI 2-66/SD-12 will be completed as a water supply well after researching the completion type and obtaining co-owner approval. The well will be converted by March, 1994. RECEIVED NOV 1 5 199~ A~aska Oil & Gas Cons. Commission Anchorage BP/AAI SHARED SERVICE DAILY OPERATIONSi PAGE: 1 WELL: MPI 2-66/SD-12 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 07/24/93 06:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 07/25/93 (1) TD: 110' ( 110) 07/26/93 (2) TD: 1260'(1150) 07/27/93 ( 3) TD: 2880' (1620) 07/28/93 (4) TD: 2880' ( 0) REPLACING UTILITY LOOP IN TOPE MW: 8.6 VIS:340 (THIS TIME IS FROM RELEASE FROM WELLHEAD REPAIR ON 1-15 UNTIL RIG ACCEPT ON 07/24/93 (2-66). ACCEPT RIG ON LOCATION @ 0600 07/24/93. DELAYED MAINTENANCE TAKING PLACE THAT COULD NOT BE DONE WHILE OPERATIONG AT LAST WELL. REPLACED UNIONS ON CHOKE & KILL LINES (AAOGC INSISTENCE) & R/U DIVERTER, MIXED SPUD MUD, ETC. WHILE REPLACING UTILITY LOOP ON TOP DRIVE. ALSO REBUILDING AUGER COVER TO ROCK WASHER UNIT BEFORE SPUD. DOING ELECTRICAL HOOKUPS NOW ON UTILITY LOOP; ESTIMATE COMPLETION +3 HRS. DRILLING MW: 8.9 VIS:240 FINISH TOP DRIVE UTILITY LOOP REPLACEMENT. P/U BHA. FUNCTION TEST DIVERTER SYSTEM. PRE-SPUD MTG. SPUD WELL @ 1130 HRS; DRILLING TO 608. GYRO SURVEYS READING 180 DEGREE OUT OF PHASE W/MWD EVEN THOUGH MWD READINGS ARE INTERMITTENT DUE TO MAGNETIC INTERFERENCE. MWD SIGNAL FAILED DUE TO SOFTWARE PROBLEM. GYROED. DRILLING TO 894 W/HYRO SURVEYS UNTIL MWD SWITCHED TO TOOL FACE READING. DRILLING & SURVEYING TO 1260 W. MWD ONLY. RUNNING 13-3/8" CASING MW: 9.3 VIS: 94 DRILLING TO 1528 WITH GYRO SURVEYS. SHORT TRIP BACT TO 220'. DRILLING & SURVEYING TO 2880. CBU. SHORT TRIP TO HWDP CBU. POOH TO RUN CASING. R/U DOYONG TO RUN 13-3/8" CASING. TESTING BOP'S MW: 9.3 VIS: 54 RUN 13-3/8" CASING (72 JT'S). R/U CMT HEAD & CIRC VOLUME OF CASING WHILE RECIPROCATING 30' STROKES. TEST LINE TO 2500 PSI. PUMP 100 BBL'S WATER, 550 SX LEAD & 400 SX TAIL CMT. SWITCH TO RIG PUMPS & DISPLACED @ 10.5 BPM WHILE RECIPROCATING 30' STROKES. BUMPED PLUG & RELEASED PRESSURE, FLOATS HELD. CIP @0300 HRS. GOT ALL THE WATER SPACER BACK, + CMT-CONTAMINATED MUD WHEN PLUG BUMPED. R/D CMT HEAD, B/O LANDING JT & N/D DIVERTER SYSTEM. R/U BJ FOR TOP JOB & PUMPED ALL 250 SX. CMT WITHOUT GETTING CMT TO SURFACE. INSTALL CIW SPLIT SPEED HEAD. N/U BOP'S N/U NEW DRILLING SPOOL. TESTING BOP'S. RECEIVED NOV 1 ,,5 Alaska Oil & Gas Cons. Commission Anchorage WELL : MPI 2-66 OPERATION: RIG : DOYON 15 PAGE: 2 07/29/93 (5) TD: 3400' ( 520) 07/30/93 (6) TD: 3781'( 381) 07/31/93 ( 7) TD: 4750'( 969) 08/01/93 (8) TD: 6412'(1662) 08/02/93 (9) TD: 7616' (1204) 08/03/93 (10) TD: 8828'(1212) 08/04/93 (11) TD: 9700'( 872) 08/05/93 (12) TD:10239' ( 539) 08/06/93 (13) TD:ll100' ( 861) DRILLING MW: 9.2 VIS: 53 TEST BOP. P/U BHA 92, TEST MWD & RIH TO 2785. BREAK CIRC. TESTED CASING. DRILL SHOE TRACK & 10' NEW HOLE TO 2890 MD. CBU UNTIL MW IN/OUT. RUN LOT. DRILL, SLID & SURVEYED TO 3369. CIRC. POOH. RIH. DRILLING RIH MW: 9.3 VIS: 70 DRILLING TO 3514'. CBU. ROUND TRIP FOR BHA CHANGE; CHANGED OUT 24 DP. COULDN'T CIRC WHEN BACK ON BOTTON. TRIP TO UNPLUG BIT-FOUND MWD SCREEN. SLIDING & DRILLING W. AGGRESSIVE BUILD ASS'Y. CIRCULATE. POOH, BACKREAM TIGHT SPOT @ 3553-3545. ROUND TRIP FOR NEW BHA & BIT, PICKED UP STEERABLE ASS'Y TO RIH. DRILLING MW: 9.3 VIS: 70 RIH TO 3250. POOH. RIH. CUT DRILING LINE AFTER RIH TO 100' ABOVE SHOE. STRIHNG HAD PLUGGED OFF AGAIN WHILE WORKING. CLOSED ANNULAR & REVERSE CIRCULATED. RIH WASHING. DRILLING. CBU. SHORT TRIP TO SHOE. PULLED TIGHT 4222-3686. POOH. CIRC INSIDE SHOE TO CLEAN ANNULUS UNTIL SOLIDS CLEANED UP. SWIVEL PACKING BEGAN LEAKING DURING SHORT TRIP; REPLACED. RIH. WASH FROM 4134-4324. RIH TO BOTTOM. DRILLING. DRILLING MW: 9.6 VIS: 58 DRILLING & SLIDING TO 5935. CIRCULATE HOLE CLEAN. SHORT TRIP THROUGH NEW HOLE (5935-4985). DRILLING 6412. ROP. DRILLING @ 7616'MD MW: 9.6 VIS: 58 DRLG TO 6572'_ CIRC & COND HOLE FOR TRIP. TRIP OUT. CHANGE BHA. TRIP IN TO 1100'. TEST MWD. TRIP IN. DRLG & SURV TRIP OUT FOR BIT MW: 9.7 VIS: 60 DRLG TO 7845'. SHORT TRIP 7845' - 6500'. DRLG F / 7845' T / 8828'. CIRC & COND. TRIP OUT FOR BIT DRLG 12-1/4" @ 9700' MW: 9.7 VIS: 50 TRIP OUT. CHANGE BHA & ORIENT MOTOR. TRIP IN TO SHOE (P/U DRILL PIPE). TEST MWD. COND TRIP IN (REAM 90' TO BTM). DRLG F / 8828' T/ 9700'. DRLG. MW: 9.8 VIS: 48 DRLG TO 9623'. (STARTED SEEING SHALE STRINGERS @9620'). TRIP OUT, PULL WEAR RING. TEST BOPE, REINSTALL WEAR RING. P/U BHA & ORIENT MTR. TRIP IN TO SHOE. CUT DRLG LINE. SERVICE RIG. TEST MWD. TRIP IN (WASH LAST 85' TO BTM=NO FILL). DRLG TO 10239'. DRLG. MW: 9.8 VIS: 58 DRLG TO 10589'. SHORT TRIP TO 9565'. DRLG TO 11100'. RECEIVED NOV 1 5 199,t A~s~ u~t & Gas Cons. Commission Anchorage WELL : MPI 2-66 OPERATION: RIG : DOYON 15 PAGE: 3 08/07/93 (14) TD:l1590' ( 490) 08/08/93 (15) TD:11952'( 362) 08/09/93 (16) TD:12177' ( 225) 08/10/93 (17) TD:12515'( 338) DRLG TUFFS FORMATION MW: 9.9 VIS: 50 DRLG TO 11576'MD = TOP OF TUFFS FORMATION. CIRC 50BBL VIS SWEEP. REAM & BACK REAM F/11576 - 10227 TILL CLEAN. TRIP OUT. CHANGE BHA. TRIP IN TO 2700'. TEST MWD. TRIP IN WASH LAST 106' TO BTM. DRILG TUFFS FORMATION TO 11590'MD. TRIP OUT FOR BIT MW:10.3 VIS: 54 DRLG TUFFS TO 11952'MD (POH BIT HIGH TORQUE). TRIP OUT FOR BIT & BHA. TOP OF TUFFS FORMATION=l1656'MD RIH. MW:10.4 VIS: 64 BACKREAM TO 11384'. RIH. DRLG TO 12117'. CBU. POOH. CHANGE BHA. RIH. DRLG. DRLG TO 12515'. MW:10.4 VIS: 73 08/11/93 (18) TD:12762' ( 247) 08/12/93 (19) TD:12762' ( 0) 08/13/93 (20) TD:12762' ( 0) 08/14/93 (21) TD:12762' ( 0) 08/15/93 (22) TD:12762' ( 0) 08/16/93 (23) TD:12762' ( 0) POOH. MW:10.3 VIS: 53 SHORT TRIP TO 11656'. DRLG F/ 12515'-12666'. CBU. DRLG TO 12762'. DROP IN PRESSURE. CIRC. POOH WET. POOH. MW:10.3 'VIS: 56 POOH. BHA PARTED TOP OF STAB BELOW JARS. TETST BOPE. RIH W/ FTA #1. REAM F/ 12503'-12564'. CIRC. REAM TO 12574'. POOH. POOH. MW:10.3 VIS: 68 POOH. L/D FTA #1. RIH W/ FTA ~2. WASH DN TO FISH @ 12583'. POOH WET. NO FISH. RIH W/ GRAPPLE, SPEAR. WASH DN TO FISH. JAR. POOH. TRIP OUT F/ O S GRAPPLE MW:10.4 VIS: 56 TRIP OUT. L/D SPEAR ASSY, P/U MILL SHOE ASSY. TRIP IN TO 2645'. CUT DRILL LINE. TRIP IN. MILL FISHING NECK ON TOP STAB FISH. CIRC & COND HOLE FLUID. TRIP OUT L/D SHOE & TOP SUB, P/U OVERSHOT BOWL BHA. TRIP IN. WORK OVER TOP OF FISH. TRIP OUT FOR FISHING GRAPPLE. TRIP OUT MW:10.4 VIS: 55 TRIP OUT FOR OVERSHOT GRAPPLE. TRIP IN TO 2645'. CUT DRILL LINE. TRIP IN TO 12583'. UNABLE TO LATCH ONTO FISH W/ OVERSHOT. CIRC & COND HOLE FOR SIDETRACK JOB. TRIP OUT & L/D DC'S & FISHING TOOLS. TRIP IN W/ OPEN ENDED DRILL PIPE. TRIP OUT. TRIP OUT F/ BHA MW:10.3 VIS: 49 TRIP OUT & L/D CMT TOOLS. TEST BOPE. CUT DRILL LINE. W.O.C., SERVICE RIG & TOP DRIVE. P/U BHA. TRIP IN TO 2871'. TEST MWD. TRIP IN TO 11100' WASH DOWN TO 11343'. CIRC & COND. TEST NEW MWD. TRIP OU~ FOR SIDE TRACK BHA. RECEIVED NOV 1 5 A~aska Oil & Gas Cons. Commissm~ Anchorage WELL : MPI 2-66 OPERATION: RIG : DOYON 15 ("' PAGE: 4 08/17/93 (24) TD:12762' ( 0) 08/18/93 (25) TD:l1391' ( 0) 08/19/93 (26) TD:lll00' ( 0) 08/20/93 ( 27) TD:11259' ( 159) 08/21/93 (28) TD:11187' ( 0) KICKING OFF MW:10.3 VIS: 56 POOH. P/U MUD MOTOR, CHANGE MWD, MOVE STAB, ORIENT. SERVICE RIG, RUN IN HOLE TO 2871. TEST MWD TOOL. RIH TO 11343. DRILLING & SURVEY FROM 11343 TO l1345.LOST POWER TO RIG, BLOWN BREAKER IN SCR ROOM. REPAIR & INSPECT SCR. REORIENT MWD, RESUME DRILLING FROM 11345. TIMED DRILLING 3 MNUTES/INCH. DRILLED FROM 11345 TO 11353, STACKED 80000# WOB, PICKED UP DRILL STRING, SLACKED OFF TO l1358(WITHOUT PUMPS RUNNING). RESUMED TIMED DRILLING. KICKING OFF MW:10.3 VIS: 60 ATTEMPTING TO KICK OFF, TIMED DRILLING FROM 11361 TO 11391. CEMENT CUTTINGS OF SOFT QUALITY. UNLESS MARKED INCREASE IN CUTTINGS RIG TEAM IS READY TO SET ANOTHER CEMENT PLUB. W.O.C. MW:10.3 VIS: 56 DRLD/SLIDE CEMENT PLUB FROM 10391 TO 11400. NO CHANGE IN SHALE FORMATION. DISCONTINUED ATTEMPT ON SIDETRACK #1. DRILLED & ROTATED FROM 11400 TO 11450. CIRC. POOH. PU 3 1/2" MULE SHOE, RIH. CUT DRILLING LINE. RIN TO 11450, TAG BOTTOM. CIRC. BATCH MIX 400 SC CL G CEMENT. CIRC HOLE WHILE BATCH MIXING. TEST LINES TO 3500 PSI, PUMP 40 BBLS, PUMP 4 BBLS BEHIND CEMENT. POOH 10 STDS. CIRC. POOH. BEGIN SIDETRACK. MW:10.4 VIS: 64 POOH.L/D CMT TOOLS. WOC. RIH W/ BHA. CIRC. TAG CMT @ 11144'. DRLG CMT F/ 11144'-11149' CBU. POOH. RIH W/ BIT, MTR. BEGIN SIDETRACK F/ 1114~' 6' -1115 . DRLG TO 11259'. KICKING OFF KICKING OFF FROM 11152 TO 11187 MW:10.4 VIS: 55 08/22/93 (29) TD:ll300' ( 113) DRILLING SIDETRACK DRIL FROM 11187 TO 11300. MW:10.4 VIS: 55 08/23/93 (30) TD:11442' ( 142) 08/24/93 (31) TD:l1580' ( 138) 08/25/93 (32) TD:11777' ( 197) RUNNING IN HOLE MW:10.4 VIS: 66 DRILLING FROM 11300 TO 11442. CBU. POOH. LAY DOWN BHA. TEST BOPE. P/U BHA. R.I.H. DRILLING MW:10.4 VIS: 54 RIH TO 2871. SERVICE RIG, TEST MWD. RIN TO 11442. DRILLING. TRIP FOR BIT MW:10.3 VIS: 59 DRILLED FROM 11580 TO 11777'. CIRCULATE IN PREPARATION FOR TRIP. RECEIVED NOV 1 5 Alaska. IJli & Gas Cons. Commission Anchorage WELL : MPI 2-66 OPERATION: RIG : DOYON 15 PAGE: 5 08/26/93 (33) TD:11943' ( 166) 08/27/93 (34) TD:12262' ( 319) 08/28/93 (35) TD:12416' ( 154) 08/29/93 (36) TD:12666'( 250) DRLG. MW:10.3 VIS: 57 CBU. POOH. CHANGE MWD, BIT. RIH. WASH BTM 110'. DRLG F/ 11777'-11943'. DRILLING @ 12262' MW:10.3 VIS: 56 DRILLED FROM 11943-12118'. MADE STAND SHORT TRIP CIRCULATE PRIOR TO SHORT TRIP. SHORT TRIP F/12118-110701' WASHED THRU TIGHT SPOTS @ 11808' & 11561'. DRILLED F/12118-12262'. DRILLING AT 12416' MW:10.4 VIS: 62 DRILLED TO 12411'. CIRC BTMS UP FOR TRIP. TRIP FOR BHA CHANGE. REPAIRED BROKEDN BOLT IN TOP DIRVE. CHANGE BHA. RIH. DRLG TO 12416'. POOH. DRLG F/ 12564'-12666'. CBU. POOH. MW:10.4 VIS: 59 08/30/93 (37) TD:12735' ( 69) 08/31/93 (38) TD:12891' ( 156) 09/01/93 (39) TD:12923' ( 32) 09/02/93 (40) TD:13018' ( 95) 09/03/93 (41) TD:13040' ( 22) 09/04/93 (42) TD:13063'( 23) 09/05/93 (43) TD:13138' ( 75) DRLG. MW:10.3 VIS: 58 POOH. CHANGE BHA. RIH. REAM F/ 11886'-12665'. CIRC. DRLG F/ 12666'-12735'. POOH. MW:10.3 VIS: 50 DRLG F/ 12735'-12859'. SHORT TRIP 10 STDS. DRLG F/ 12859'-12891'. CIRC. POOH. DRLG 12-1/4" MW:10.4 VIS: 52 TRIP OUT (BACKREAM TH). TEST BOPE. M/U BHA. TRIP IN TO 2000'. TEST MWD. TRIP IN TO 12820. WASH TO BTM. DRLG TO 12923' MD. CIRC.XANVIS SWEEP MW:10.3 VIS: 55 DRLG TO 12955' SHORT TRIP TO 10470. DRLG TO 13018'. CIRC HI VIS SWEEP. DRLG 12-1/4" HOLE MW:10.4 VIS: 48 CIRC. TRIP OUT. RIG REPAIR. P/U BHA (N/D BIT & TURBO MTR). TRIP IN TO SHOE. CUT DRLG LINE. TEST MWD & MT. TRIP IN TO 12935. WASH 83' TO BTM. WASH & BREAK IN BIT. DRILG TO 13040'. DRLG 12-1/4" MW:10.3 VIS: 47 DRLG TO 13036 TRIP OUT (TH PUMP & BACK REAM OUT). L/D BHA #19. TRIP IN W/BHA#20 TO 2600'. TEST MWD. TRIP IN TO 12982'. WASH 54' TO BTM @ 13036'. DRLG TO 13063'. DRLG 12-1/4" HOLE MW:10.4 VIS: 50 DRLG TO 13080'. SHORT TRIP TO 10351'. DRLG TO 13138 R F.. CF. IV F-.D NOV 1 5 ~99~ u~i & Gas Cons. Commission Anchorage WELL : MPI 2-66 OPERATION: RIG : DOYON 15 PAGE: 6 09/06/93 (44) TD:13224' ( 86) DRLG 12-1/4" MW:10.3 VIS: 54 DRLG TO 13161'. SHORT TRIP TO 12305'. DRLG TO 13224. 09/07/93 (45) TD:13225' ( 1) 09/08/93 (46) TD:13263' ( 38) 09/09/93 (47) TD:13297' ( 34) 09/10/93 (48) TD:13398' ( 101) 09/11/93 (49) TD:13516' ( 118) TRIP OUT W/ LWD MW:10.3 VIS: 56 DRLG F/13224' T/13225' (PREP TO PULL FOR BIT & SPERRY SUN LWD) DROP SURVEY. TRIP OUT (L/D MWD, P/U LWD & R/R #16 BIT). TEST LWD AT SURFACE. TRIP IN TO 2750'. CUT DRILL LINE. TRIP IN W/LWD. MAD LOG FROM 12287' TO 13225' MD. CIRC HI VIS SWEEP. TRIP OUT. DRLG 12-1/4" MW:10.4 VIS: 49 TRIP OUT, UNLOAD DATA FROM LWD TOOL. TEST BOPE. P/U BHA TRIP IN TO 1500'. TRIP TO 13200' WASH LAST 25' TO BTM, BREAK IN BIT. DRLG TO 13263'. DRLG. MW:10.4 VIS: 48 DRLG TO 13270'. SHORT TRIP TO 12319' DRLG TO 13277'. POOH. CHANGE BIT. RIH. WASH TO BTMi DRLG F/ 13277'-13297'. DRILLING 12-1/4" MW:10.4 VIS: 54 DRLG F/13297' T/13398. SHORT TRIP TO 10629' (PULLED ROUGH TO 11362' TAKING 55K OVER STRING). DRILG TO 13398' DRLG 12-1/4" MW:10.4 VIS: 56 DRLG TO 13469' SHORT TRIP TO 12550'. DRLG TO 13516'. 09/12/93 (50) TD:13522' ( 6) 09/13/93 (51) TD:13522' ( 0) 09/14/93 (52) TD:13635' ( 113) 09/15/93 (53) TD:13698'( 63) 09/16/93 (54) TD:13936' ( 238) RUN 9-5/8" CSG MW:10.4 VIS: 54 DRLG TO 13522'. SHORT TRIP. CIRC. TRIP OUT. TEST RAM. RUN 9-5/8" CASING. P/U 8-1/2" BHA MW:10.2 VIS: 52 RUN CSG 9-5/8". CIRC. PUMP 20 BBLS PREFLUSH, 50 BBL SPACER 507 BBLS LEAD CMT, 81 BBLS TAIL CMT. DISPLACE W/991 BBLS MUD, BUMP PLUG. INSTALL PACKOFF & TEST BOPE. M/U 8-1/2" BHA & TRIP IN. DRLG. MW: 9.5 VIS: 58 RIH. TEST CSG. OK. DRLG FC, CMT. CIRC. DRLG CMT, FS, 10' NEW HOLE. FIT (10 PPG EMW). DRLG TO 13635'. DRILLING MW: 9.5 VIS: 60 DRILLING TO 13695'. DROP SINGLE-SHOT SURVEY (NO AZIMUTH). ROUND TRIP FOR BIT CHANGE. DRILLING TO 13698'. POOH MW: 9.5 VIS: 49 DRILLING 13698-13936'. CBU. DROP SINGLE-SHOT SURVEY. POOH FOR BIT & BHA CHANGE. RECEIVED NOV 1 5 1993 Ai;~ska Oil & Gas ConsI Commission Anchorage WELL : MPI 2-66 OPERATION: RIG : DOYON 15 PAGE: 7 09/17/93 (55) TD:14100' ( 164) 09/18/93 (56) TD:14295' ( 195) 09/19/93 (57) TD:14331' ( 36) 09/20/93 (58) TD:14455' ( 124) 09/21/93 (59) TD:14595' ( 140) 09/22/93 (60) TD:14940'( 345) 09/23/93 (61) TD:14940' ( 0) 09/24/93 (62) TD:15045' ( 105) 09/25/93 (63) TD:15203' ( 158) 09/26/93 (64) TD:15203' ( 0) DRILLING MW: 9.4 VIS: 48 ROUND TRIP TO PICK UP TRIPLE COMBO LOGGING ASS'Y (INTEQ). NO HOLE PROBLEMS DURING TRIP. DRILLING. DRLG. MW: 9.4 VIS: 51 DRLG F/ 14100'-14118'. SHORT TRIP TO SHOE. DRLG F/ 14118'-14295'. POOH. MW: 9.4 VIS: 55 DRLG F/ 14295'-14331'. CBU. POOH. SURVEY DOWN . MAD RUN F/ 13950'-14331'. CBU. POOH. DRILLING MW: 9.5 VIS: 50 POOM. CHANGE BIT, BMA. RIH, REAMING TO BOTTOM. DRILLING 14331'-14455'. DRLG. MW: 9.5 VIS: 52 DRLG F/ 14455'-14549' CIRC. POOH FOR WASHOUT. FOUND 18-2/3 STDS OUT. REPLACE. RIM. DRLG F/ 14549'-14585'. CIRC. DRLG F/ 14585'-14595'. POOH MW: 9.6 VIS: 53 DRILLING 14595'-14778' POOH. R/U. RIH. DRILLING 14778'-14940'. POOH, MWD CHECK, BOP TESTS & NRS INSTALLATION. CIRC. DROP SINGLE-SHOT SURVEY. POOH SLM. RIH. MW: 9.6 VIS: 64 POOM. REPAIR MWD. TEST BOPE. P/U BHA, BIT. RIH. DRLG. MW: 9.6 VIS: 59 RIH. TEST BOPE. RIM TO 14550'. MAD LOG RUN F/ 14550'-14940'. DRLG F/ 14940'-15045'. CIRC. MW: 9.7 VIS: 57 DRLG F/ 15045'-15128'. P[OOM 42 STDS FOR WASHOUT. DRLG F/ 15128'-15203'. TD WELL @ 00:30 HRS, 9/25/93. CIRC. SHORT TRIP TO 13496'. CIRC. POOH. MW: 9.8 VIS: 59 CBU. POOH TIGHT. WASH & REAM TIGHT SPOTS. CIRC. POOH. 09/27/93 (65) TD:15203' ( 0) RIH. MW: 9.8 VIS: 78 POOH. R/U SWS. RUN RFT/GR. LOG RUN: DIL/GR/CNL/LDT. R/D SWS. RIH. NOV ~ 5 ~99'$ 0ii & Gas Cons. Commission Anchorage WELL : MPI 2-66 OPERATION: RIG : DOYON 15 PAGE: 8 09/28/93 (66) TD:15203 PB: 0 09/29/93 (67) TD: 15203 PB: 0 09/30/93 (68) TD:15203 PB: 0 10/01/93 (69) TD:15203 PB:15179 10/02/93 (70) TD:15203 PB:15179 POOH. MW: 9.7 WBM RIH TO 13357'. DROP HOWCO TEMP PROBE. CIRC. RIH TO 15083'. REAM TO BTM. CBU. SHORT TRIP TO CSG SHOE. CIRC. RIH. CIRC. POOH. CIRC. MW: 9.8 WBM POOH. L/D BHA. RIH W/ 7" 13CR LNR ON DP. CIRC. RIH W/ LNR. CIRC @ SHOE. RIH W/ LNR TO BTM. CIRC. RIH. MW: 9.8 WBM CIRC. R/U HOWCO. PUMP SUPERFLUSH, 158 BBLS (770 SX) 15.8 PPG CMT. DISP W/ MUD. BUMP PLUG W/ 3500 PSI. RELEASE F/ HGR. POOH 10 STDS. CIRC. POOH. RIH W/ BIT, CSG SCRAPER. CLEAN OUT CMT TO TOL @ 13199'. TEST CSG, LNR LAP. CBU. POOH. RIH W/ BIT. POOH. MW: 9.9 NaCl RIH. CLEAN OUT CMT F/ 13498'-13593'. RIH. DRLG CMT F/ 15055'-15179'. TEST LNR. DISP WELL TO BRINE. TEST LNR. OK. REV CIRC. POOH, L/D DP. RIG RELEASED. MW: 9.9 NaCl POOH. DISP 105 BBLS DIESEL F/P TO 1500' POOH. INSTALL TBG HGR. N/D BOPE. N/U TREE. TEST TRE~. SECURE WELL. RIG RELEASED @ 20:30 HRS, 10/1/93. MOVE. SIGNATURE: (drilling superintendent) DATE: RECEIVED NOV 1 5 199 A~ska (Jit& Gas Cons. Commission Anchorage FINAL WELL REPORT PRUDHOE BAY DRILLING GROUP ENDICOTT SAG DELTA #12 MPI 2-66/SD-Z.9. (SIDETRACK) NORTH SLOPE, ALASKA 28 AUGUST 1993 TO 25 SEPTEMBER 1993 THE INFORMATION, INTERPRETATIONS, RECOMMENDATIONS, OR OPINIONS CONTAINED HEREIN ARE ADVISORY ONLY AND MAY BE REJECTED. CONSULTANT DOES NOT WARRANT THEIR ACCURACY OR CORRECTNESS. NOTHING CONTAINED HEREIN SHALL BE DEEMED TO BE INCONSISTENT WITH, NOR EXPAND, MODIFY OR ALTER CONSULTANT*S OBLIGATION OF PERFORMANCE AS PROVIDED FOR IN A WRITTEN AGREEMENT BETWEEN THE PARTIES, OR IF NONE, IN CONSULTANT*S MOST RECENT PRICE LIST. BAKER HUGHES INTEQ COMPILED BY: SAM HEWITT TERRY WOLFORD APPROVED BY: JOHN MORRIS r41CROFILI ED INTRODUCTION THE MPI 2-66/SD-12 WELL IS AN EXPLORATION WELL DRILLED ON THE ENDICOTT PAD, APPROXIMATELY 17.5 MILES NORTH EAST OF PRUDHOE BAY, ALASKA. COORDINATES FOR THE SURFACE LOCATION OF THE WELL ARE: 3151' FSL & 2360' FEL, IN SECTION 36, T12N, R16E UMIAT MERIDIAN. PROPOSED BOTTOM HOLE COORDINATES WERE: 2780' FSL & 4924' FEL, IN SECTION 2, T11N, R16E UM. TARGET COORDINATES WERE 3204' FSL & 4338' FEL, IN SECTION 2, T11N, R16E UM WITH A FINAL AZIMUTH OF ABOUT 234 DEGREES AND A FINAL DEPARTURE OF 9664'. TOTAL PROPOSED DEPTH WAS 15539' MD (11571' TVD). TOTAL DEPTH WAS 15203'MD (11504' TYD). THE MAIN OBJECTIVE OF THIS WELL WAS TO EVALUATE AND, IF PRODUCTIVE, PRODUCE THE KEKIKTUK FORMATION ON THE DOWN-THROWN SIDE OF THE MIKKELSEN BAY FAULT. THE PROPOSED TARGET WAS TO BE REACHED THROUGH THE USE OF DIRECTIONAL DRILLING TOOLS AND TECHNIQUES TO DRILL A DEVIATED HOLE TO REACH THE PROPOSED TARGET. THE KICK OFF WAS TO 'START AT 500'MD AND BUILD ANGLE AT RATES OF I - 2 DEGREES PER 100' UNTIL AN AVERAGE HOLE ANGLE OF ABOUT 46.35 DEGREES, FROM TRUE VERTICAL, WAS OBTAINED BY ABOUT 3568' MD (3308' TVD). THE HOLE ANGLE WAS TO BE HELD TO FINAL WELL TD. IT WAS DESIRED TO DRILL 12-1/4" HOLE AND SET 9-5/8" CASING SHOE AT THE TOP OF THE KAYAK, AND THEN SET 7" LINER AFTER DRILLING 8-1/2" HOLE TO FINAL WELL TD. THE DRILLING ASSEMBLY TWISTED OFF AT THE NEAR MONEL STABILIZER WHILE DRILLING IN THE ORIGINAL HOLE AT 12762' MD (9529' TVD). AFTER PLUGGING BACK TO 11300' MD THE WELL WAS REDRILLED TO A TOTAL DEPTH 15203'MD (11504'TVD) IN THE LOWER KEKIKTUK FORMATION. BAKER HUGHES INTEQ MUDLOGGED THE SIDETRACKED HOLE FROM 12640' MD TO TOTAL DEPTH AT 15203' MD. --1-- SUMMARY OF PERTINENT DATA WELL NAME: ENDICOTT MPI 2-66/SD-12 API NUMBER: 50-029-22374 OPERATOR: BP EXPLORATION PARTNERS: CONTRACTOR: LOCATION: CASING: DATE SPUDDED: DATE TOTAL DEPTH REACHED: EXXON, UNOCAL, A~OCO, CIRI NANA, DOYON, ARCO ALASKA DOYON RIG #15, LAND 3151' FSL, 2360' FEL SEC 36, T12N, R16E UMIAT MERIDIAN 13 3/8" AT 2870' RKB 9 5/8" AT 13496' RKB 25 JULY 1993 25 SEPTEMBER 1993 FINAL TOTAL DEPTH: CONVENTIONAL CORES: 15203' MD, 11504' TVD NONE FORMATION TESTS: NONE HYDROCARBON SHOWS: SEE SHOW REPORTS - APPENDEX II COMPANY GEOLOGISTS: CONNIE ZARNDT - BP EXPLORATION B.H. INTEQ GEOLOGISTS: FINAL WELL STATUS: SAM HEWITT, TERRY WOLFORD 'SUSPENDED -2- METHODS GEOLOGIC AND DRILLING DATA WAS COLLECTED AT THE WELLSITE USING EXLOG'S DRILL MONITOR SYSTEM (DI~L~). THE SYSTEM IS A COMPUTER BASED ~ DATA COLLECTION UNIT, USED IN ACQUISITION, COMPILATION AND OUTPUT OF DATA. ADDITIONAL LITHOLOGIC AND HYDROCARBON EVALUATION WAS PROVIDED BY EXLOG'S ONSITE GEOLOGISTS. METHODS OF ANALYSIS USED FOR EVALUATION ARE PRESENTED IN EXLOG'S MANUAL "MUDLOGGING: PRINCIPLES AND INTERPRETATIONS'* (MS-196). MUDLOG THE LOG FORMATS WERE STANDARD MEASURED DEPTH AND TRUE VERTICAL DEPTH LOGS. IN ADDITION, AN INTERGRATED TVD - M~D LOG WAS PROVIDE OVER THE INTERVAL GAMMA RAY AND RESISTIVITY DATA WERE COLLECTED BY TELECO, A BAKER HUGHES COMPANY. DATA DISPLAYED ON THE LOG INCLUDES: LITHOLOGY, RATE OF PENETRATION, TOTAL GAS, CUTTINGS GAS, CHROMATOGRAPH DATA, AND SHOW QUALITY WlEN PRESENT. TOTAL GAS, RATE OF PENETRATION, AND CUTTINGS GAS ARE PLOTTED LINEARLY, WHILE ALL OTHER PARAMETERS ARE PLOTTED LOGARITH- MICALLY. LOGS WERE PLOTTED AS 2 INCHES PER 100 FEET (1:600). AUTOCALCXMETER ANALYSIS OF Z CALCITE VERSUS DOLOMITE WAS DISPLAYED ON THE FAR LEFT OF THE MEASURED AND TRUE VERTICAL DEPTH LOGS. DRILL DATA DRILLING DATA MONITORED INCLUDED: RATE OF PENETRATION (ROP) USING THE BLOCK HEIGHT SYSTEM, HOOKLOAD, WEIGHT ON BIT, AND PUMP STROKES. H2S WAS ALSO MONITORED THROUGH THE GAS STREAM FROM THE SHAKERS ON A CONTINUAL BASIS. SAMPLING SAMPLES WERE COLLECTED AT 10 FOOT INTERVALS FROM 12640* TO FINAL WELL TD AT 152203'. TWO WET SAMPLES AND THREE DRY.SAMPLES WERE COLLECTED. IN ADDITION, SAMPLEX TRAY SAMPLES (10 FOOT INTERVALS) WERE PROVIDE FROM 13200' TO TOTAL DEPTH. SAMPLES WERE STORED WITH THE BP GEOLOGICAL REPREGENTITIVE ON LOCATION AND SHIPPED TO BP*S SAMPLE FACILITY IN ANCHORAGE AT THE COMPLETION OF DRILLING ON 9/25/93. A COMPLETE LISTING OF SAMPLES COLLECTED AND SHIPPED CAN BE FOUND IN THE APPENDIX OF THIS REPORT. -3- FORMATION EVALUATION LOGGING OF THE SIDETRACKED HOLE BEGAN AT 23:11HOURS~ AUGUST 28~ AT 12640 FEET MD (9432 FEET TVD) IN THE LATE CRETACEOUS HRZ FORMATION. ALL DEPTHS, UNLESS OTHERWISE SPECIFIED~ ARE REFERENCED FROM THE ROTARY TABLEt AT 56 FEET ABOVE SEA LEVEL. ALL FORI~TION TOPS LISTED BELOW ARE I~fADE FROM DITCH CUTTINGS, THUS ARE APPROXIMATE, AND DO NOT NECESSARILY REPRESENT THE OPERATORS PICKS. HRZ SHALE LITHOLOGY BAKER HUGHES INTEQ BEGAN LOGGING THE SIDETRACKED HOLE AT 12640~ IN THE LOWER CRETACEOUS HRZ SHALE UNIT. LITHOLOGY WAS VERY DARK GRAY TO BLACK CARBONACEOUS AND MICACEOUS SHALES. THE SHALES WERE FISSEL TO FLAKEY, AND PLATEY. COLSON TO ABUNDANT, LIGHT GRAY TO GRAY WHITE, SUB PLATEY TO SPLINTERY, TUFFS OCCURED IN THE CUTTINGS AND APPEARED'TO BE SLOUGH I~OM UP HOLE. OCCABONAL TO COLSON MEDIUlq BROWN AND CREAI~ WHITE INOCF.~AI~S I~AGMENTS OCCURED THROUGHOUT THE INTERVAL. OCCASIONAL TO COI~OM PYRITE AND TRACES OF CHERT WERE NOTED. OCCASIONAL RED BROWN, HARD SIDERITE WAS NOTED. FINE TO VERY COARSE, CLEAR TO FROSTED, ROUNDED QUARTZ GRAINS BECAME COlOrON NEAR THE BASE OF THE UNIT. BASE OF THE HRZ WAS APPROXlRATELY 12689' MD (9471' TVD) AT THE LOWER CRETACEOUS UNCONFOI~J4ITY (LCU). DRILL RATE AND GAS DATA THE RATE OF PENETRATION THROUGH THE HRZ RANGED FROM 12 TO 18 FEET PER HOUR. THE AVERAGE RATE OF PENETRATION WAS 16 FEET PER HOUR. DITCH GAS RANGED FROM A LOW OF 16 TO A HIGH OF 34 UNITS WITH AN OVERALL AVERAGE OF 20 UNITS BACKGROUND PORI~TION GAS. CHROMATOGRAPH ANALYSIS OF THE GAS DETECTED Cl (I~fETHANE) THROUGH C5 (PENETHANE) AS FOLLOWS: C1 (METHANE) 1796 - 4830 PPM; C2 (ETHANE) 165 - 448 PI~; C3 (PROPANE) 99 - 208 PI~; C4 (ISO AND NOP~L BUTANE) 62 -92 PI~; C5(ISO AND NORMAL PENETHANE) 0'- 55 Pl~. THE C5'S OCCURED JUST ABOVE THE LCU BOUNDRY. OIL AND GAS SHOWS THE HRZ WAS CHARA~ERIZED BY A PERSISTENT WEAK LIGHT BLUE SOLVENT CUT FLUORESCENCE WITH LOCAL WEAK STRAW TO LIGHT BROWN VISIBLE CUTS AND LOCAL /4EDIUM BROWN RESIDUAL STAIN. THE PERSISTENT CUTS APPEARED DUE TO THE HIGH CARBONACEOUS CONTENT OF THE SHALE AND THE SOURCE BED CHARACTERISTICS OF THE HRZ. -4-- LISBUENE GROUP LITHOLOGY THE LISBURNE GROUP, OF PENNSYLVANIAN AGE, WAS ENCOUNTERED AT 12689' MD (9471' TVD) BELOW THE LO#ER CRETACEOUS UNCONFORMITY (LCU). IT WAS CHARACTERIZED BY A DRAMATIC INCREASE IN PENETRATION RATE AND A SHARP INCREASE IN BACKGROUND GAS FROM THE OVERLYING HRZ. THE LITHOLOGY CHANGE WAS MASKED IN THE DITCH SAMPLES BY ABUNDANT SLOUGH WITH LIMESTONE NOTED IN THE 12730' MI) SAMPLE. LIMESTONE BECAME DOMINATE IN THE SAMPLES BY 12760'MD. THE LIMESTOME WAS BUFF, MOTTLED GREY TO CREAM, AND OCCASIONALLY CHALKY WHITE IN COLOR. IT RANGED FROM WACKSTONE TO GRAINSTONE WITH COMMON GHOSTS OF BROKEN GRAINS AND FRAGMENTS VISABLE. OCCASIONAL LIGHT BROWN SUCROSSIC DOLOMITE OCCURED AS INTERBEDS AND THE LIMESTONE OCCASIONAL GRADED TO A DOLOMITIC LIMESTONE. THE LIMESTONE WAS LOCALLY CHERTY, RANGED FROM FIRM AND CHALKY TO MODERATELY HARD AND DENSE IN PART. IT WAS GENERALLY CLEAN AND ONLY LOCALLY SLIGHTLY ARGILLACEOUS, OCCASIONALLY GRADING TO A CALCAREOUS SILTSTONE. A SLIGHT CARBONACEOUS PARTING APPEARANCE WAS PRESENT LOCALLY IN THE SAMPLES. AUTOCALCIMETER ANALYSIS WAS USED TO DETERMINE PERCENTAGE CALCITE VERUS DOLOMITE AND DISPLAYED ON THE LOG FROM 12730* TO 13400* MI). ZONES OF HIGHEST PERCENTAGES OF DOLOMITE WERE FROM 12790*- 12800'MD (50 12990* - 13020' MD (55 - 69Z). IT WOULD APPEAR THAT THE MAJORITY OF THE DOLOMITIC ZONE IN THE LISBURNE WAS REMOVED BY THE LCU UNCONFORMITY IN THIS WELL. BASE OF THE LISBURNE FORMATION WAS MARKED BY THE FIRST APPEARANCE OF BRICK RED BROWN SHALES OF THE ITKILYARIAK FORMATION AT 13310* MD (9927'TVD). DRILL RATE AND GAS DATA THE'PENETRATION RATE INCREASED FROM AN AVERAGE OF 9 FEET PER HOUR IN THE OVERLYING HRZ TO 30 -64 FEET PER HOUR FROM 12689* - 12700' AT THE TOP OF THE LISBURNE. AGAIN FROM 12780 ' TO 12800* MD DRILL RATE RANGED FROM 22 - 60 FEET PER HOUR. THE REST OF THE LISBURNE DRILLED FROM 2 - 10 FEET PER HOUR, AVERAGING 4 FEET PER HOUR. THE UNUSUALLY SLOW DRILL RATE CAN BE ATTRIBUTED TO OPEN HOLE DRAG ON THE DRILL STRING (13 3/8" CSG AT 2870*). BACKGROUND GAS INCREASED FROM 16 UNITS AT 12888' MD TO A MAXIMUM OF 701 UNITS AT THE LCU UNCONFORMITY. DITCH GAS RANGED FROM 83 TO 202 UNITS FROM 12775* - 12812' MD. AVERAGE DITCH FROM 12812' - 12900* MD WAS 20 UNITS, AND FROM 12900' - TO 13310* MD AVERAGED 5 UNITS. MUD WEIGHT WAS 10.3 PPG THROUGHOUT THE INTERVAL. -5- ALL COMPONENTS OF THE PARAFFIN SERIES, Cl - C5, WERE PRESENT AT THE TOP OF THE LISBURNE IN THE INTERVAL 12685 TO 12710*. MAXIMUM VALUES WERE AS FOLLOWS: Cl, 115,000 PPM; C2, 5245 PPM, C3, 2249 PPM, ISO AND NORMAL C4, 985 PPM; ISO AND NORMAL C5 449 PPM. IN THE ZONE 12775* -~12812' Cl THROUGH C40CCURED AS FOLLOWS: Cl, 28901PPM, C2 2294 PPM, C3 1093, ISO AND NORMAL C4 377 PPM, ISO AND NORMAL C5, O PPM. Cl THROUGH C3 WERE PRESENT THROUGHOUT THE LISBUNE, WITH OCCASIONAL NORMAL C40CCURING IN BOTTOMS UP ON TRIPS OR SHORT TRIPS. OIL AND GAS SHOWS THE HIGH GAS VALUES NOTED ABOVE, AT THE TOP OF THE LISBURNE, WERE ACCOMPANIED BY WEAK AND SLOW LIGHT BLUE STREAMING SOLVENT CUT FLUORESCENCE AND LOCAL FAINT STRAW VISIBLE CUTS WITH LIGHT TO MEDIUM BROWN RESIDUAL STAINING. MEDIUM TO DARK BROWN STAINING WAS SCATTERED THROUGHOUT, WITH TRACES OF TARRY RESIDUAL OIL IN THE DOLOMITES AT 12775* TO 12812* MD. TRACES OF RESIDUAL OIL STAINING OCCURED TO 12900' MD, WITH OCCATIONAL WEAK CUT FLUORESCENCE TO THE BASE OF THE LISBURNE. THE TWO ZONES OF SHOWS ARE DETAILED ON THE 8HOW REPORTS IN THE APPENDIX OF THE REPORT. ITKILYARIAK FORMATION LITHOLOGY THE TOP OF THE ITKILYARIAK FORMATION AT 13310' (9927' TVD) WAS MARKED BY THE FIRST OCCURACNCE OF BRICK RED TO ORANGE RED SHALES. INTERPRETATION OF DRILLED FORMATION WAS VERY DIFFICULT THROUGHOUT THIS INTERVAL DUE TO UNUSUAL HIGH AMOUNTS OF SLOUGH FROM UP HOLE (THE WELL BORE WAS OPEN FROM 2870' MD, THE 13 3/8'*CASING SHOE). HIGH AMOUNTS OF RESINEX ADDED TO THE MUD SYSTEM COMPLICATED DIFFERENTIATING RESISDUAL TARRY RESIDUE lq?,OM MUD ADDITIVES. THE PREDOMINENT LITHOLOGY WAS SHALES AND LIMESTONES. THE SHALES RANGED IN COLOR I~M BRICK RED TO ORANGE RED, MAROON, LIGHT TO MEDIUM GREEN, LIGHT TO MEDIUM.GREY, AND RARE PURPLES. THEY RANGED FROM NON TO VERY CALCAREOUS, .PLATY TO BLOCKY, AND OCCASIONALLY GRADED TO CALCAREOUS SILTSTONE. THEY WERE INTERBEDDED WITH LIGHT BROWN TO BUFF LIMESTONES, AND MINOR AMOUNTS OF SANDSTONE. THE SANDSTONES WERE MOSTLY CLEAR TO WHITE, VERY FINE TO FINE GRAINED, AND LOOSLY CONSOLIDATED TO VERY FRIABLE. MATRIX WAS PREDOMINENTLY CALCAREOUS, OCCASIONALLY PYRITIC, AND RARELY BRICK RED ORANGE SIDERITIC. RARE GLAUCONITE OCCURED IN SOME OF THE THINNER SANDS. -6- BASE OF THE ITKILYARIAK WAS MARKED BY THE OCCURANCE OF THICK SAND/ SANDSTONES AT 13982 *MD. DRILL RATE AND GAS DATA DRILL RATE THROUGH THE ITKILYARIAK RANGED FROM 3 - 10 FEET PER HOUR ~O THE 9 5/8*' CASING POINT AT 13496* MD, AVERAGING 4 FEET PER HOUR. AFTER CASING WAS SET, THE DRILL RATE PICKED UP ? TO 12 FEET AN HOUR, AVERAGING 8 FEET PER HOUR TO 13700'. THE INCREASE APPEARED DUE TO SMALLER HOLE SIZE, LESS DRAG ON THE DRILL STRING, AND LIGHTER MUD WEIGHT (CUT FROM 10.3 TO 9.4 PPG). FROM 13700' TO 13982 THE DRILL RATE INCREASED TO 8 -17 FEET PER HOUR, AVERAGING 12 FEET PER HOUR. THIS HIGHER RATE APPEARED DUE TO THE DECREASE IN THE AMOUNTS OF LIMESTONE DRILLED AND THE INCREASE IN SHALES DITCH GAS THROUGHOUT THE INTERVAL WAS LOW. FROM 13310* TO 13315* MD IT RANGED FROM 3 - 8 UNITS AND AVERAGED 4 UNITS. FROM 13515' TO 13982' MD TRACES TO 5 UNITS OCCURED, WITH AN AVERAGE OF ! UNIT. THE GAS DETECTION SYSTEM WAS CHECKED SEVERAL TIMES FOR FUNCTION AND ACCURACY IN THIS INTERVAL. CHROMATOGRAPH ANALYSIS SHOWED PREDOMINENTLY METHANE (C1) WITH VERY SMALL TO TRACE AMOUNTS OF C2' AND C3 IN THIN SANDS AT 13430* - 13460' MD AND 13690' - 13705* MD. OIL AND GAS SHOWS NO OIL NOR GAS SHOWS WERE NOTED IN THIS INTERVAL. THE VERY LOW AMOUNTS OF TOTAL DITCH GAS AND LACK OF HEAVY COMPONENTS OF THE PARAFFIN SERIES WERE WERE OF NOTE, AND CHARACTERIZE THE ZONE. KAYAK/KEKITUK FOMATIONS LITHOLOGy THE TOP OF THIS SEQUENCE IS MARKED BY THE SIGNIFICANT INCREASE IN SANDSTONES AT 13982' MD (10454* TVD). SANDSTONES ARE CLEAR, FROSTED, TRANSLUCENT QUARTZ AND CHERT WITH COMMON SILICEOUS OVERGROWTHS. THEY ARE LOOSLY CONSOLIDATED'TO FRIABLE WITH SLIGHTLY CALCAREOUS OR SILICEOUS CEMENT. GRAIN SIZE RANGES FROM VERY FINE TO COARSE'. THE SANDS ARE MODERATELY TO WELL SORTED. VISABLE POROSITY RANGES FROM FAIR TO VERY GOOD, WITH THE KEKIKTUK SANDS HAVING CONSISTENT GOOD VISABLE POROSITY. THERE IS APPEARANT INTERGRANULAR, RESIDUAL, LIGHT .TO MEDIUM BROWN OIL STAINING SCATTERED THROUGHOUT. THE VALIDITY OF THE STAINING IS HARD TO DETERMINE AS GILSONITE, A BLOWN ASPHALT ADDITIVE, WAS ADDED TO THE MUD SYSTEM JUST AS THE FIRST OF THE SANDS WERE DRILLED. POSSIBLE TOPS FOR KEKIKTUK SANDS AS CORRELATED IN THE ENDICOTT FIELD ARE AS DRILLED: 3A SAND, 14545* MD (10921' TVD); 2B SAND, 14784* MD (11130* TVD); 2A SAND, 14960 MD (11286* TVD); lC SAND, 15070* MD (11383* TVD). -7- COALS FIRST OCCURRED AT 14490' MD (10873' TVD) IN THE DITCH SAMPLES. THEY WERE THIN BEDDED, FIRM TO MODERATELY HARD, PLATY, PYRITIC, WITH A WOODY TEXTURE. MAJOR COALS OCCURRED ABOVE THE SAND INTERVALS IN THE KEKIKTUK AT 14710', 14940', AND 15040'. THESE COALS WERE FIRM TO HARD, IN PART BRITTLE, PLATY TO BLOCKY, AND EXHIBITTED A CONCOIDAL FRACTURE. COAL WAS LOGGED IN THE INTERVAL 15070' - 15110' MD, RUNNING ALMOST 100X OF THE DITCH SAMPLE. IT WAS LATER DETERMINED THAT THIS INTERVAL WAS SAND FROM MWD LOG DATA. SHALES THROUGH THE INTERVAL ARE LIGHT TO'MEDIUM GREY, LIGHT GREY BROWN, AND DARK GREY, CARBONACEOUS TOWARD THE BASE. THEY ARE SOFT TO FIRM AND FOR THE MOST PART NON-CALCAREOUS. THEY ARE PLATY TO BLOCKY, AND OCCASIONALLY SUBFISSILE. IN PLACES THEY GRADE TO A CARBONACEOUS SILTSTONE. DRILL RATE AND GAS DATA DRILL RATES FOR THE KAYAK/KEKITUK FORMATIONS AVERAGED APPROXIMATELY 12 FEET PER HOUR FROM 13980' - 14525', INCREASING TO AN AVERAGE OF 20 FEET PER HOUR FROM 14525' TO TD. HIGHER THAN AVERAGE DRILL RATES WERE OBSERVED WITHIN SANDS AND COALS IN THIS SECTION. GAS PEAKS OF UP TO 150 UNITS WERE ALSO OBSERVED IN THE KAYAK/KEKITUK FORMATIONS. AVERAGING 15 TO 20 UNITS. CHROMATOGRAPHIC BREAKDOWN OF THE GAS SHOWED THAT THE GAS CONSISTED OF C1 (METHANE) THROUGH C4 (BUTANE) DURING THE HIGHEST GAS PEAKS. WHILE ONLY C1 AND C2 (ETHANE) WERE OBSERVED DURING THE AVERAGE GAS READINGS OF 15 TO 20 UNITS. OIL AND GAS SHOWS NO OIL OR GAS SHOWS WERE OBSERVED IN CUTTINGS SAMPLES WITHIN THIS INTERVAL. ALTHOUGH, SLIGHT YELLOW GREEN CUT FLUORESCENCE WAS OBSERVED IN SOME SAMPLES, IT WAS LIKELY ,ATTRIBUTABLE TO ADDITIVES BEING USED IN THE MUD. -8- OIL COMPANY: PRUDHOE BAY DRILLING DATE: 8/29/93 TIME: 22:10 SHOW REPORT # 1 WELL#: SAG DELTA # 12 LOCATION: ENDICOTT, MPI MPI 2-66/SD-12 NORTH SLOPE, ALASKA SHOW INTERVAL: 12685' TO 12710' (MI)) 9422' TO 9442' (TVD) BlT SIZE: 12.2§" NUD WEIGHT: 10.3+ ppg WOB: 55 klb LOGGING COND: GOOD BIT TYPE: #15 HTC VISCOSITY: 59 RPM: 105 ATMllCG HOURS: 1.8 FILTRATE: 5.2 PUMP PR: 2900 FEET: 19' EST. PORE PRES: 9.8 ppg PUMP SPM: 180 I I I I I I I TOT I , , , , , , ROP ] GAS I C1 ~ C2 ] C3 I C4 I C5 I CHL I LITHOLOGY ft/hr~unitsJ ppm J ppm { ppm ~ ppm J ppm J ppm J I I I I I , , , , 114 128 , , BEFORE 10 I 16 I 17961 165 I 99 I 47 I O' I 39001 100% SHALE I I I I , , , , 1281 1197 ' ' DURING 65 I701 I llSKI 52451 22491 6771 252J 39001 100% SHALE .. I I I I I , , , , ~23 124 , I 80% SHALE, 10% LIMESTONE, 7 I 26 I 32881 319 I 143 J 73 J 33 I 3900J 10% TUFF I I I I I I I I I I I~1~1 I I~1 I AFTER OIL IN FLUOR: NONE NONE UNWASHED CUTT FLUOR: NONE WASHED CUTT FLUOR: DULL GOLD-MOD YELLOW STAIN' SCAT LIGHT TO DARK BROWN . I SOLVENT CUT FLUOR: PALE YELLOW TO LIGHT BLUE! ! INTENSITY: FAINT TO MODERATE , ! TYPE & SPEED: VERY SLOW, STREAMING ' NAT COLOR & RESIDUE: LIGHT TO DARK BROWN V~SUAL POROSITY: FAIR TO GOOD I I CUTTINGS DESCRIPTION: ! ! SH: V DK CRY - BLK, MOD FRM, PAPERY, PLTY, FISS, MIC MICA, V CALC MTX, TR INOC, TH PYR, ,' LT - MED CRY - TN BENT TUFF, SIDERITE, TR FN - (]CC MED SD, LOC MED C PBL FRAGS, TR CHT, SCAT DULL GLD - MED YEL SMPL FLUOR, SLO MOD STRMG PALE YEL LT BLU WI'IT CUT FLUOR, LT BRN VIS CUT, MED BRN RES STN !! ! ! I I COMMENTS: LCU: DRILL RATE INCREASE AND A CORRESPONDING SIGNIFICANT INCREASE IN BACKGROUND J ! GAS, INDICATING AN INCREASE IN POROSITY. 12' TOTAL REPRESENTING LCU. , ! · ! RATING: TRACE - FAIR ( 5 ) LOGGING GEOLOGIST' T. WOLFORD, S. HEWITT , IIIIIIII iiiiiiiiiiiiiIIiiiIIiIiIIIiiIIIiiIiiiIiiIiiiiiiiiiilillII IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII t.' mmmmmmmmmNmmmmmmmmmmmmmmmmmmmm SHOW REPORT # 2 OIL COMPANY: PRUDHOE BAY DRILLING WELL#: SAG DELTA # 12 LOCATION: ENDICOTT MPI 2-66 / SD-12 NORTH SLOPE, ALASKA DATE:8/30/93 TII~:ll:30 HOURS INTERVAL: 12774* TO 12799' 9492' TO 9512' (TVD) BIT SIZE: 12 1/4" BIT TYPE: NO. 15 HTC ATMllCG HOURS: 14.3 FEET: 107' MUD WEIGHT: 10.3+ ppg viSCOSITY: 59 FILTRATE: 5.2 EST. PORE PRES: 9.8 WOB: 55 klb RPM: 106 PUMP PR: 2870 ppg PUMP BPM: 185 LOGGING COND: C~30D I I I I I I ' l' TOT : ROP : GAS I C1 : C2 J C3 : C4 : C5 I CHL : LITHOLOGY Ift/hrlunitsl ppm I I I I I I I ~ ~ ~ ~ ~ ~8 ~ ~ 160X LIMES?ONE~ 30~ 8HALE, BEFORE I 12 I 16 I 16631 1331 611 0 I 0 ~ 4000110~ TUFF mmmmm mmmmm mmmmm mmmmmlmmmmm ......... I ..... I ..... f ..... f f ~ ' , I I I I I I I , , , , , 1289 , , 150X LIMEBTOME, 20X DOLOMITE, DURING ~ 61 J 220 ~28901~ 2294~ 1093~ 88~ 0 J 4000~30X SHALE I I I I I , , 150% LIMESTONE, 30~ DOLOMITE, AFTER [ 18 ~ 17 I 17111 1481 79J 0 J 0 I 4000120Z SHALE I I I I I I I I I I , I , I~l I I I~1 OIL IN MUD: NONE SOLVENT CUT FLUOR: YELLOW - WHITE FLUOR: NONE INTENSITY: BRIGHT UNWASHED CUTT FLUOR: - TYPE & SPEED: INSTANT WASHED CUTT FLUOR: TRACE WEAK YELLOW NAT COLOR & RESIDUE: LT STW CUT, LT BRN RES STAIN: OCC LT BRN OIL BTN ON DOL oCC TARRY RES IN SUC DOL VISUAL POROSITY: FAIR CUTTINGS DESCRIPTION: LIMESTONE: MOTTLED CREAM, LITE BROWN - TAN, GRAY, WACKSTONE - GRAINSTONE, OCCASIONAL DOLOMITE: LITE BROWN, 8UCRO8IC TEXTURED GRAINSTONE, OCCASIONAL OIL STAINED, OCCASIONAL WITH INTERGRANULAR BLACK TARRY OIL RESIDUE COMMENTS: POOR RESIDUAL SHOW IN INTERBEDDED DOLOMITES RATING: POOR ( 4 ) LOGGING GEOLOGIST: S. HEWITT, T. WOLFORD mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmm I I I (' I OIL COMPANY: PRUDHOE BAY DRILLING I DATE: 9/16/93 TII~: 20:56 I I ! SHOW REPORT #3 WELL#: SAG DELTA # 12 LOCATION: ENDICOTT MPI 2-66 / SD-12 NORTH SLOPE, ALASKA SHOW INTERVAL: 13982' TO 14003' (MD) 10454' TO 10471' (TVD) BIT SIZE: 8.5" BIT TYPE: ATMllHC HOURS: 3.9 FEET: 46 MUD WEIGHT: 9.4+ ppg VISCOSITY: 49 FILTRATE: 5.6 WOB: 35 klb RPM: 100 PUMP PR: 3000 EST. PORE PRES: 9.0 ppg PUMP SPM: 125 LOGGING COND: GOOD ~mmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~m~mmmmm ' I TOT I I I I I ROP I GAS ICl J C2 I C3 J C4 Ift/hrlunitsl ppi I ppm I PD/ I ppm I I I I I I I I I I I I BEFORE I 12 ~ I I 46 J 0 I 0 I 0 I I I I I , , , , , 133 DURING I 70 ~ 182 120.5K~ 11061 323~ 70 I I I I I I I I I I I I I I I I ~,1~1 I~1 __ AFTER ! I~l OIL IN MUD: NONE FLUOR: NONE UNWASHED CUTT FLUOR: NONE I I C5 J CHL I LITHOLOGY ppm ~ ppm I , 120% LIMESTONE, 60% SHALE, 0 ~ 4500120% SANDSTONE ,! 110% LIMESTONE, 20% SHALE, 0 J 4500J?0% SAND ! , 110% LIMESTONE, 30% SHALE, 0 I 4500J60% SAND/SANDSTONE ! SOLVENT CUT FLUOR: MILKY YELLOW INTENSITY: PALE TO MODERATE WASHED CUTT FLUOR: DULL YELLOW STAIN: NONE TYPE & SPEED: EVEN/STREAMING, MODERATE NAT COLOR & RESIDUE: THIN, LIGHT BROWN RING VISUAL POROSITY: CdX)D CUTTINGS DESCRIPTION: SAND/SANDSTONE: CLEAR TO WltlTE, FINE TO MEDIUM GRAINED, SUBANGULAR TO ROUNDED, MODERATELY TO WELL SORTED, LOOSELY CONSOLIDATED TO UNCONSOLIDATED, MODERATELY CALC/ffiEOUS, TRACES I~rRITE INCLUSIONS, NO ODOR COMMENTS: NOTE, MOST OF FLUORESCENCE AND CUT PROBABLY DUE TO ADDITION OF GILSONITE TO MUD. RATING: TRACE ( 3 ) LOGGING GEOLOGIST: TERRY WOLFORD, SAM HEWITT FINAL WELL REPORT PRUDHOE BAY DRILLING GROUP ENDICOTT SAG DELTA #12 MPI 2-66/SD-12 NORTH SLOPE, ALASKA 10 AUGUST 1993 TO 12 AUGUST 1993 THE INFORr/ATION, INTERPRETATIONS, RECO//MENDATIONS, OR OPINIONS CONTAINED HEREIN ARE ADVISORY ONLY AND MAY BE REJECTED. CONSULTANT DOES NOT WARRANT THEIR ACCURACY OR CORRECTNESS. NOTHING CONTAINED HEREIN SHALL BE DEEMED TO BE INCONSISTENT WITH, NOR EXPAND, MODIFY OR ALTER CONSULTANT'S OBLIGATION OF PERFORIW_ANCE AS PROVIDED FOR IN A WRITTEN AGREEMENT BETWEEN THE PARTIES, OR IF NONE, IN CONSULTANT'S MOST RECENT PRICE LIST. EXPLORATION LOGGING OF USA, INC. COMPILED BY: GARY HA//BURG TERRY WOLFORD APPROVED BY: JOHN N. MORRIS MIC ,FILMED · .ttO[/o.¢ TABLE OF CONTENTS PAGE INTRODUCTION ............................................ 1 SUMMARY OF DATA ......................................... 2 METHODS OF: ............................................. 3 MUDLOG ........................................... 3 DRILL DATA ACQUISITION ........................... 3 COMMUNICATIONS ................................... 3 SAMPLING PROCEDURES AND INTERVALS ................ 3 FORMATION EVALUATION HRZ LITHOLOGY ............................... 4 DRILL AND GAS DATA ...................... 4 OIL AND GAS SHOWS ....................... 4 LISBURNE LITHOLOGY ............................... DRILL AND GAS DATA ...................... OIL AND GAS SHOWS ....................... 5 APPENDIX I. SAMPLE DISTRIBUTION II. SHOW REPORTS I I I.. BIT RECORD IV. DAILY DRILLING SUI~4ARY V. FORMATION LOG (MD), FORMATION LOG (TVD) INTRODUCTION THE MPI 2-66/SD-12 WELL IS AN EXPLORATION WELL DRILLED ON THE ENDICOTT PAD, APPROXIMATELY 17.5 MILES NORTH EAST OF PRUDHOE BAY, ALASKA. COORDINATES FOR THE SURFACE LOCATION OF THE WELL ARE: 3151' FSL & 2360' FEL, IN SECTION 36, T12N, R16E UMIAT MERIDIAN. PROPOSED BOTTOM HOLE COORDINATES WERE: 2780' FSL & 4924' FEL, IN SECTION 2, TllN, R16E UM. TARGET COORDINATES WERE 3204' FSL & 4338' FEL, IN SECTION 2, TllN, R16E UM WITH A FINAL AZIMUTH OF ABOUT 234 DEGREES AND A FINAL DEPARTURE OF 9664'. TOTAL PROPOSED DEPTH WAS TO BE 15539' MD / 11571' TVD. THE MAIN OBJECTIVE OF THIS WELL WAS TO EVALUATE AND, IF PRODUCTIVE, PRODUCE THE KEKIKTUK FORMATION ON THE DOWN-THROWN SIDE OF THE MIKKELSEN BAY FAULT. THE PROPOSED TARGET WAS TO BE REACHED THROUGH THE USE OF DIRECTIONAL DRILLING TOOLS AND TECHNIQUES TO DRILL A DEVIATED HOLE TO REACH THE PROPOSED TARGET. THE KICK OFF WAS TO START AT 500' MD AND ' BUILD ANGLE AT RATES OF 1 - 2 DEGREES PER 100' UNTIL AN AVERAGE HOLE ANGLE OF ABOUT 46.35 DEGREES, FROM TRUE VERTICAL, WAS OBTAINED BY ABOUT 3568' MD (3308' TVD). THE HOLE ANGLE WAS TO BE HELD TO FINAL WELL TD. IT WAS DESIRED TO DRILL 12-1/4" HOLE AND SET 9-5/8" CASING SHOE AT THE TOP OF THE KAYAK, AND THEN SET 7" LINER AFTER DRILLING 8-1/2" HOLE TO FINAL WELL TD. THE DRILLING ASSEMBLY TWISTED OFF AT THE NEAR MONEL STABILIZER WHILE DRILLING IN THE ORIGINAL HOLE AT 12762' MD (9529' TVD). SEVERAL UNSUCCESSFUL FISHING ATTEMPTS WERE MADE TO RECOVER THE BHA; AFTER, WHICH A CEMENT PLUG WAS SET UPHOLE FOR A SIDETRACK. FINAL WELL TD WAS IN THE LISBURNE. -1- SUI~ARY OF PERTINENT DATA .WELL NAME: API NUMBER: OPERATOr: PARTNERS: CONTRACTOR: LOCATION: ELEVATION: CASING: DATE SPUDDED: DATE TOTAL DEPTH REACHED: FINAL TOTAL DEPTH: CONVENTIONAL CORES: FORMATION TESTS: HYDROCARBON SHOWS: COMPANY GEOLOGISTS: B.H. INTEQ GEOLOGISTS: FINAL WELL STATUS: ENDICOTT MPI 2-66/SD-12 50-029-22374 PRUDHOE BAY DRILLING GROUP ARCO ALASKA~ BP EXPLORATION, AND EXXON DOYON RIG #15~ LAND 3151' FSL, 2360' FEL SEC 36, T12N, R16E UMIAT MERIDIAN GROUND LEVEL 10~ ABOVE MEAN SEA LEVEL ROTARY KELLY BUSHINg 56' ABOVE MSL 13.375" AT 2870~ RKB 25 JULY 1993 11 AUGUST 1993 12762~ MD, 9529~ TVD NONE WERE CUT NONE RUN AT THIS TIME SEE SHOW REPORTS - APPENDIX II CONNIE ZARNDT - BP EXPLORATION GARY HAMBURG~ TERRY WOLFORD TWISTED OFF LOWER B.H.A. SET CEMENT PLUG FOR SIDETRACK -2- METHODS GEOLOGIC AND DRILLING DATA WAS COLLECTED AT THE WELLLSITE USING EXLOG'S DRILL MONITOR SYSTEM (DMS). THE SYSTEM IS A COMPUTER BASED DATA COLLECTION UNIT, USED IN ACQUISITION, COMPILATION AND OUTPUT OF DATA. ADDITIONAL LITHOLOGIC AND HYDROCARBON EVALUATION WAS PROVIDED BY EXLOG'S ONSITE GEOLOGISTS. METHODS OF ANALYSIS USED FOR EVALUATION ARE PRESENTED IN EXLOG'S MANUAL "MUDLOGGING: PRINCIPLES AND INTERPRETATIONS" (MS-196). biUDLOG THE LOG FORMATS WERE STANDARD MEASURED DEPTH AND TRUE VERTICAL DEPTH LOGS. DATA DISPLAYED ON THE LOG INCLUDES: LITHOLOGY, RATE OF PENETRA- TION, TOTAL GAS, CUTTINGS GAS, CHROMATOGRAPH DATA, AND SHOW QUALITY WHEN PRESENT. TOTAL GAS, RATE OF PENETRATION, AND CUTTINGS GAS ARE PLOTTED LINEARLY, WHILE ALL OTHER PARAMETERS ARE PLOTTED LOGARITHMICALLY. LOGS WERE PLOTTED AS 2 INCHES PER 100 FEET (1:600). DRILL DATA DRILLING DATA MONITORED INCLUDED: RATE OF PENETRATION (ROP) USING THE BLOCK HEIGHT SYSTEM, HOOKLOAD, WEIGHT ON BIT, AND PUMP STROKES. H2S WAS ALSO MONITORED THROUGH THE GAS STREAbi FROM THE SHAKERS ON A CONTINUAL BASIS. SAMPLING SAMPLES WERE COLLECTED AT 10 FOOT INTERVALS FROM 12420' TO FINAL WELL TD AT 12762'. TWO WET SAMPLES AND THREE DRY SAMPLES WERE COLLECTED. ALL SAMPLES WERE PRESENTED TO B.P. AT THE WELL SITE FOR FURTHUR DISPOSITION. A COMPLETE LISTING OF SAMPLES COLLECTED CAN BE FOUND IN THE.APPENDIX OF THIS REPORT. -3- FORMATION EVALUATION LOGGING COMMENCED AT 01:07 HOURS, AUGUST 10, 1993 AT 12420 FEET MD (9260 FEET TVD) IN THE LATE CRETACEOUS. ALL DEPTHS, UNLESS OTHERWISE SPECIFIED, ARE REFERENCED FROM THE ROTARY TABLE WHICH WAS 56 FEET ABOVE SEA LEVEL. ALL FORMATION TOPS MENTIONED, ARE UNCONFIRMED AND APPROXII~TE, AND ARE SUBJECT TO CHANGE AT A LATER DATE. HRZ SHALE LITHOLOGY BAKER-HUGHES INTEQ CALVE ON LINE WHILE DRILLING IN THE LOWER CRETACEOUS HRZ UNIT. THE DRILL CUTTINGS OVER THE SHAKER WERE COMPOSED OF VERY DARK GRAY TO BLACK CARBONACEOUS AND MICACEOUS SHALES. THE SHALES EXHIBITED A FISSILE, FLAKEY, AND PLATEY APPEARANCE. THE SHALE WAS ACCOMPANIED BY LIGHT GRAY TO GRAY WHITE, SUB PLATEY TO SPLINTERY, TUFF AND MEDIUM BROWN TO CREAM WHITE INOOERAMUS FRAGMENTS. THE PRESENCE OF BENTONITIC TUFF IN THE SAMPLES WAS THOUGHT TO BE HOLE CAVINGS. PYRITE AND TRACES OF CHERT AS WELL AS OCCASIONAL cOARSE ROUNDED AND BROKEN PEBBLE FRAGMENTS. THE HRZ CONTINUED ON TO THE TOP OF THE LOWER CRETACEOUS UNCONFORMITY (LCU) AT 12737' 1~ (9431' TVD). DRILL RATE AND GAS DATA THE RATE OF PENETRATION THROUGH THE HRZ RANGED FROM 17 TO 28 FEET PER HOUR WITH 2 ISOLATED PEAKS OF UP TO 50 FEET PER HOUR. THE AVERAGE RATE OF PENETRATION WAS ABOUT 20 FEET PER HOUR. DITCH GAS RANGED FROM A LOW OF 4 TO A HIGH OF 83 UNITS WITH AN OVERALL'~AVERAGE OF 30 UNITS BACKGROUND FORMATION GAS. ONE SHORT TRIP GAS OF 380 UNITS WAS NOTED AT 12516' MD. C1 (METHANE) RANGED FROM 352 TO 14037 PPM WHILE C2 (ETHANE) RANGED FROM 25 TO 1176 PPM AND C3 (PROPANE) VARIED FROM 14 TO 408 PPM. IC4.(ISO-BUTANE). AND NC4 (NORMAL-BUTANE) VARIED FROM 0 TO 131 PPM. OIL AND GAS SHOWS THE HRZ WAS CHARACTERIZED BY A PERSISTENT WEAK LIGHT BLUE SOLVENT CUT FLUORESCENCE WITH LOCAL WEAK STRAW TO LIGHT BROWN VISIBLE CUTS AND LOCAL MEDIUM BROWN RESIDUAL STAIN. THE PERSISTENT CUTS WERE PROBABLY DUE TO THE HIGH CARBONACEOUS CONTENT OF THE SHALE AND THE SOURCE BED CHARACTERISTICS OF THE HRZ. '-4-- LISBURNE GROUP LITHOLOGY THE LOWER CRETACEOUS UNCONFORMITY (LCU) AND THE TOP OF THE LISBURNE GROUP, OF PENNSYLVANIAN AGE, WAS ENCOUNTERED AT THE BOTTOM OF THE HRZ AT 12637' I~D (9431' TVD). THE PRESENCE OF THE LCU WAS CHARACTERIZED BY A DRAMATIC INCREASE IN PENETRATION RATE AND A SHARP INCREASE IN BACKGROUND GAS FROM THE OVERLYING HRZ. A LITHOLOGY CHANGE WAS NOTED BY THE APPEARANCE OF GRAY AND WHITE CHERT AS THE SHALE BEGAN TO GRADE TO SILTSTONE. THE APPEARANCE OF LIGHT GRAY TO GRAY WHITE CHALKY LIMESTONE WAS NOTED BY 12650' (9441' TVD). THE SILTSTONE QUICKLY GAVE WAY BACK TO BLACK CARBONACEOUS SHALE ACCOMPANYING LIMESTONE IN THE SAMPLES. BY 12730' MD (9§04'TVD), LIMESTONE WAS PREDOMINATE IN IN THE CUTTINGS SAMPLES. THE LIMESTONE WAS LOCALLY CHERTY AND RANGED FROM FIRM AND CHALKY TO MODERATELY HARD AND VITREOUS IN PART. THE LIMESTONE WAS GENERAnLY CLEAN AND ONLY LOCALLY SLIGHTLY ARGILLACEOUS. DOLOMITIC AND SLIGHTLY SUCROSIC LIMESTONE WAS AN EXCEPTION AND RARELY NOTED IN THE SAMPLES. A .SLIGHT CARBONACEOUS PARTING APPEARANCE WAS PRESENT LOCALLY IN THE SAMPLES. DRILL RATE AND GAS DATA THE PENETRATION RATE INCREASED FROM AN AVERAGE OF 15 FEET PER HOUR IN THE OVERLYING HRZ TO A MAXIMUM OF 66 FEET PER HOUR IN THE LCU. AFTER 12656' l~I), THE DRILL RATE VARIED FROM 8 TO 25 FEET PER HOUR WITH AN AVERAGE RATE OF PENETRATION OF 14 FEET PER HOUR TO THE END OF THE HOLE. BACKGROUND GAS INCREASED TO A MAXIMUM OF.138§ UNITS IN THE LCU AND THEN DROPPED, AFTER 12660', TO RANGE FROM 8 TO 30 UNITS WITH AN AVERAGE OF 20 UNITS BACKGROUND GAS TO THE BOTTOM OF THE HOLE. ALL COMPONENTS OF THE PARAFFIN SERIES, C1 - C4, WERE PRESENT AT THE TOP OF THE LISBURNE, IN THE LCU, AND WERE PRESENT OVER THE REMAINDER OF THE HOLE WITH THE EXCEPTION OF IC4 WHICH DROPPED OUT AFTER 12714' MD (9491' TVD). C1 REACHED A MAXIMUM OF 209K PPM AT THE TOP WITH C2, C3, IC4, AND NC4 REACHING MAXII~ VALUES OF 13.7K PPM, 6117 PPM, 876 PPM, AND 1871 PPM, RESPECTIVELY. Gl DROPPED, AFTER 12660' MD, TO RANGE FROM 551 TO 4030 PI~ WHILE C2 VARIED FROM 43 TO 279 PPM. C3 RANGED FROM 26 TO 134 PPM WHILE NC4 VARIED FROM 15 TO 55' PPM. IC4 RANGED FROM 2 TO 19 PPM UNTIL DROPPING OUT. SEE SHOW REPORT IN THE APPENDIX. OIL AND GAS SHOWS THE HIGH GAS VALUES NOTED ABOVE, AT THE TOP OF THE LISBURNE, WERE ACCOMPANIED BY WEAK AND SLOW LIGHT BLUE STREAMING SOLVENT CUT FLUORESCENCE AND LOCAL FAINT STRAW VISIBLE CUTS WITH LIGHT TO MEDIUM BROWN RESIDUAL STAINING. MEDIUM TO DARK BROWN STAINING WAS SCATTERED AND DECREASED WITH DEPTH. VISIBLE POROSITY WAS POOR AND SOLVENT CUTS WERE POOR AFTER 12730' MD (9504' TVD). -5- APPENDIX I. SAMPLE DISTRIBUTION SAMPLE SHIPMENT FROM PBD ENDICOTT SAG DELTA # 12 UNIT 242, DOYON RIG 15 MPI 2-66/SD-12 8/15/93 WET SAMPLES SETS A, B BOX NO. W1A, W1B TOTAL 2 BOXES WET SAMPLES INTERVAL 12430' - 12760' DRY SAMPLES SETS A, B, C (STATE OF AK SET) BOX NO. (SHIPPING) A,B C INTERVAL (CARD BOXES) 12430' - 12760' 12430' - 12760' TOTAL 3 BOXES DRY SAMPLES TOTAL 5 BOXES SHIPPED TO: STORED IN LOGGING UNIT 905 ON ENDICOTT ISLAND FOR LATER DISPOSITION 08/15/93 -1- APPENDIX II. SHOW REPORTS OIL COMPANY: PRUDHOE BAY DRILLING DATE: 8/10/93 TIME: 15:18 SHOW REPORT # 1 WELL#: SAG DELTA # 12 LOCATION: ENDICOTT, MPI MPI 2-66/SD-12 NORTH SLOPE, ALASKA SHOW INTERVAL: 12639' TO 12652' (MD) 9388' TO 9394' (TVD) BIT SIZE: 12.25" MUD WEIGHT: 10.3+ BIT TYPE: #9 STC M15SCL VISCOSITY: 73 HOURS: 30.4 FILTRATE: 6.6 FEET: 522' EST. PORE PRES: 9.8 ppg ppg WOB: 55 klb RPM: 100 PUMP PR: 2960 PUMP SPM: 182 LOGGING COND: GOOD BEFORE DURING AFTER ROP ft/hr 18 66 I I I TOT GAS units 1385 · 30 C1 C2 ppm ppm 253 19 209K: 13. 2686 201 C3 ppm 10 6117 108 iC4 nC4 ppm ppm 0 8 876 1871 19 53 CHL ppm 2100 2100 2100 LITHOLOGY 100% SHALE 10% CHERT, 90% SHALE 20% CHERT, 40% SHALE, 40% SILTSTONE OIL IN MUD: NONE SOLVENT CUT FLUOR: LIGHT BLUE FLUOR: NONE INTENSITY: FAINT TO MODERATE UNWASHED CUTT FLUOR: NONE TYPE & SPEED: VERY SLOW, STREAMING WASHED CUTT FLUOR: DULL GOLD-MOD YELLOW NAT COLOR & RESIDUE: LIGHT TO DARK BROWN STAIN: SCAT LIGHT TO DARK BROWN VISUAL POROSITY: FAIR TO GOOD CUTTINGS DESCRIPTION: SH: DK BN - BLK, MOD FRM, PAPERY, PLTY - OCC ELONG, SUBFISS - FISS, MIC MICA, V CALC MTX V CARB, ABNT CHT FRAGS, TR PYR, MOD - ABNT TUFF, LT - DK BRN STN, FNT'PET ODOR, LOC TR FSS, SCAT DULL GLD - MED YEL SMPL FLUOR, LT BL - WHT SLO STMG CUT FLUOR, STRAW VIS CUT, LT BRN RES STN. CHT: LT - MED GRY - WHT, V ANG - SUBRND FRAGS, SCAT LT - DK BRN SURF STN, MICRO-FRAC COMMENTS: LCU: DRILL RATE INCREASE AND A CORRESPONDING SIGNIFICANT INCREASE IN BACKGROUND GAS, INDICATING AN INCREASE IN POROSITY. 13' TOTAL REPRESENTING LCU. RATING: POOR - FAIR ( 4 ) LOGGING GEOLOGIST: T. WOLFORD, G. HAMBURG APPENDIX III. BIT RECORD ." / Il,' ! ,' ', ,' ,' sIZ~ "~ ~EP~H,' I~. ,'IRS,' ROP IxlO00[ I PR[SSlII:O:D: I '"~ .....+ ........t ..........t ......~ ...........~ .......~ .......? ..... + .......~ ..... ~ ..... ? ...... ~ .........+ ....................... Iii I I STC I A1JSL 116,00 ITFA=0,62661 I101 2770 I 21,51 128,81 301 240 I 2200 1169/711 ~...~ .....~ ........~ ..........~ ......~ ...........~ .......~ .......? ..... ~ .......~ ..... ~ ..... ~ ......~ .........~ ........................ I 2 I I I iTC i AT~-Clll 112.15 l?~i: 0.83141 1880 I 489 I f.Ol 97.81 10II80 I1500 I150/634 ?...? .....t ........~ ..........~ ......t ...........~ .......t .......~ ..... ~ .......t ..... + ..... ~ ......~ .........+ ........................ ~---? .....+ ........? ..........t ......? ...........? .......~ .......t ..... ? .......? ..... i ..... t ...... ? .........~ ........................ I 4f t I STC IMFDSHCL 112,25 ITFA=0,75771 378II 27911 44,0f 63,41 201180121001150/634 ?---~ .....t ........t ..........t ......? ...........? .......t .......~ ..... t .......t ..... ? ..... ? ......+ .........? ........................ 15 I 5 I STC I ~DSS~C 112,25 IT~A= 0,96641 6572 f 2256 I 31,01 72,8 I 55 I 110 I I950 I 134/566 13:4:~T: A:E: I/8:fO:HR ~.--? .....? ........t ..........~ ......~---~ .......t .......? .......~ ..... ? .......+ ..... ~ ..... ? ......? .........? ........................ 161 6 I iTC IATICMG1 112.25 IT~A=0,83441 8828 I 795 I 17,01 46,81 30[ 11013fl001 170/717 ?---t .....+ ........t ..........? ......+ ...........? .......t .......t ..... ? .......t ..... t ..... ? ......t .........? ........................ I 7 I 7 I HYCALOGI DS591 112,25 IT~A= 0.99091 9623 I 1953,1 35,01 55,8 I 12 I II0 I 3050 I 170/718 ~---? .....+ ........+ ..........~ ......+ ...........? .......? .......? ..... t .......? ..... ? ..... ? ......+ .........~ ........................ I 8 I. 8 I IYC I ATMllCG II1,~5 ITFA= 1,0492f 11576 f 5411 33,01 16,4 I 55 I 110 I 3000 I 165/696 II:2:--:MI:E: I:]O:SH ~---~ ..... ~ ........ ~ .......... ? ...... ? ........... ? ....... ~ ....... ? ..... ? ....... t ..... ? ..... ? ...... ? ......... ? ........................ 191 9 I STC I~ISSCL f12,i5 IrmA= 0,97861 121171 645136,61 17,6 I 55 I I00 f3ooo 1164/692 I:: : :: : : ~---t ..... t ........ ? .......... ? ...... ? ........... ? ....... + ....... ~ ..... ? ....... ? ..... t ..... t ...... t ......... ? ........................ APPENDIX IV. DAILY DRILLING SUMM~Y DRILLING LOG FOR ENDICOTT MPI 2-66/SD-12 AUGUST 7, 1993 CREW ARRIVED AT RIG AND POWERED UP THE UNIT AND EQUIPMENT. AUGUST 8, 1993 CONTINUE RIGGING UP AND CHECKING OUT EQUIPMENT. AUGUST 9, 1993 CONTINUED TO CHECK OUT EQUIPMENT WHILE WAITING FOR LOGGING DEPTH AUGUST 10, 1993 12420' - 12743' EXLOG CAbiE ON LINE AT 01:07 HOURS ON AUGUST 10, 1993 WHILE DRILLING AT 12420' MD (9260' TVD) IN THE CRETACEOUS HRZ. 12-1/4" HOLE WAS BEING DRILLED WITH BIT # 9, STC M15SCL, AND A CONVENTIONAL DRILL STRING. THE DRILLING FLUID USED WAS A 10.3 TO 10.3+ PPG LSND MUD SYSTEM. CONTINUED DRILLING AHEAD TO 12515' WHERE A SHORT TRIP TO 11656' WAS PULLED WITH NO PROBLEMS. CONTINUED DRILLING AHEAD AND SHORT TRIP GAS WAS 380 UNITS. DRILLED AHEAD TO THE TOP OF THE LISBURNE (LCU) AND THE START OF A DRILLING BREAK AT 12637' MI) (9431' TVD). DRILLED AHEAD TO 12666' AND CIRCULATED OUT GAS AND SAMPLES. MAXIMUM BACKGROUND GAS RECORDED FROM THE BREAK WAS 1385 UNITS, WHICH WAS SIGNIFICANTLY HIGHER THAN THE PREVIOUSLY RECORDED VALUES OF 9 TO 40 UNITS. THE RATE OF PENETRATION INCREASED FROM 18 FEET PER HOUR TO A MAXII~%rb{ OF 66 FEET PER HOUR IN THE DRILLING BREAK. CONTINUED TO DRILL AHEAD AT 8 TO 28 FEET PER HOUR WITH BACKGROUND GAS AVERAGING ABOUT 15 UNITS. AUGUST 11, i993 12743' - 12762' CONTINUED TO DRILL AHEAD TO 12762' bid (9529' TVD). A CONNECTION WAS MADE, A CARBIDE WAS DROPPED TO CHECK HOLE VOLUME, AND A SURVEY WAS PUMPED UP. THE DRILLER THEN NOTICED AN IMMEDIATE 500 PSI DROP IN PUMP PRESSURE FROM 3000 TO 2500 PSI AND THE MWD TOOL WOULD NO LONGER TURN ON. PULLED OUT OF THE HOLE WET CHECKING FOR LEAKS AND DISCOVERED THAT THE BHA WAS PARTED AT THE UPPER NEAR MONEL STABILIZER LEAVING THE APPROXIMATELY 180' OF BHA, INCLUDING THE MWD TOOL~ IN THE HOLE. TESTED THE STACK, CHECKED THE GAS ALARMS ON THE RIG, AND RECALIBRATED EXLOG'S H2S DETECTOR, TO ENSURE ACCURATE OPERATION. PICKED UP A TAPER TAP TO RUN IN THE HOLE FOR THE FIRST FISHING ATTEMPT. WASHED THROUGH A TIGHT SPOT AT 8880' AND CONTINUED TO RUN IN THE HOLE. WASHED AND REAMED FROM 12503' TO 12564' WHERE THE bfUD SYSTEM AND HOLE WAS CIRCULATED AND CONDITIONED. biAXIMUM GAS WAS 26?? UNITS. -1- AUGUST 12, 1993 12762' CONTINUED TO CIRCULATE AND CONDITION THE HOLE. MAXIMUM BACKGROUND GAS WAS 51 UNITS. WASHED AND REAMED TO 12574' WHILE ATTEMPTING TO ENGAGE THE FISH. PULLED OUT OF THE HOLE WHEN THE TOP OF THE FISH COULD NOT' BE REACHED. PICKED UP A SPEAR AND RAN IN THE HOLE. ATTEMPTED TO ENGAGE THE TOP OF THE FISH AT 12583' BUT THE EFFORT WAS UNSUCCESSFUL. PULLED OUT OF THE HOLE AND PICKED UP A BIGGER DIAMETER SPEAR. AUGUST 13, 1993 12762' RAN IN THE HOLE AND ATTEMPTED TO ENGAGE THE FISH. PULLED OUT OF THE HOLE WITH NO FISH ATTACHED. PICKED UP A MILL TO RUN IN THE HOLE IN ORDER TO CUT A STUB ON THE STABILIZER FOR AN OVERSHOT TO GRAB ON TO. RUN IN THE HOLE AND MILLED OVER THE FISH FROM 12583' TO 12586'. CIRCULATED AND CONDITIONED THE MUD BEFORE PULLING OUT OF THE HOLE. MAXIMUM BOTTOMS UP GAS WAS 159 UNITS. LAID DOWN THE SPEAR AND PICKED UP AN OVERSHOT TO RUN IN THE HOLE. AUGUST 14, 1993 12762' RAN IN THE HOLE WITH THE OVERSHOT AND ATTEMPTED TO ENGAGE THE FISH. PULLED OUT OF THE HOLE WITH THE OVERSHOT AND PICKED UP A DIFFERENT SIZED GRAPPLE FOR THE LAST FISHING ATTEMPT. RAN IN THE HOLE AND ATTEMPTED TO ENGAGE THE TOP OF THE FISH AT 12583'. THE MUD WAS CIRCULATED AND CONDITIONED AFTER THE ATTEMPT WAS NOT SUCCESSFUL. MAXIMUM TRIP GAS WAS 92 UNITS. PULLED OUT OF THE HOLE AND LAID DOWN THE DRILL COLLARS AND FISHING TOOLS. RAN IN THE HOLE WITH OPEN ENDED DRILL PIPE AND A PLUG CATCHER. AUGUST 15, 1993 CIRCULATED 18 POUND BARITE PLUG AND SPOTTED AT 11700'. PULLED OUT OF 'THE HOLE TO 11500. PUMPED 20 BARRELS OF WATER FOLLOWED BY 49 BARRELS OF CEMENT FOLLOWED BY 3 BARRELS OF WATER. DISPLACED CEMENT AND SHEARED THE PLUG AT 2500 PSI. PULLED OUT OF THE HOLE TO 10108' AND CLEANED THE.PIPE BEFORE PULLING OUT OF THE HOLE. -2- This is to acknowledg receipt of the following _nts and negatives. COMPANY: STATE OF ALASKA ATTENTION: LARRY GRANT FIELD: ENDICOTT WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA 1-51/V-20 (PERF~PFC CCL S" %%~o~ 1._ rL%66% 0 1 2-66/SD-12 SBT/GR~CCU 5" ~55~O ~ ~%~ 0 - 05/0-29 PLS ~INJECTION) 1 0 1 , . , , I, , SIGNED DATE a~; ~'~ Please retun one copy of signed transmittal to each of the following: Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Alaska Oil Gas Conscrcation Commission 3001 Porcupine Drive Anchorage, Alaska ggS01-3192 907-279-1433 Permit The following data is hereby acknowledged as being received: I! :~ Mb 1 g. q20 .--.,l~_?u 2_ Dated: Copy sent tn sender: Yes ~ No ~ '"""" ""-"'""'" ...... '-'" .... INVENTORY LiST AUbbb br'ULUblbAL MR I r_.l-URLb PERMIT) ~5 - 7~ i LOG 1YPE RUN INTERVALS SCALE NO. [to the nearest foot) [inchl100'] 20) ' ' 211 ' 231 ,, ..... m ,mm 251 ..... ani ~21 " mm m m m m m aal · m m m m mm m m m imm m m m m m m I I I II J ~ .. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil and Gas Conservation Commission Attn' R. Crandall 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Robert, As per our phone conversation earlier today, this is to reiterate that running of the gyro survey for Endicott MPI 2-66/SD-12 has been delayed and consequently related final wellbore trajectory data will not be available until November. The well completion summary form (407), drilling report history, and MWD directional data that you requested are currently being reviewed by our drilling department pdor to distribution. We anticipate that you will receive the information next week. If you have any questions regarding these data, please contact Marion Sloan at 564-5127. Also, final open hole wireline log hard copies have been distributed by Schlumberger, however issuance of associated LIS tapes have not due to contractor delays. Final tapes should be distributed next week. Similarly, contractor errors have delayed distribution of finalized mudlogs, and we expect that finalized mudlogs and MWD logs hard copies will be distributed next week along with final formation marker picks. Best Regards, , BTent J. Voorhees Endicott Development 564-4448 29 October, 1993 RECEIVED NOV - 1 199 Alaska.0il & Gas Cons. C0mmissio, ~Anofiomge " (' STATE OF ALASKA (' ' ALASKA UIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL Et GAS [] SIJSPEM3ED [] ~=d~d~ItNDONED [] SERVICE [] 2. Name of Operator U~f~,,~ , 7. Permit Number BP Explorationbl f ~..~4 93-79 3. Address / B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 .~,~ so- 029-22374 4. Location of well at surface 9. Unit or Lease Name R16E ':~ ......... .~ ~: 't.OC, ATK3~ r Duck Island Unit/Endicott 3151' NSL, 2360' WEL, SEC. 36, T12N, ~ .,'.m .; .-~.'-'~:~ At Top Producing Interval i ~¥/_ ~_..~-~ 1804' SNL, 3956' WEL, SEC. 2, T11N, R16L~ '~i~'~- i ~ 2-66/SD-12 t .~:, · ,=_ ~ 11. Field and Pool At Total Depth i -4~_C._~..__..~. i~ Endicott Field/Endicott Pool 2005' SNL, 4580' WEL, SEC. 2, T 11N, R16E . ,. 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 56' I ADL 34636 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. er Aband. 115. Water Depth, if offsho re 116. No. of Completions 7/25/93 9/25/93 1.g/4'/99 /o~.,z~,~I 6-12' MSL feet ESL lOne 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD} 19. Directional Survey ~:~0. Depth where SSSV set ~1. Thickness of Permafrost 15203' MD/11505' TVD 15179' MD/11484' TVD '~s [] N~ []I None feet MD 11465' (Approx.) 22. Type Electric or Other Logs Run Run #1 RFT/GR Run #2 DIUGR/CNI../LDT Run ;K3 DIL/GR/CNL/LDT 23. CASING, LINER AND CEMENTING FIECOFID SE~ DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I'rOM HOLE SIZE CEMI~4'rlNG RECORD AMOUNT PULLED 20" Struct. Drive 37' 131' 30" Drive 13-3/8" 68# N T-80 42' 2871' 16" 550 sx "E"/400 sx Class "G" 9-5/8" 47# NT80/NT95 45' 13502' 12-1/4" 1280 sx Class "G" 7" 29~ 13CR80 13195' 15200' 8-1/2" 770 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD Interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Not on production I N/A Date of Test Hours Tested PRO[X~TION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SiT_.E IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure ~ALCULATED..~ OIL-BBL GAS-MCF WATER-BBL 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. RECEIV B N OV - 1 1993 Alaska 0ii & Gas Cons. Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ( 30. GEOLOGIC MARKERS i-,.~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEP'IH TRUE VERT. DEPTH GOR, and time of each phase. Base HRZ 12667' 9419' Top Kekiktuk 13920' 10362' Top Zone 3B 14226' 10652' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signf/~ ~, ° .~/~'~,/ ~ TitleDrillin.clEnclineerSupervisor hate I ~"'" I '~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 · If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". RECEIVED Form 10-407 NOV - 1 1993 Alaska 0il & Gas Cons. CommissioD Anchorage BP/AAI SHARED SERVICE ( DAILY OPERATIONS PAGE: 1 WELL: MPI 2-66/SD-12 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 07/24/93 06:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 07/25/93 (1) TD: 110'( 0) 07/26/93 (2) TD: 1260'(1150) 07/27/93 (3) TD: 2880'(1620) 07/28/93 ( 4) TD: 2880'( 0) REPLACING UTILITY LOOP IN TOPE MW: 8.6 VIS:340 (THIS TIME IS FROM RELEASE FROM WELLHEAD REPAIR ON 1-15 UNTIL RIG ACCEPT ON 07/24/93 (2-66). ACCEPT RIG ON LOCATION @ 0600 07/24/93. DELAYED MAINTENANCE TAKING PLACE THAT COULD NOT BE DONE WHILE OPERATIONG AT LAST WELL. REPLACED UNIONS ON CHOKE & KILL LINES (AAOGC INSISTENCE) & R/U DIVERTER, MIXED SPUD MUD, ETC. WHILE REPLACING UTILITY LOOP ON TOP DRIVE. ALSO REBUILDING AUGER COVER TO ROCK WASHER UNIT BEFORE SPUD. DOING ELECTRICAL HOOKUPS NOW ON UTILITY LOOP; ESTIMATE COMPLETION +3 HRS. DRILLING MW: 8.9 VIS:240 FINISH TOP DRIVE UTILITY LOOP REPLACEMENT. P/U BHA. FUNCTION TEST DIVERTER SYSTEM. PRE-SPUD MTG. SPUD WELL @ 1130 HRS; DRILLING TO 608. GYRO SURVEYS READING 180 DEGREE OUT OF PHASE W/MWD EVEN THOUGH MWD READINGS ARE INTERMITTENT DUE TO MAGNETIC INTERFERENCE. MWD SIGNAL FAILED DUE TO SOFTWARE PROBLEM. GYROED. DRILLING TO 894 W/HYRO SURVEYS UNTIL MWD SWITCHED TO TOOL FACE READING. DRILLING & SURVEYING TO 1260 W. MWD ONLY. RUNNING 13-3/8" CASING MW: 9.3 VIS: 94 DRILLING TO 1528 WITH GYRO SURVEYS. SHORT TRIP BACT TO 220'. DRILLING & SURVEYING TO 2880. CBU. SHORT TRIP TO HWDP CBU. POOH TO RUN CASING. R/U DOYONG TO RUN 13-3/8" CASING. TESTING BOP'S MW: 9.3 VIS: 54 RUN 13-3/8" CASING (72 JT'S). R/U CMT HEAD & CIRC VOLUME OF CASING WHILE'RECIPROCATING 30' STROKES. TEST LINE TO 2500 PSI. PUMP 100 BBL'S WATER, 550 SX LEAD & 400 SX TAIL CMT. SWITCH TO RIG PUMPS & DISPLACED @ 10.5 BPM WHILE RECIPROCATING 30' STROKES. BUMPED PLUG & RELEASED PRESSURE, FLOATS HELD. CIP @0300 HRS. GOT ALL THE WATER SPACER BACK, + CMT-CONTAMINATED MUD WHEN PLUG BUMPED. R/D CMT HEAD, B/O LANDING JT & N/D DIVERTER SYSTEM. R/U BJ FOR TOP JOB & PUMPED ALL 250 SX. CMT WITHOUT GETTING CMT TO SURFACE. INSTALL CIW SPLIT SPEED HEAD. N/U BOP'S N/U NEW DRILLING SPOOL. TESTING BOP'S. RECEIVED NOV -- "l 1993 Anchorage WELL : MPI 2-66 OPERATION: RIG : DOYON 15 PAGE: 2 07/29/93 (5) TD: 3400' ( 520) 07/30/93 (6) TD: 3781'( 381) 07/31/93 (7) TD: 4750'( 969) 08/01/93 (8) TD: 6412'(1662) 08/02/93 (9) TD: 7616'(1204) 08/03/93 (10) TD: 8828'(1212) 08/04/93 (11) TD: 9700'( 872) 08/05/93 (12) TD:10239' ( 539) 08/06/93 (13) TD:11100'( 861) DRILLING MW: 9.2 VIS: 53 TEST BOP. P/U BHA %2, TEST MWD & RIH TO 2785. BREAK CIRC. TESTED CASING. DRILL SHOE TRACK & 10' NEW HOLE TO 2890 MD. CBU UNTIL MW IN/OUT. RUN LOT. DRILL, SLID & SURVEYED TO 3369. CIRC. POOH. RIH. DRILLING RIH MW: 9.3 VIS: 70 DRILLING TO 3514'. CBU. ROUND TRIP FOR BHA CHANGE; CHANGED OUT 24 DP. COULDN'T CIRC WHEN BACK ON BOTTON. TRIP TO UNPLUG BIT-FOUND MWD SCREEN. SLIDING & DRILLING W. AGGRESSIVE BUILD ASS'Y. CIRCULATE. POOH, BACKREAM TIGHT SPOT @ 3553-3545. ROUND TRIP FOR NEW BHA & BIT, PICKED UP STEERABLE ASS'Y TO RIH. DRILLING MW: 9.3 VIS: 70 RIH TO 3250. POOH. RIH. CUT DRILING LINE AFTER RIH TO 100' ABOVE SHOE. STRIHNG HAD PLUGGED OFF AGAIN WHILE WORKING. CLOSED ANNULAR & REVERSE CIRCULATED. RIH WASHING. DRILLING. CBU. SHORT TRIP TO SHOE. PULLED TIGHT 4222-3686~ POOH. CIRC INSIDE SHOE TO CLEAN ANNULUS UNTIL SOLIDS CLEANED UP. SWIVEL PACKING BEGAN LEAKING DURING SHORT TRIP; REPLACED. RIH. WASH FROM 4134-4324. RIH TO BOTTOM. DRILLING. DRILLING MW: 9.6 VIS: 58 DRILLING & SLIDING TO 5935. CIRCULATE HOLE CLEAN. SHORT TRIP THROUGH NEW HOLE (5935-4985). DRILLING 6412. ROP. DRILLING @ 7616'MD MW: 9.6 VIS: 58 DRLG TO 6572'. CIRC & COND HOLE FOR TRIP. TRIP OUT. CHANGE BHA. TRIP IN TO 1100'. TEST MWD. TRIP IN. DRLG & SURV TRIP OUT FOR BIT MW: 9.7 VIS: 60 DRLG TO 7845'. SHORT TRIP 7845' - 6500'. DRLG F / 7845' T / 8828'. CIRC & COND. TRIP OUT FOR BIT DRLG 12-1/4" @ 9700' MW: 9.7 VIS: 50 TRIP OUT. CHANGE BHA & ORIENT MOTOR. TRIP IN TO SHOE (P/U DRILL PIPE). TEST MWD. COND TRIP IN (REAM 90' TO BTM). DRLG F / 8828' T/ 9700'. DRLG. MW: 9.8 VIS: 48 DRLG TO 9623'. (STARTED SEEING SHALE STRINGERS @9620'). TRIP OUT, PULL WEAR RING. TEST BOPE, REINSTALL WEAR RING. P/U BHA & ORIENT MTR. TRIP IN TO SHOE. CUT DRLG LINE. SERVICE RIG. TEST MWD. TRIP IN (WASH LAST 85' TO BTM=NO FILL). DRLG TO 10239'. DRLG. MW: 9.8 VIS: 58 DRLG TO 10589'. SHORT TRIP TO 9565'. DRLG TO 11100'. RECEIVED OV - '1 .& Gas Cons. ~;omlnjsstor, Anchorage WELL : MPI 2-66 OPERATION: RIG : DOYON 15 08/07/93 (14) TD:11590' ( 490) 08/08/93 (15) TD:11952'( 362) 08/09/93 (16) TD:12177' ( 225) 08/10/93 (17) TD:12515'( 338) DRLG TUFFS FORMATION MW: 9.9 VIS: 50 DRLG TO 11576'MD = TOP OF TUFFS FORMATION. CIRC 50BBL VIS SWEEP. REAM & BACK REAM F/11576 - 10227 TILL CLEAN. TRIP OUT. CHANGE BHA. TRIP IN TO 2700'. TEST MWD. TRIP IN WASH LAST 106' TO BTM. DRILG TUFFS FORMATION TO 11590'MD. TRIP OUT FOR BIT MW:10.3 VIS: 54 DRLG TUFFS TO 11952'MD (POH BIT HIGH TORQUE). TRIP OUT FOR BIT & BHA. TOP OF TUFFS FORMATION=11656'MD RIH. MW:10.4 VIS: 64 BACKREAM TO 11384'. RIH. DRLG TO 12117'. CBU. POOH. CHANGE BHA. RIH. DRLG. DRLG TO 12515'. MW:10.4 VIS: 73 08/11/93 (18) TD:12762'( 247) 08/12/93 (19) TD:12762' ( 0) 08/13/93 (20) TD:12762' ( 0) 08/14/93 (21) TD:12762'( 0) 08/15/93 (22) TD:12762'( 0) 08/16/93 (23) TD:12762' ( 0) POOH. MW:10.3 VIS: 53 SHORT TRIP TO 11656'. DRLG F/ 12515'-12666'. CBU. DRLG TO 12762'. DROP IN PRESSURE. CIRC. POOH WET. POOH. MW:10.3 VIS: 56 POOH. BHA PARTED TOP OF STAB BELOW JARS. TETST BOPE. RIH W/ FTA 91. REAM F/ 12503'-12564'. CIRC. REAM TO 12574'. POOH. POOH. MW:10.3 VIS: 68 POOH. L/D FTA #1. RIH W/ FTA ~2. WASH DN TO FISH @ 12583'. POOH WET. NO FISH. RIH W/ GRAPPLE, SPEAR. WASH DN TO FISH. JAR. POOH. TRIP OUT F/ 0 S GRAPPLE MW:10.4 VIS: 56 TRIP OUT. L/D SPEAR ASSY, P/U MILL SHOE ASSY. TRIP IN TO 2645' CUT DRILL LINE. TRIP IN. MILL FISHING NECK ON TOP STAB ~ISH. CIRC & COND HOLE FLUID. TRIP OUT L/D SHOE & TOP SUB, P/U OVERSHOT BOWL BHA. TRIP IN. WORK OVER TOP OF FISH. TRIP OUT FOR FISHING GRAPPLE. TRIP OUT MW:10.4 VIS: 55 TRIP OUT FOR OVERSHOT GRAPPLE. TRIP IN TO 2645'. CUT DRILL LINE. TRIP IN TO 12583'. UNABLE TO LATCH ONTO FISH W/ OVERSHOT. CIRC & COND HOLE FOR SIDETRACK JOB. TRIP OUT & L/D DC'S & FISHING TOOLS. TRIP IN W/ OPEN ENDED DRILL PIPE. TRIP OUT. TRIP OUT F/ BHA MW:10.3 VIS: 49 TRIP OUT & L/D CMT TOOLS. TEST BOPE. CUT DRILL LINE. W.O.C., SERVICE RIG & TOP DRIVE. P/U BHA. TRIP IN TO 2871'. TEST MWD. TRIP IN TO 11100'. WASH DOWN TO 11343'. CIRC & COND. TEST NEW MWD. TRIP OUT FOR SIDE TRACK BHA. WELL : MPI 2-66 OPERATION: RIG : DOYON 15 PAGE: 4 08/17/93 (24) TD:12762' ( 0) 08/18/93 (25) TD:11391' ( 0) 08/19/93 (26) TD: 11100' ( 0) 08/20/93 (27) TD:11259'( 159) 08/21/93 (28) TD:ll187'( 0) KICKING OFF MW:10.3 VIS: 56 POOH. P/UMUD MOTOR, CHANGE MWD, MOVE STAB, ORIENT. SERVICE RIG, RUN IN HOLE TO 2871. TEST MWD TOOL. RIH TO 11343. DRILLING & SURVEY FROM 11343 TO 11345.LOST POWER TO RIG, BLOWN BREAKER IN SCR ROOM. REPAIR & INSPECT SCR. REORIENT MWD, RESUME DRILLING FROM 11345. TIMED DRILLING 3 MNUTES/INCH. DRILLED FROM 11345 TO 11353, STACKED 800009 WOB, PICKED UP DRILL STRING, SLACKED OFF TO 11358(WITHOUT PUMPS RUNNING). RESUMED TIMED DRILLING. KICKING OFF MW:10.3 VIS: 60 ATTEMPTING TO KICK OFF, TIMED DRILLING FROM 11361 TO 11391. CEMENT CUTTINGS OF SOFT QUALITY. UNLESS MARKED INCREASE IN CUTTINGS RIG TEAM IS READY TO SET ANOTHER CEMENT PLUB. W.O.C. MW:10.3 VIS: 56 DRLD/SLIDE CEMENT PLUB FROM 10391 TO 11400. NO CHANGE IN SHALE FORMATION. DISCONTINUED ATTEMPT ON SIDETRACK 91. DRILLED & ROTATED FROM 11400 TO 11450. CIRC. POOH. PU 3 1/2" MULE SHOE, RIH. CUT DRILLING LINE. RIN TO 11450, TAG BOTTOM. CIRC. BATCH MIX 400 SC CL G CEMENT. CIRC HOLE WHILE BATCH MIXING. TEST LINES TO 3500 PSI, PUMP 40 BBLS, PUMP 4 BBLS BEHIND CEMENT. POOH 10 STDS. CIRC. POOH. BEGIN SIDETRACK. MW:10.4 VIS: 64 POOHoL/D CMT TOOLS. WOC. RIH W/ BHA. CIRC. TAG CMT @ 11144'. DRLG CMT F/ 11144'-11149' CBU. POOH. RIH W/ BIT, MTR. BEGIN SIDETRACK F/ 1114~'-11156'. DRLG TO 11259'. KICKING OFF KICKING OFF FROM 11152 TO 11187 MW:10.4 VIS: 55 08/22/93 (29) TD:11300'( 113) DRILLING SIDETRACK DRIL FROM 11187 TO 11300. MW:10.4 VIS: 55 08/23/93 (30) TD:11442'( 142) 08/24/93 (31) TD:l1580'( 138) 08/25/93 (32) TD:11777' ( 197) RUNNING IN HOLE MW:10.4 VIS: 66 DRILLING FROM 11300 TO 11442. CBU. POOH. LAY DOWN BHA. TEST BOPE. P/U BHA. R.I.H. DRILLING MW:10.4 VIS: 54 RIH TO 2871. SERVICE RIG, TEST MWD. RIN TO 11442. DRILLING. TRIP FOR BIT MW:10.3 VIS: 59 DRILLED FROM 11580 TO 11777'. CIRCULATE IN PREPARATION FOR TRIP. ~, :k.~f'~ Anchor WELL : MPI 2-66 OPERATION: RIG : DOYON 15 PAGE: 5 08/26/93 (33) TD:11943' ( 166) 08/27/93 (34) TD:12262' ( 319) 08/28/93 (35) TD:12416'( 154) 08/29/93 (36) TD:12666'( 250) DRLG. MW:10.3 VIS: 57 CBU. POOH. CHANGE MWD, BIT. RIH. WASH BTM 110'. DRLG F/ 11777'-11943'. DRILLING @ 12262' MW:10.3 VIS: 56 DRILLED FROM 11943-12118'. MADE STAND SHORT TRIP CIRCULATE PRIOR TO SHORT TRIP. SHORT TRIP F/12118-110701' WASHED THRU TIGHT SPOTS @ 11808' & 11561'. DRILLED F/12118-12262'. DRILLING AT 12416' MW:10.4 VIS: 62 DRILLED TO 12411'. CIRC BTMS UP FOR TRIP. TRIP FOR BHA CHANGE. REPAIRED BROKEDN BOLT IN TOP DIRVE. CHANGE BHA. RIH. DRLG TO 12416'. POOH. DRLG F/ 12564'-12666'. CBU. POOH. MW:10.4 VIS: 59 08/30/93 (37) TD:12735'( 69) 08/31/93 (38) TD:12891'( 156) 09/01/93 (39) TD: 12923' ( 32) 09/02/93 (40) TD:13018' ( 95) 09/03/93 (41) TD:13040' ( '22) 09/04/93 (42) TD:13063'( 23) 09/05/93 (43) TD:13138'( 75) DRLG. MW:10.3 VIS: 58 POOH. CHANGE BHA. RIH. REAM F/ 11886'-12665'. CIRC. DRLG F/ 12666'-12735'. POOH. MW:10.3 VIS: 50 DRLG F/ 12735'-12859'. SHORT TRIP 10 STDS. DRLG F/ 12859'-12891'. CIRC. POOH. DRLG 12-1/4" MW:10.4 VIS: 52 TRIP OUT (BACKREAM TH). TEST BOPE. M/U BHA. TRIP IN TO 2000'. TEST MWD. TRIP IN TO 12820. WASH TO BTM. DRLG TO 12923' MD. CIRC.XANVIS SWEEP MW:10.3 VIS: 55 DRLG TO 12955'. SHORT TRIP TO 10470. DRLG TO 13018'. CIRC HI VIS SWEEP. DRLG 12-1/4" HOLE MW:10.4 VIS: 48 CIRC. TRIP OUT. RIG REPAIR. P/U BHA (N/D BIT & TURBO MTR). TRIP IN TO SHOE. CUT DRLG LINE. TEST MWD & MT. TRIP IN TO 12935. WASH 83' TO BTM. WASH & BREAK IN BIT. DRILG TO 13040'. DRLG 12-1/4" MW:10.3 VIS: 47 DRLG TO 13036 TRIP OUT (TH PUMP & BACK REAM OUT). L/D BHA #19. TRIP IN W/BHA#20 TO 2600'. TEST MWD. TRIP IN TO 12982'. WASH 54' TO BTM @ 13036'~ DRLG TO 13063'. DRLG 12-1/4" HOLE MW:10.4 VIS: 50 DRLG TO 13080'. SHORT TRIP TO 10351'. DRLG TO 13138 ov - 1 199: A]ask~. Oil & Gas Gons, Gomm'issiOf~ Anchorags WELL : MPI 2-66 OPERATION: RIG : DOYON 15 PAGE: 6 09/06/93 (44) TD:13224'( 86) DRLG 12-1/4" MW:10.3 VIS: 54 DRLG TO 13161'. SHORT TRIP TO 12305'. DRLG TO 13224. 09/07/93 (45) TD:13225'( 1) 09/08/93 (46) TD:13263' ( 38) 09/09/93 (47) TD:13297' ( 34) 09/10/93 (48) TD:13398' ( 101) 09/11/93 (49) TD:13516' ( 118) TRIP OUT W/ LWD MW:10.3 VIS: 56 DRLG F/13224' T/13225' (PREP TO PULL FOR BIT & SPERRY SUN LWD) DROP SURVEY. TRIP OUT (L/D MWD, P/U LWD & R/R 916 BIT). TEST LWD AT SURFACE. TRIP IN TO 2750'. CUT DRILL LINE. TRIP IN W/LWD. MAD LOG FROM 12287' TO 13225' MD. CIRC HI VIS SWEEP. TRIP OUT. DRLG 12-1/4" MW:10.4 VIS: 49 TRIP OUT, UNLOAD DATA FROM LWD TOOL. TEST BOPE. P/U BHA TRIP IN TO 1500'. TRIP TO 13200' WASH LAST 25' TO BTM, BREAK IN BIT. DRLG TO 13263'. DRLG. MW:10.4 VIS: 48 DRLG TO 13270'_ SHORT TRIP TO 12319'. DRLG TO 13277'. POOH. CHANGE BIT. RIH. WASH TO BTM. DRLG F/ 13277'-13297'. DRILLING 12-1/4" MW:10.4 VIS: 54 DRLG F/13297' T/13398. SHORT TRIP TO 10629' (PULLED ROUGH TO 11362' TAKING 55K OVER STRING). DRILG TO 13398'. DRLG 12-1/4" MW:10.4 VIS: 56 DRLG TO 13469' SHORT TRIP TO 12550'. DRLG TO 13516'. 09/12/93 (50) TD:13522'( 6) 09/13/93 (51) TD:13522' ( 0) 09/14/93 (52) TD:13635' ( 113) 09/15/93 (53) TD:13698' ( 63) 09/16/93 (54) TD:13936'( 238) RUN 9-5/8" CSG MW:10.4 VIS: 54 DRLG TO 13522'. SHORT TRIP. CIRC. TRIP OUT. TEST RAM. RUN 9-5/8" CASING. P/U 8-1/2" BHA MW:10.2 VIS: 52 RUN CSG 9-5/8". CIRC PUMP 20 BBLS PREFLUSH, 50 BBL SPACER 507 BBLS LEAD 6MT, 81 BBLS TAIL CMT. DISPLACE W/991 BBLS MUD, BUMP PLUG. INSTALL PACKOFF & TEST BOPE. M/U 8-1/2" BHA & TRIP IN. DRLG. MW: 9.5 VIS: 58 RIH. TEST CSG. OK. DRLG FC, CMT. CIRC. DRLG CMT, FS, 10' NEW HOLE. FIT (10 PPG EMW). DRLG TO 13635'. DRILLING MW: 9.5 VIS: 60 DRILLING TO 13695'. DROP SINGLE-SHOT SURVEY (NO AZIMUTH). ROUND TRIP FOR BIT CHANGE. DRILLING TO 13698'. POOH MW: 9.5 VIS: 49 DRILLING 13698-13936'. CBU. DROP SINGLE-SHOT SURVEY. POOH FOR BIT & BHA CHANGE. RECEIVED .Alaska Oil & 6as Oons. Anchorage WELL : MPI 2-66 OPERAT I ON: RIG : DOYON 15 PAGE: 7 09/17/93 (55) TD:14100' ( 164) 09/18/93 (56) TD:14295' ( 195) 09/19/93 (57) TD:14331'( 36) 09/20/93 (58) TD:14455'( 124) 09/21/93 (59) TD:14595' ( 140) 09/22/93 (60) TD: 14940' ( 345) 09/23/93 (61) TD:14940'( 0) 09/24/93 (62) TD:15045' ( 105) 09/25/93 (63) TD:15203'( 158) 09/26/93 (64) TD:15203'( 0) DRILLING MW: 9.4 VIS: 48 ROUND TRIP TO PICK UP TRIPLE COMBO LOGGING ASS'Y (INTEQ). NO HOLE PROBLEMS DURING TRIP. DRILLING. DRLG. MW: 9.4 VIS: 51 DRLG F/ 14100'-14118'. SHORT TRIP TO SHOE. DRLG F/ 14118'-14295'. POOH. MW: 9.4 VIS: 55 DRLG F/ 14295'-i4331'. CBU. POOH. SURVEY DOWN . MAD RUN F/ 13950'-14331'. CBU. POOH. DRILLING MW: 9.5 VIS: 50 POOH. CHANGE BIT, BHA. RIH, REAMING TO BOTTOM. DRILLING 14331'-14455'. DRLG. MW: 9.5 VIS: 52 DRLG F/ 14455'-14549'. CIRC. POOH FOR WASHOUT. FOUND 18-2/3 STDS OUT. REPLACE. RIH. DRLG F/ 14549'-14585'. CIRC. DRLG F/ 14585'-14595'. POOH MW: 9.6 VIS: 53 DRILLING 14595'-14778'. POOH. R/U. RIH. DRILLING 14778'-14940'. POOH, MWD CHECK, BOP TESTS & NRS INSTALLATION. CIRC. DROP SINGLE-SHOT SURVEY. POOH SLM. RIH. MW: 9.6 VIS: 64 POOH. REPAIR MWD. TEST BOPE. P/U BHA, BIT. RIH. DRLG. MW: 9.6 VIS: 59 RIH. TEST BOPE. RIH TO 14550'. MAD LOG RUN F/ 14550'-14940'. DRLG F! 14940'-15045'. CIRC. MW: 9.7 VIS: 57 DRLG F/ 15045'-15128'. P[OOH 42 STDS FOR WASHOUT. DRLG F/ 15128'-15203'. TD WELL @ 00:30 HRS, 9/25/93. CIRC. SHORT TRIP TO 13496'. CIRC. POOH. MW: 9.8 VIS: 59 CBU. POOH TIGHT. WASH & REAM TIGHT SPOTS. CIRC. POOH. 09/27/93 (65) TD:15203'( 0) RIH. MW: 9.8 VIS: 78 POOH. R/U SWS. RUN RFT/GR. LOG RUN: DIL/GR/CNL/LDT. R/D SWS. RIH. ..,.R ECE IV NOV -,- '! Alaska Oil & t~as Cons. ~or~m~,ssi°~'~ Anchorage WELL : MPI 2-66 OPERATION: RIG : DOYON 15 09/28/93 (66) TD:15203 PB: 0 09/29/93 (67) TD:15203 PB: 0 POOH. MW: 9.7 WBM RIH TO 13357'. DROP HOWCO TEMP PROBE. CIRC. RIH TO 15083' REAM TO BTM. CBU. SHORT TRIP TO CSG SHOE. CIRC. RIH. ~IRC. POOH. CIRC. MW: 9.8 WBM POOH. L/D BHA. RIH W/ 7" 13CR LNR ON DP. CIRC. RIH W/ LNR. CIRC @ SHOE. RIH W/ LNR TO BTM. CIRC. 09/30/93 (68) TD:15203 PB: 0 10/01/93 (69) TD:15203 PB:15179 10/02/93 (70) TD:15203 PB:15179 RIH. MW: 9.8 WBM CIRC. R/U HOWCO. PUMP SUPERFLUSH, 158 BBLS (770 SX) 15.8 PPG CMT. DISP W/ MUD. BUMP PLUG W/ 3500 PSI. RELEASE F/ HGR. POOH 10 STDS. CIRC. POOH. RIH W/ BIT, CSG SCRAPER. CLEAN OUT CMT TO TOL @ 13199'. TEST CSG, LNR LAP. CBU. POOH. RIH W/ BIT. POOH. MW: 9.9 NaCl RIH. CLEAN OUT CMT F/ 13498'-13593'. RIH. DRLG CMT F/ 15055'-15179' TEST LNR. DISP WELL TO BRINE. TEST LNR. OK. REV CIRC] POOH, L/D DP. RIG RELEASED. MW: 9.9 NaC1 POOH. DISP 105 BBLS DIESEL F/P TO 1500'. POOH. INSTALL TBG HGR. N/D BOPE. N/U TREE. TEST TREE. SECURE WELL. RIG RELEASED @ 20:30 HRS, 10/1/93. MOVE. SIGNATURE: (drilling superintendent) DATE: NOV '" Alaska Oi~ & (las Cons, Anchorage Baker Hughes INTEQ Anchorage, Alaska BP Exploration WELL Field Borough STATE DATE Country Survey Performed By : 2-66/SD-12 : ENDICOTT MAIN PRODUCTION ISLAND : North Slope : Alaska : 29 Sept 93 : U.S.A. : Rodney St. Pierre FIICROFILHED RECEIVED NOV - '~ 199~ A~aska Oil & Gas Cons. oummissio~'~ Anchorage ~his survey is correct to the best of my knowledge and is supported by actlI~l field data;~,~ lille' e~ COMPANY REPRESENTATIVE Client WELL Field Borough STATE Baker Hughes INTEQ : BP Exploration : 2-66/SD-12 : ENDICOTT MAIN PRODUCTION ISLAND : North Slope : Alaska Date 29 Sept 93 Filename : 1242 No Interpolation Plane of Vertical Section : 234.0° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.24°WELLSITE North Grid convergence : +0.0000° +0° 0' 0"' (T) RECE[VED NOV - 1 199; Alaska Oil & (~as Cons. ~,ummissio~" Anchorags Client WELL Field Borough STATE Baker Hughes : BP Exploration : 2-66/SD-12 : ENDICOTT MAIN PRODUCTION : North Slope : Alaska MD C~L INC DIR TVD ft ft deg deg ft 13490 0 38.3 244.0 10067.75 13531 41 37.8 245.9 10100.05 13590 59 37.7 245.9 10146.70 13682 92 37.5 246.6 10219.59 13773 91 38.1 248.0 10291.50 13866 93 38.6 248.0 10364.43 13885 19 38.8 248.0 10379.26 13959 74 38.4 248.7 10436.74 14087 128 36.7 249.4 10538.57 14183 96 34.9 249.8 10616.43 14237 54 33.9 250.5 10660.99 14333 96 32.4 250.8 10741.36 14409 76 31.0 251.2 10806.02 14523 114 30.3 251.9 10904.09 14619 96 29.4 253.3 10987.36 14708 89 28.7 252'.6 11065.16 14903 195 28.4 255.8 11236.46 15001 98 26.7 254.7 11323.34 15094 93 25.5 256.8 11406.86 15121 27 25.2 255.8 11431.26 15203 82 25.2 255.8 11505.46 ISLAND INTEQ VS ft 8215.84 8240.64 8275.98 8330.83 8385.11 8441.10 8452.63 8497.08 8572.68 8626.76 8656.07 8706.36 8744.55 8799.96 8845.2'5 8886.12 8973.56 9015.80 9053.80 9064.50 9096.91 Page 1 of 1 Date 29 Sept 93 Filename : 1242 No Interpolation LAT DEP D'LEG ft ft °/100 -4851.25 -6630.70 0.00 -4861.94 -6653.58 3.06 -4876.69 -6686.55 0.17 -4899.30 -6737.93 0.51 -4920.82 -6789.38 1.15 -4942.44 -6842.88 0.54 -4946.88 -6853.90 1.05 -4963.81 -6896.54 0.81 -4991.81 -6969.65 1.36 -5011.39 -7022.28 1.89 -5021.75 -7050.97 1.99 -5039.15 -7100.50 1.57 -5052.15 -7138.26 1.86 -5070.55 -7193.38 0.69 -5084.84 -7238.97 1.19 -5097.51 -7280.29 0.87 -5122.89 -7369.93 0.80 -5134.42 -7413.77 1.81 -5144.50 -7453.41 1.63 -5147.24 -7464.64 1.94 -5155.81 -7498.49 0.00 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 9100 ft 235.5° REC£ V D N0V - 1 199 A)aska Oi~ & Gas Cons. Anchorage ********* S~HiUMBER~E~ ********************************************************** NELL N~E 2-6~/S~-t2 LOCATION 1 MPIrENDICOTT LOCATION 2 NEBrALASkA MA~N3~t~ DECLINATION 30,43 DATE: 2~-AUG-¥~ WELL NUMBER 0 WELL HEAD ~CATION: LAT(N/-S) 0.00 AZIMUTH FROM RO~AF,~ TABLE ~0 TARGEi IS TIE IN PGINT(TIP) : MEASURED DEPTH TRu= V£.,~ DE?TH 1NCL!NA?iON AZIMUTH LATITUD£(N/-S) DEF'ARTUR~(E/-W) 1!053.14 8247,56 46,20 231,70 -5210,71 234,06 RECEIVED $.EP l ? 1993 ,~-'daska Oil & Gas Co,s. ,-.~~..=,- ft ft fz 11137 "" .. 8.~..._., ! F. i !lP.,O,70 43,5 8325,?. 11~1,92 5!,2 837: 1i~3,77 1!542,90 11413,50 11781,69 11964,89 12236,48 1240~,5& 12441,90 12506,19 12591,20 128,93,01 I27~.~,7,~ 12274,66 12950,41 I306~,59 !3225,00 S~CTiG~ IN~.~N. N/-S :./-W it ~e~ deg i~ it ft ,., ..... . ,~. 254,08 -4156,80 -5265,90 6753,7i 43,7t 2~,01 -~?A-~:~...... -~i;'.. _,....z~ 67s~,%.__ , ~z~ ~ 43,70 232,94 -52!~ ..... .,,. .... 2, -~163,55 ~45 AFAT.47 7?,4 8437,0~' !9,! ~450,31 70,6 6498,14' 92,4 8559,55 87,4 8615,2I ~io,:: 45,89 235,37 -4215,92 -5365,i2 6~23,3~ 6- ,. ac:,':l 46,19 236.82 -42~2,60 -5376,55 6~37.!! 6853,74 46,40 239.68 -425~,87 "~20,66 6865,65 6952,~ 4~,43 23~,62 -4235.80 -5460,33 69~.!7 7017,05 47,25 2.,%.',33 -4318,70 -5536,14 702i,40 94,4 86~3,55 94,0 8750~72 ,v,: G8('4,75 90,9 ~951,57 7064,74 45,15 241,65 -4352,28 -5595,41 7068.7? 7149,81 43,55 242.08 -43S3.25 -5653.32 7153,53 7212,53 42,~8 243,4~. , -4412,28 -5709,75 'm~'/.~5,~ 7273,10 42,62 244,i0 -443~,41 -5764,89 7276,15 7323,70 42,7? 245,22 -4465,76 -582~,65 7336,4! 180,7 9083,?4 93.8 9152,54 7~.2 9209,~3 33,3 9234,50 ~),q ~7~ ~ 7453,85 42,98 247,27 -4515,18'_~JJ,21~"'~" .~:,~..~' ~l 7516,10 43,06 247,91 -4539.59 -5992,40 7517,77 7567,73 42,78 246,79 -4559,25 -604~,93 7569,12 7589,46 41,74 247,77 -4567,54 %062,75 7590,75 7626,62 40,16 247,32 -4552,!3 -609~,07 7627,74 91,0 44o. 101,5 9429,85' 90,7 95Q2,60 4!,5 9535,92 49,4 9575,47 7682.90 36,05 243,26 7744,12 37,00 ~" ._ .4~,17 -4634,02 -62~s,56 7744,89 7797,74 36,52 243,15 -4658,55 -6254,03 7798.39 7~22,21 36,73 242,$0 -4669,60 -6276,10 7622,82 ~ASl,44 36,~4 242,77 -46~3,.53 .~n ...... ~, , 75,7 9636,4i IA,5 ' TM 93,7 9'727,!9 7895,b~, ~b,O~ 243,50 -4703,66 %342,52 7896,32 7906.56 35,95 243,73 '47t~,48 ~ ~' ~O7,Al 7960,85 2~,92 242,32 -4~,41 '6401,23 7~61,Zi THS FINA~ ~n ...... IS . . ' ~u,.v:~ PROJSCi£D TO iOTAL DS?TH LOCG£n WiTH MWD, ..,.,;qx~ ~ 9856,76 60SS,l~,.. 35,90 242,30 -~?77,x?.. . ., -6455,60 8055,J)~m'''' AZiMU% Oeo.-'" deo lOOft 23!,~r. 231,8{, I --- ~Q ,m ~-, 22i,~5 5,~,~, 231,90 4,32 231,97 0,06 232,04 1,37 232.12 2,65 232,2i 1,73 ~Jz,3.~ 1,27 232,40 0.54 232,50 232,73 0,74 232,~..5 0,47 "'"' ?A O,A'~ $-C,£, . ,.-- 232.01 3,75 233,0e, 2,72 233,17 3,66 :.~',3,2., 1,03 232,32 0,55 233,35 0,7i 233,28) 0,24 233,44 1,22 232.45 2~,:,.: 0,88 233,62 0,02 SEP 1 7 1°,qq ~:,..taska Oli& L~as t;.' '. .......... ~ELL N~E LG&ATI~4 1 ~Pi~ENDiCOT? H~NEIIC DECLINATION 30,43 24-JUL-g3 WELL NUMBEP. 0 WELL HEAD LOCATION; LA~,N/-S~ 0,00 DEP(E/-W) o.00 AZI~JTH FRDN ROTARY TABLE TO TARD.~ I2 234,10 TIE IN POINT(TIP) ~ASURED DEPTH 100,00 TRUE '~RT DEPTH INCLINATION AZIMUTH 0,00 LATiTUD£(N/-S) 0.00 DEPAF~URE(~/-W) O,O0 RECF Vrr SEP ! ? 19'qq ~Jask~ O~ & 6a~ ~,,. ~ASURHD INTZRVAi VE~?iCAZ ft ft ft 100.00 0.0 I00.00 2£Z,10 i22,1 222,i0 522;00 299.9 5~1,91 6B0,00 158,0 679,71 ~07.00 t27.0 806,49 903,00 108!.43 ~7~ I2 1366,23 1459,75 1554,25 1649,47 174o~ 1844,00 1940,24 2033,I4 2126,76 2220,92 2316,36 2412,31 250~,16 260~,3E 26~7.60 2612,54 2962,42 )377,11 326~,07 3364,6~ 345!,00 3549.93 3643,43 3741,60 3840,12 3935.56 4030,52 4127,37 ~.~, ~ ,. 96.0 %'.5 93,7 1173.67 92..B 1267.17 97,3 1363,99 93,5 1456,80 94,5 1550,03 95,2 i643,21 96,7 1737,07 97,8 1830,91 96,2 9~,9 2~7,8! 93,6 2092,27 94,2 ~ 7 =1.5,01 95,4 2257,60 95,9 2340,50 95,~ 2423,14 94,2 2503,89 95,2 2585°40 114,9 2684,i2 I69,9 2830,67 94,7 2912,29 95,8 2993,45 95,2 3072,91 96,6 2153.31 86,3 3224.70 98,9 3304.$~ 93,5 3378,32 ~,~ 3453,94 98,5 352~.26 95,4 2'597.35 95,0 3662,65 96,9 5727.73 95,0 ~ n~ ~,! TARGE~ STAT]O~ AZIMUTH LAT]TUDZ SECTION IN~. N,.-~ ft deo deg ft 0,00 0.00 0,00 0,00 0,17 O,lS !99,70 -0,19 6,~ 2,40 236,!0 -3,98 ~,~v 243,60 -1.75 22,02 3,50 245.60 -!0,97 28.0? 4.0~ 252.10 '13.2i 33,28 3.97 253,~ ' -~4,~2 40.i6 4,25 244,00 47.27 4.56 242,~ 54,93 4,~7 23~,76 '24.40 64,4~ 6,45 2~.45 -29,24 75,89 7,75 245.~ -~,4~ 91,01 10,97 244,21 -4!,09 110,34 I2,70 240,52 133.52 15,13 235,70 -62,53 161,16 17,70 2~.00 -78,26 192,78 20,67 234,55 227.~3 23.68 233,90 -117,0! 268,19 27.39 233.49 -140,91 313,12 29,62 234,28 -167,3~ 360,96 30,55 234,63 -195.20 409.24 29,89 235,75 -22~,.77 457,7? 31,00 235+31 -250,26 5~,,33 31,03 236,06 -277.63 555,53 31.21 234,27 -305,74 614,39 30,4I 2~,76 -339.50 700,2~ 30,34 234,94 -388.25 748,27 30,56 233,99 -416,24 799,10 33,56 232,97 -446.50 851,52 33,27 233.51 -477..88 9¢5,08 S4.O~ """ ~' 953,59 34,~' 234.52 -538,56 1011,46 37,29 234.53 -572,15 1069,3? ~ ~. -. ~¥.~o 233,73 -606,09 1131.98 39,99 234,17 -642,93 1196,65 4~,v/ ~.,:;,t~ -6qI,29 -, ~ ~.~. ~,. .. 1262.39 45,16 .~^ i5 ~v. '722,I9 1331,]~ 47,9A '~q r, 45 · ... Z.~.Ou -766, 1~):.,.~ ~.55 . .22 .... ' '- -c~z. Y6 1472,62 47,23 ~z.1. '~55.32 l~/ ft ft 0.00 0,00 "g, g."" _ + _,... -!2.45 14.6E. ~,-. ,eq. 4..' de~ lO0~t 0.00 O.O0 1%,70 0,16 234.46 0.75 240,3~ -25,1i 2~.37 242.24 0,68 -30.55 33,76 242 "' 0.15 -36,9~ 40,57 244,80 0,76 -43.4~ 4c.~., 244,59 0,34 '~,', 55.77 244,06 0,49 -~,.44 65,24 245,42 1,63 -6B,73 76,89 243,~ 1,52 -82,61 ~,26 243,55 3+4! -99,8~ 1II.7E 243,32 1,98 -!!?.57 134,93 242,39 2,7~ -!42,30 162,40 241,I9 2,64 -168,12 193,85 240,I4 3,09 -196,~, 22~,75 239,23 3,26 -229,07 2&~.94 238,40 3,97 -265,38 313,76 237.76 2,39 -304,31 361,53 -343,95 409,79 -383,99 45~,34 -424.09 506,8t -464,48 5~,08 237,32 0,99 237,07 0,91 236,91 1,18 236,79 0,41 236+65 0.99 -512,71 614,93 236,49 0,96 -583,S? 700 ~" ,~ 2~.35 0.25 -622,44 745,7~' 236.23 0,56. -663.27 799,56 236,05 3,I7 -705,27 ~51,93 .... z:,5,6b 0,43 -748,21 -787,36 953,93 -834,4? 1011,79 -8~1,41 1069,66 -932.03 I!32,27 235,73 0,67 235,63 1,00 29J,56 3,00 235,4~ 2,17 235,40 -984, n? * ~6,9~ 225 "' '1035.65 12~=,59 ' ~ ~l ~ ,p -1055,59 !331,2~ 234.~5 2,97 '114~.915 !402.8.2 2C~.63 1,04 -119~.81 1472,65 234,4? 0,7~ RECEIVEP SEP 1 7 1993 Anchorag," · -- a.r~ ~, .~r~, vrt~ DE;'T~ · .. '..,~!-: n f: ft 4~!5,~.3 9/..,,22920,12 4.-.4n ~ 94,3 3979,2? 4604.S6 94.2 4057,90 ~"'"' ~' *"q R . _ 4..,..-:,, ~ ;~,,: 4793.62 5079,7.1 5175,03 5270,11 5365.71 5461,3.~. 5555.37 56.51 ,B2 5749,90 5641,66 5937,89 6035.35 6!30,42 6224.36 6317,09 64!4.46 6479.75 6679,93 6i 7/, 4 6A..72,E5 6967,29 7063,~ 7253.46 7350,37 7444,54 7539,96 7632,95 772~.71 7~22,25 7918.16 6015.75 tE .-~ 95.5 5'5,5 4217,85 95.1 '5.~,~. _, 4340.07 95,3 4401,25 95,1 4462,45 95.6 4524,52 95,7 45&6+77 94.0 4647,60 96,5 4705'.8~ 98,1 4772.99 91.6 4&31,79 96,2 4693,91 ~7.5 4957,35 95,1 5019,70 94.0 50~!,98 92,7 5143+79 97,4 5205.~ ~,3 5252.77 104,2 5322,51 95,9 5386,51 97,7 5451,57 95.2 5515,16 94,4 5578,70 96,6 5644.04 94,4 570~,34 95,2 5773,67 96,? 5540,52 94,2 5905,B0 95,4 5972,44 ~.,0 6037,64 ~5..5 6104.U 93,5 6170,66 95,9 623f,17 97,6 6307,00 ......... ..o. ii~iH.~.~..-.~.~ TARGET ~TATION AZ!MUT~ LAT!TU~E SEC!iO~ INCL', ..... ~,-~ ft 6eq deg !5.~,46 46.05' 232.92 -E99.04 1617,51 50,76 232,~2 -945,15 1690.94 51,53 ~o:,~' ..... -957.~ i76~.69 51,52 235,~i -103!.59 i~s~.~,.,~.~5i,02 :o~.~ ..... -I075,24 .?-66157~- 1 ;' ft ft -1255.85 1544.~? -1314,i0 1617.52 -1372.62 !690.95 -!42i,77 17~.69 -!490.47 ....~ ' de.o/ deg !00ft 234,40 1.07 234,33 2,7~ 234.27 0.62 234.23 234.15 0,9! lv.x.77 50.54 231.47 -1120,56 19B5.2! 50.19 231.67 '1166.28 2058.21 50.!5 231.56 -1211.64 2i31,43 50.05 232.52 '1256.71 2204.45 50,05 232,09 '1301,5~ -I54~..92 19i!.77 -!&96.51 19~5.22 -1663.76 -1721,56 -,~-,, -1779,36 2204~47 234,!2 234,02 0.41 23~.94 2~..~, 0,.77. 2~2.e2 2277,18 49,82 ~ &: :~;..J -1345.80 2249,8e. 49,22 233,19 -1389.65 2422,51 4g.59 233.44 ~'. n. 2494.15 49,76 232,~9 -1475,95 2567,76 49,81 23i,56 -1521.01 -1636,98 2277,2! ~"~ ' ~:,~,7/ 0,5! -1~95,~ 2349,92 233.75 0.76 '1953,25 2422,56 233,73 0,43 -20!0.63 2474.21 ~A~.,;~ 0.40 -206~,88 2567.~3 233,6~ 1,i4 2642,76 50.09 231.~ -1567,82 2713,il ~',21 231,01 -1612,0! 2786,54 49,3~ 232.47 -1657,52 2&60,50 49,39 232,56 -1702,54 2932,23 48,65 232,12 -I746,39 -2!27,5& 2642.~5 233,61 0,35 -2162,45 2713,23 .... ~ ~ -2240,16 2786,70 233,50 1.44 '2298,B6 266~,67 233,4B 0,07 -2355,67 2932.42 232,45 0.84 3002,55 48.31 232,34 '1789,4~ 307!,60 46.07 231,69 -1~31,91 3!43,6~ 47,88 231.36 -!876,~1 3192,23 47,86 23!.55 3267.65 4~,16 232,46 -1954,67 -2411,29 3002.76 -2465,63 3071,84 -2522.55 3144,15 -2560,40 3192,52 -262i,45 3269,9~ 233,42 0,41 232.39 0,44 233.35 0.45 2L~.,32 0,21 233,25' 0,71 3341,1! 46,17 233,22 -!997,85 3413,94 4~,31 231,72 -2042,23 3484,78 47,91 231,50 -2066.26 3554,5) 47.52 231.30 -2i2~.B6 3625,56 47,33 230,25 -2174,~3 -2678.42 334!,46 -2736,20 3414.31 -2791.78 . 3465.18 -2846.3~ 3555,02 -2901,48 3626,G8 232,26 0,59 233,26 1,15 2~ ~ ~..~o 0,46 233,19 0,44 233.15 3694,56 46,8.3 229,90 -2219,21 3763,55 46,45 229,87 -2263,76 3033,53 46,34 229,6~ -23.99,10 3901,16 45, (~.~ 229,21 -2252,22 3969,22 4..., 5.;.229,35' -235'7,77 -2954.51 3695.13 233,09 0,59 -3007,42 U64.,2t 232.03 0.4! -3061.00 3834,27 232.97 0,1~ -3112.56 3902,01 232.9i 0,61 -3164,32 3970,!7 232.~5 0.37 4035.27 45.43 228.90 -2441,16 4!03,14. 45,39 .....w;'= r),... -~4~¢," "' , "jo 4169,26 45,~3 227,89 -2530,86 4~ 9o ~5,29 227 ~n o:~ Sc. .~.J, . ~ .. , .tV '~! .,,. / 4305,74 45,00 227.71 -2623,10 -~14.45 4036,3,3 232.79 0,26 -3265.52 4!04,2;4 232,71 0.6! -3314,92 4170.61 232,64 0,22 -~o~,,c, ~-~,~.,-,.~ ~",5~,~ . O,lO -3416.6~ 4307.45 232.49 0.31 RECEIVED SEP 1 7 1993 Alaska 0ii & Gas Cons. Anchorag,s ME~:E;UE!Z: £210,07 ~.307 ~496,S7 fl59'i ,14 ;E. oo4, y,., 89o6,5.6 900~, 9~, 9095,2! 9191.15 9287,22 9363,46 9475,21 9609,9'5 9669,76 9765,82 9661,76 10141,~. 10324,52 10417.26 1050~,74 10596,17 106~7,76 10779,70 10672~34 10962.29 11053,14 11146.99 11239,72 !133S,44 11424,76 11504.45 11590.97 I1665.56 i!775.12 9~,5 %,S 6444,5! 97.9 6513,81 9!,6 96,6 6647-32 "/~, .., A714,27 ~3,~ 67E.0,35 12E,,q Ac?r, 94,7 6956,53 95,6 7000,97 93,2 7060,60 95,? 71!9,63 96.1 7176,14 96,2 7231,93 91,7 72~3.60 !34,7 735B,09 59,8 7391+50 %,1 7445,71 95,9 7500,01 96.1 7554,6! o~,.,~n7607,59 90,2 7659,07 91,1 7711.69 92,4 7767.29 92,7 7625,73 91,5 76~4,41 87,4 7940,85 91,6 8000,16 91,9 ~v6'~.97 92,6 8!~,84 90,9 8245,04 95,8 ~Jl4,.z 90,7 637~,43 93,7 9k,3 6510,25 79,7 8567,66 66,5 663~,,46 94,6 8700,02 6S',6 ~766,67 S~.:UEY C~ ......... ............. ~.~. ARC S~C?IC% iNCLN? 4374.~5 .44.,60 2L7,94 -~669,7~ 4442,21 45,22 227J2 -27!5,27 4510.94 44.62 22~,49 -2761,42 45~5,26 45.00 226.~3 -2605.02 4642.92 44,90 226,50 -285i,64 E./-W ft ft -3~6~.17 4S76J5 -351S,40 4444.30 -~.56~.c4 45!3.23 -3617,6S 4577,74 -~67,31 4645,66 deo./ .~.~ ~ 232,4~ 0,26 232,34 0,47 · . ,o,z~ 226,77 -2~7,9! 4775,42 45.16 4~64,22 44,7'3 226,36. -3004,76 4931,~ 46,16 230 -37i6,0~ 47!2.44 -,-,- -3764,65 477~.69 231,96 0,21 -3~2~,~i 4667,~6 231,66 0,50 ~,~ ~9:5.!9 ~i.~4 3,37 -3735,60 5005,79 23i,S3 3,59 5073.36 51.12 232,29 -3136,P_5 5!49.13 '~" ~ ~.~...~, ~. 52,:..ol 54,70 ~4,72 -3~26,6. 5305,23 54,45 232,67 -~. o.04 53eo,e~ 56,69 232,34 -3519,10 -3992,39 ~77,30 231,~4 -4053,37 5!53,03 231,67 3,06 -4116,~4 5230,62 23t,91 1,52 J3gY,O0 2~,~4 1,75 -4240,07 5364,67 '~ '= . L~1,% 2,47 5493,18 56,35' 231.24 -3358,63 5541.74 55,71 231,44, -3419,63 .~,.. 55,58 . . tal,4~ -34Ag,Os 5700,9~ 55,46 231,76 '35i~,17 5779,99 55+29 231,22 -3567.42 -432~,40 -4367.14 5546.69 -442?,I5 5625,99 -4491,15 5705.06 -4553+04 5784,18 23i,94 0,72 23i,94 1,17 231,93 231,93 0,28 Zo~,92 0,51 5656,32 55,25 231,31 %615.24 5930,27 55,i2 231,33 -3661,51 6004,54 54,34 230,24 '3708,49 6076,09 51,61 227,9i -3755,75 6149,9S 50,26 230,2~ ~ ~ -~1,95 '46!2.65 5860,59 231.91 0,09 -4670,45 5934,.63 231,90 0+I4 '4726.13 6009,00 231,97 !,23 -47M,72 6082,70 ~ .... ' ~,~,.~ 2,98 -4639.96 6154.68 231~5 1,47 62i9.92 49,93 229.45 -3547,i9 ~.~,~ 49,65 230,79 -3~90,00 6356,20 49,61 23!,47 .-~933,79 6425,11 47,5~ 232,4~ '3976.27 6493,1! 46.97 230,98 -4016~42 -4693,62 6~24,6, 23! ,6.:: 0,79 -4944,85 6291.55 22,!,6! 1.21 -4999,16 6361,32 23!.6~ 0,57 '5053,49 64J0,~o ~.,~.~s~ ~. 2.36 ,.~.-,, ~., .~ =,v 1,36 655E,62 46,64 232,09 -4059,21 6624,~= ~= 46,20 231.68 6693,16 45,64 231.0~ -4142.~.Q 6757,67 45.16 231,01 -4163.41 682~.67 44,55 23!.04 -4224,9~ -515~,27 6563,91 231.80 -~lO,O5 662~,72 2ol,69 0,59 -5263.64 669~,57 23!.60 0,73 -5314,0~ 6763,17 23i,79 0,53 -5365,46 6629,26 221,76 0.65 6657,34 44.0! 231.2i -4265.0! 6942.54 4.,0~ 231,19 700i.97 43.06 23!,43 -4336,~3 706A,A2 ,~ ~ - ~ ,~,~0 232,51 -4376,~3 7125,84 41,m/ =~J,~., -44i2,1E '5415.I(: 67;'3,n' -5504,62 70(:7,7E, -5603,00 .... ~" 22!,7~ 0,60 221,77 0,24 23i,77 0,67 23i,7E 1,25 RE.CEIVED SEP 1 7 1993 ,::daska Oil & Gas Cons. (;u~'t't~'~,,,,~ ,..', Anchorag~ I,£PTH D£F'TH !!866,~0 9!,7 11954,2E 87.. ~ 2901.57 1205S.42 97,1 $975,57 12!~6.21 ~4,~ 904~.37 12234,15 67,? 9116,03 12420,6~, 96.2 9260,77 12511,07 90.4 93~!,7~ !2605,9E 94,9 94C,6.4~ 1269i,7! ~,~,~N AZIMUTH TARGET "~'~ .... SEC%lO~ IN3D4. f~ ~eg 6eg 71%.4! 4i,~' ~'~' ~ 7242,7~ 40,77 2~5,47 ....730A.~4 4O,0u 236.~,~= -40E,,47. 7567,30 39~63 Z35,97 7423,43 39.75 237,12 -455i,24 AZimUTH -~z~,~5 71~9.91 "' ..... -569~.56 7247.47 -575:~',6E 7312,25 231.85 ~ ¢ · --~- ~ ~ -,', ~Q ~- . ~,, .-. -~.,,9~' 742~,7E 7540,67 ~ '~ 240 ~ .~;' oo,Z~..- ,~. '4642,.. 7596,36 36,32 2~?,51 ~" ~ 7E54,63 37,95 2~0,94 77¢7,18 36,39 241,67 -4725,42 -576,4~ 7485,94 231.$7 '5945,!0 ~ 7~>,~.: 232.03 -5996,58 -,,., ,z -6047,45 765q,0S 232,15 -6092,92 7711.25 232 '~ DLS · I :~¢ C,,gE. i, 9,Z.i 1,0i 0,74 RECEIVED OEP 1 7 1993 AlaskaOii & Gas Cons...,.,..,i Anchorago No. 8235 SCHLUMBERGER GEOQUEST INTERPRETATION AND COMPUTING SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY · STATE OF ALASKA LOCATION · ALASKA OIL & GAS CONS. COMM. ATTENTION WELL NAME SERVICES · tARRY fl~ANT · 2-66/SD12 MPI -~ 587Z10H.~,~rS :, TAPE 1 RFT COPY TAPE NO. OF BOXES: JOB NO. · 93454 ADD'L TAPES · · DATE ' WELLNAME ' SERVICES · · NO. OF BOXES: JOB NO. · ADD'LTAPES · WELL NAME ' SERVICES · NO. OF BOXES: JOB NO. · ADD°L TAPES · WELL NAME ' SERVICES ' NO. OF BOXES: · JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: WELL NAME ' SERVICES ' NO. OF BOXES: JOB NO. · ADD'LTAPES · WELL NAME · SERVICES . · NO. OF BOXES: JOB NO. · ~ .... ADD'L TAPES · DATE DELIVERED: .~:,.:.... OCTOBER 29, 1993 RECEIVED BY: ..... BP EXPLORATION ALASKA INC. CORE SAMPLE TRANSMITTAL BP Exploration Alaska, Inc. c/o Document Storage Core Store 2410 E. 88th Ave. Anchorage, Alaska 99507 Attn: John Trautwein (907) 522-2684 TO: Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 AIRBILL #: CHARGE: WELL NAME: SAMPLE TYPE: NUMBER OFBOXE REFERENCE: AFE# 684875.1 Sag Delta 12 Dry cuffings 664751 DATE: 1016/93 2 TRANSMITTAL NC 1170 DESCRIPTION OF MATERIALS TRANSPORTED: Two cardboard boxes, containing 11 boxes of Washed and Dried Cuffings samples from Sag Delta 12. Depths within the 11 boxes are as follows: 12430-12760, 12640-12880, 12880-13210, 13210-13430. 13430-13670, 13670- 13940, 13940-14200, 14200-14500, 14500-14740, 14740-14940. 14940-15203. Please acknowledge receipt in whole of the material described above by signing this transrnitta returning a copy to the address shown above. ~ Sent by: Date: SCHLUMBERGER WELL SERVIC~ ~ION OF SCHLUMBERGER TECHNOLOGY O~. =ORATION HOUSTON. TEXAS 7725!-2175 PLEASE REPLY TO SEP 2 tt 1993 SC.LUMSERGE. WEL. SE.V,CES ?ouch 340069 ?rudhoe Bay, AK 9973/,-006! ittn: Bernie/Shelley BP Exploration 900 E. Benson Blvd., MB 3-3 Anchorage, AK 99519-6612 Attention; Petrotechnical Data Center Gentlemen: ~F'T Enclosed ore 2 B.L_prints of the Subse_.~._T,.V~ Log, RF--T, .L[~, Run 1, 9/26/93 Company BP Exploration Well 2-66/SD12 F{eld Endicog~ County North Slope Store Alaska 1BL prints, 1RFolded Sepia Amoco Production Company 200 W. 34th Avenue, Suite f76 Anchorage, AK 99503 Attn: Shirley A. Kuhr Additionolprintsore being sentto: ARGO Alaska, Inc. P. O. Box 100360 Anchorage? AK 99510-0360 Attn: Lucille Johnson~ ANO B-la on: 3001Porcuoine Drive / ~nch?ra~eo-AK_ x.6_ttn: 1BL prints, 1RFolded Sepia Bxxon Company U.S.A.~ P. O, Box 2180 Houston. TX 77252-2~80 At/n: Jeffery A. Davis, Room f3039L prints ~prints 1 BL prints, 1 RFolded Sepia UNOCAL ~P. O. Box 190247 Anchorage: AK 99519-0247 .Attn: Debra Childers The film is returned to BP. We appreciate the privilege of serving you. prints Very truly yours, SCHLUMBERGER WELL SERVICES Sws-- 132?.F OH/CH (6BL/4RF/IRR) Raymond N. Dickes DISTRICT MANAGER MEMORANDUM( ,, Stat~ ,~f Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, DATE: Chairman -,~ THRU: Blair Wondzeli, ~ P. I. Supervisor E/z-~ FROM: ]~0bby Foster, SUBJECT: Petroleum Inspector September 22, 1993 FILE NO: AKHIIVAB.doc ,. BOP TEST-- DOYON 15 BPX- DIU - 2-66\ SD - 12 P...T..D ..8.93 -. 79. EN'.I~I:C'O.~TT FIELD Wednesday, Seotember 22~ 1993: I traveled to BPX'.s Endicott Field and witnessed the BOPE test on Doyon rig 15. As the attached BOPE Test Report shows there were no failures. Summary: Tested BOPE on Doyon 15 on BPX's Endicott Field well 2 - 66 \SD- 12. No failures. ~. ~. k~. Attachment: AKHIIVAB STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover:~ Drlg Contractor: DOYON Operator: BPX Well Name: 2 - 66 t SD - 12 Casing Size: 9 5/8 Set ~ Test: Initial Weekly X DATE: 9/22/93 Rig No. 15 PTD # 93 - 79 Rig Ph.# 659- 65~0 Rep.: STEVE WALLS Rig Rep.: ALLEN SINCLAIR 13,465 Location: Sec. 36 T. 12 N R. 16 N Meridian U Other . Test MISC. INSPECTIONS: Location Gen.: OK , , ~ Housekeeping: ,.OK (Gen) Reserve Pit N t A ._ BOP STACK: Quan. Annular Preventer f Pipe Rams '~f .... · Pipe Rams f Blind Rams ' '1'" Choke Ln. Valves 3 HCR Valves 2 , , Kill Line Valves 3 Check Valve N t A Well Sign OK Drl. Rig OK Test Pressure 300 t 3000 ' ooo 300 % 5000 '30o' 500o 300 s0oo 30~"t 5000' ...... P/F FLOOR SAFETY VALVES: Ouan. Pressure P/F Upper Kelly / IBOP I i 300 t, 5000 ! P .- Lower Kelly / iBOP ~! 300 \ 5000! P Ball Type ' f 300 \5000 P Inside BOP f 300 '5000 '_ ~' .. . MUD SYSTEM: Visual Tdp Tank YES Pit Level IndicatorS YES' FIow Indicator - YES' Gas DetectorS 'YES Test. CHOKE MANIFOLD: Pressure P/F No. Valves I 300 ~ 5000 I P No. Flanges .... [ 300 ~,5000 "! P Manual Chokes " ~=un~oned 'P Hydraulic Chokes , ' Functioned ACCUMULATOR SYSTEM: System Pressure 3,000 Pressure Alter Closure ', ..... f, 4.00, ,, '1 P Alarm 200 psi Attained After Closure 0 minutes 32 sec. YES System Pressure Attained 3" minutes 07" sec. ~'~S' Blind Switch CoverS: Mast~: ~S Remote: YES YEs' Nitgn. Btl's: 4.~ 2400.' ...... . . . YES Psig. , ?fl=, ;I~I~lll ~.~.~I~i!lii,.q~I .- ' Number of Failures: NONE ,Test Time; 2.5 Hours. Number of valves tested 29 Repair or Replacement of Failed :Equipment will be made within N I A da~s' Notify the Inspector and follow with Wr~ten or Faxed verification to the AOGCC Commission office at: ~:a~ ~ ' 275-1842 If your call is not returned by the inspector within 12houmi Inspector North Slope Pager No. 659-3607 or 3687 please contact the P. I. SuperviSOr at 279-1433 · II I III I II I , I JII II III IIII I I I II I J ·. REMARKS: , Theupper and lower kelly valves will be tested before.. ~o, ing below the cas',m~l sh~, . ........ The.kelly could not be p~cked,uPdue to t.h.e .way the p(pe wdas racked in the derick i,1 i i , i . i i , j , ,j i i J i i , i ii ,1 , , , i i , ,, i i i i . .i i i i . i iii Distribution: 'S'j'ATE WITNESS REOUIRED? Waived By: .................. oR-Well File YES , , _ NO X c - Oper./Rig VVitnessed By: ~0~,~ iiiii i i. , i . i .., i i i c- Database :24 HOUR NOTICE GIVEN c - Trip Rpt File YES X NO c - Inspector i!11_! ii . ii I I I I I I Il/ FI-021L (Rev. 7/93) AKHIIVAB.XLS MEMORANDUM TO: David John' Chairman THRU: Blair Wondzell P.I. Supervisor FROM: Lou Grimaldi ;~ 1~2, Petroleum Inspector STATE OF ALASKA ALAS~ OIL AND GAS CONSER VA TION COMMISSION DA TE: September 15 1993 FILE NO: QKHJIOAB. doc PHONE NO: 279-1433 SUBJECT: Rig BOPE inspection Doyon #15 BPX well # 2-661SD-12 Endicott Wednesday September 15 1993 I made a rig BOPE inspection on Doyon rig #15 drilling BPX well # in the Endicott field. I found the rig to be in very good shape with all equipment I observed to be in compliance with evidence of regular maintenance. The connections (hammer union's) between the choke manifold and pit skid have been replaced with unibolt connection's and now fall within the APl requirement's of no threaded connection's permitted in the choke system. The area surrounding the rig was clean and orderly providing for good access. .SUMMARY; I made a rig Bope inspection on Doyon #15 with all equipment in compliance. Attachment: QKHJIOAB.XLS STATE OF ALASKA ALASK~ .,L AND GAS CONSERVATION COl RIG I BPS INSPECTION REPORT ,ISSlON OPERATION: Drilling ~; Workover ~C°mpl. UIC DATE: '9-15-93 Well Name: .St) -13, %, ~ --/,,~,, PTD# 93-79 Drig Contractor Doyon Rig# #15 Rep; Mike Drood¥ Operator. B.P.X. Rep. Steve Walls Rig Ph.# 659-6510 Location: Section 36 T. 12n R. 16E M. U i.:.!~:?f;,:;~': :i:'i:':.ii!i-:!~i~!::ilN~!ii~Ni!i~.~i~?.:'?,?!~::.::~:'i~?':',~;i':.!::: ~' INi Ci)~~Eili!! ::.;~!~:!~::!i:!i~:!!!:.:!~,:?,:i:'::?.!';!~E~T~N..~!!~MS;: (A.) B.O;P. STACK YES NO N/A {C.) MUD SYSTEM YES NO NIA 1 Wellhead fig wkg press X 29: Pit level floats installed X 2 Stack wkg press X 30 Flow rate sensor X 3 Annular preventer X 31 Mud gas separator X 4 Pipe rams X '32 Degasser X 5 Blind rams X 33 Separator byPass X 6 Stack anchored X 34 Gas sensors X 7 Chke/kill line size X 35 Choke line connections X 8 All turns targeted ( chke & kill Ln.) X 36 Trip tank X ti;l;i~i~i]i;i;[l: ' ................... "'i ''~ ' '. .... . ...... ~ ...... 10 Manual valves (chke & kill Ln.) X {D.) RIG FLOOR YES NO NIA 11 Connections (Flgd, Whd, ClamPed X 37 Kelly cocks (upper, lower, 'IBOP) X · 12 Drilling sPool X 38 FlOor valves (dart, ball,..ect:) x 13 Flow Nipple X . . 3g Kelly & floor valve wrenches X 14 Flow monitor X 40 Drillers COna:de (flow monitor, X 15 'Control lines fire. protected x flow rate 'indicator, pit level X li:i:[:i'il~:iL~ I;'i{iHi:it ti~ ................. ~'1 ........ II II I CLOSING UNIT YES NO N/A 41 Kill sheet up-to-date X 16 working'Pressure X 42 GasdetectJ0n i~onitors X 1.7Fluid level X ' (H2S.& me{hane) ' X 18 Operating. pressure X 43: Hydraulic choke panel X 19 Pressure gauges X 44 Choke manifold 21 :Regulator bypass ' X ('E.) M.ISC. EQUIPMENT YES NO NIA 22 4-way valves (actuators) X 45 Flare/vent line X , 23 Blind rams handle Cover X 46 All turns targeted X 24 Driller COntrol panel X (d,ownst, mare choke' lines),. X 25 Remote Control panel X 47 Reserve pit tankage X 26 Firewall X 48 Pemonnel protective equip, avail. X 27 Nitrogen power Source. (backUP) X ' 4g All Drillsite Supervisors Trained X ' ' '28.Condition (le~ks, hoses, eot.)' X " For Procedures "' I , 50 H2S. Probes X 5.1 Rig hoUsekeeping X ,rl~'"'iJ A &"~I/L~').. I'"~;__ .'_ '. ...... i · i REMARKS: Rig ;s in very good shape RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will' Be Completed: BOP Test & Results Properly Entered ~n Daily Record? Yes 9/12/93 None Kill Sheet Current? Yes Distribution: orig - Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector OPERATOR REP: QKHJIOAB.XLS (Rev. 12/92) I'll:IICI_lNG S~ !:1~/I C1::5 WELL LOG TRANSMITTAL To: State of Alaska September 9, 1993 Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs - 2-66/SAG DELTA 12 RE: AK-MF-930919 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: Paul Radzinski, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 1 Blueline ' 1 Folded Sepia 2" x 5' SSTVD Resistivity and Gamma Ray Logs: 1 Blueline ~o~- ~g.]e-t~.~ ~.~ qo~ -et~'l Folded Sepia Received: Date 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Baroid Company MEMORANDUM( Stat~ df Alaska Alaska Oil and Gas Conservation Commission TO: David Johnst~on, Chairma-6~ DATE: August 31, 1993 THRU: Blair Wondzell, ~ P. I. Supervisor ~ NO: AKHIH5AC.doc · FROM: Bobby Foster, SUILJECT: Petroleum Inspector BOP Test - Doyon 15 BPX- DIU- 2-66\SD12 PT.D. # 93- 79 Endicott Field Tuesday .Aug..USt 31t, 1993: I traveled to Doyon rig 15 this date and witnessed the weekly BOP test. As the attached BOP Test Report shows there was one failure. The manual kill line valve leaked. The valve was replaced and tested OK. . Summary: i witnessed the BOP test on Doyon 15 - test time 2.5 hours - one failure . Attachment: AKHIH5AC.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Workover: Drlg Contractor~"V' '~ n u Operator: .... ' BPX Well Name: ~ - 66 % SD 12 Casing Size: 1'3 3/8 "Set ~ ' Test: Ir~itial ' ' Weekly X Rig No. 15 PTD# 93-79 Rep.: Rig Rep.: 2,872' Location: Sec. "~6 T. Other DATE: 8/31~3 Rig Ph.# ' ' 659 - 6510 JEFF HUPP ALLEN SINCLAIR 12N R. 16E Meridia~ 'U MISC. INSPECTIONS: Location Gen.: OK _ Housekeeping: 'OK (Gen) Reserve Pit N % A BOP STACK: Quan. Annular Preventer f Pipe Rams I Pipe Rams 1 Blind Rams f Choke Ln. Valves ' '3. 'HCR Valves 2 Kill.Une Valves k 3 . Check Valve N [ A Well Sign . OK DH. Rig OK Test Pressure 300 % 2500 3oo sooo 300~ 5000 3 0'[a o 3bo.t P/F P 'p' ,, , · p ,,p ~ MUD SYSTEM: Visual Alarm Tdp Tank YES YES Pit .Level Indicators "~E$" YEs Flow 'Indicator YES ~'ESL' _ Gas Detectors YES YEs i i i ill i _.. [ FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Ouan. Pressure P/F _ I eoot I P 'f 1~ t ! 300 \ ~0001- ~P .... . '1 'P I 1~5 ''IP Test CHOKE MANIFOLD: Pressure P/F No. Valves 17 ! 300 ~ 5000 I P No. l,no ,3e I3oo ',"i ' Manual Chokes f Functioned P Hydraulic Chokes ,',.1, :1 FuncUoned I ,P ,. ACCUMULATOR SYSTEM: Systam Pressure 3,000 I P Pressure After Closure .. . 1,.400 ..... ~ 200 psi Attained After Closure 0 minutes 32 System Pressure Attained 3 minutes Blind Switch Covers: Master: YES RemOte: Nilgn. afl's: .......... 3 ¢~ 23,00 ..... ...... ........ sec, sec. YES Number of Failures: I ,Test Time: 2.5' Hours. Number of valves tested 27 Repair or'Replacement of Failed Equipmentwill. be made within I ~J'ays. Notify the Inspector and fOllow with"Written or Faxed verification to the AOGCC Commission Office at: Fax N' 276-7542 Inspector North Slope Pager No. 659'-3607 or 3687 If your call iS not returned by the. inspector within 1.2 hours please contact the P. I. SuperV~or at 279-1433. · . REMARKS: Distribution: orig-Well File c - OperJRig. c - Database c. Trip Rpt File c - Inspector ii i KILL LINE VALVE LEAKED. REPLACED AND TESTED OK iiii iiiii. . ii , , i ii . i i . ii i i . i i i i .. i .. i J i . i i [ i i i i . iIi ii i i i iiij i i i . i. ill iii i i.. .i . ii i i i i.i i ~ i i i i ii ii iii ii .... STATE Wj'TNESS J~EQUI.I~.~"D?' ' YES NO X . .iL 24 HOUR NOTICE GIVEN YES X NO iiiiii i i i i i i Waived By: Witnessed By: i i i i i ii iii i i .] ii ~1 i[ i . _1 i iii i ii . i i i , , , · ........ , . . ,, . ....... ii ii i i i i ii . i[ _. i i _ i i.. i.. iii , ii i _ i i i i i jii FI-O21L (Rev. 7/93) AKHIH5AC.XLS MEMORANDU Stat( of Alaska Alaska Oil and Gas Conservation Commission TO: David John~ Chairman DATE: August 14, 1993 THRU: Blair Wondzell, P. I. Supervisor FILE NO: akhkhkaa.doc FROM: Jerry Herring, ~(~ ~ SUBJECT: Petroleum Inspector BOP Test- Doyon 15 BPX, DIU, 2-66/SD-12 Endicott Field PT~!';~:~,.,*.:{7..,, 9,,.,, Wednesday, August 11~. 1993:. I traveled to Endicott and witnessed a BOP test on Doyon 15, drilling well number 2-66/SD-12. The 13-3/8" surfaCe casing was installed to 2,872 feet. The BOP Test Report and Rig Inspection Report are attached. The BOP test started at 10:00 PM and lasted for 2-1/2 hours. All of the BOP equipment functioned, well. The only failure occurred when the turbine room methane gas detector #2 failed to function properly. The gas detector head was replaced with a new one and successfully retested. One problem was discovered. Permit #93-79 requires a functioning ~ detection, system be installed as outlined, in 20 AA 25.065. The required equipment was on order at the time of the BOP test. I worked with tool pusher Mike DroorJy to make sure the I-~ detection equipment requirements were met. Seven days ~given to have the ~ equipment installed and in working order. As a quick fix to meet the (7) day requirement, Mike improvised and utilized operations H2S equipment already in place to monitor adjacent wells under the rig which were shut-in. Two H2S detection heads were relocated from the well houses to the shale shaker and the bell nipple. At last report, the new H2S detection equipment is due on location August 18. Mike Droody is a good Tool Pusher and a pleasure to work with. Summary: The BOP test on Doyon 15 lasted 2-1/2 hours and there was 1 failure. Attachments STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: DO~'ON Operator: ,, BP Exploration, , Well Name: DIU 2-66/SD-12 Casing Size:' 13-3/8~ Set {~ Test: Initial Weekly , Rig No. 15 PTD# , , . Rep.: Rig Rep.: 2'872 Ft. Location: Sec. Other 36 'T. DATE: 8/f 1/93 Rig Ph.# 659-6510 Clarence Ballard Mike ~m~,~, ' , , 12N R. 16E Meridian ii i, Test MISC, INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: OK Well Sign OK Upper Kelly I ,BOP 1,300/5000,P Housekeeping:"0K (Gen) Drl. Rig OK Lower Kelly ! IBOP ' '~ 'i ,5000 Reserve Pit.'../~/'A' -'--' Ball Type "~ ~00 / ' P' :'- Inside BOP ' 1' 300/5000 'p Test BOP STACK: Quan. Pressure P/F Test Annular Preventer I I 300/3000 ~ P CHOKE MANIFOLD: Pressure 'P/F Pipe Rams ~ i 300./~ I'"P ..... No. Valves ~ ~Z I. 300/5000 I P Pipe 'Rams "f': ' I 3oo/~ I, P: No. Flanges 3,00/ Blind Rams f . !.'3..~,/..5000... i ' P .... Manual Chokes Funclioned . Choke Eh. Va~es . f . i 3,OO/~ I, ,,'P' Hydrauac Chokes ...... Functioned HCR Valves 2 I 300/S0OO I P i1,~ ~ . ~a~ une valves :i: f . ! .3oo/~'1 ACCUMULATOR SYSTEM: CheckValve .N/C .I ' .'N/C. ,, i~ System Pressure 3~0001"1'_ :'P"i..P '"' ........ Pressure Alter Closure ' 1,250 MUD SYSTEM: .Visual Alarm 200 psi Attained After Closure 0' minutes 40 sec. Trip Tank OK ,,,,N/A, System Pressure. Attained 3 - minutes. ' 2~' sec. Pit Level Indicators 'OK OK Blind Switch Covem: Master:' OK Rem0~'.:' ' OK Flow Indicator "' OK ~' -'~ Nilgn. Btl's: (4) Bottles Gas Detectors OK ' OK' ' :'- ~ '2~ (Ave,) ": -" ' Psig. H2S Detectors . ' No~e " NO~ .... ' "' :"~ ': "' NUmberofFaiiures':' I ,Test Time: 2~5" Hours. Number'of Valves tested 23 Repair or RePlaCement of Failed ' · · :; t ' :: :~._::: _: ~ · ' · ~ · · ~Equ,pment will be made within. , ,. 7, .... days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax N 276-7~42 Inspector North Slope Pager No.. 6'59-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279.t 433 =-- ' . I I,I [11111 "11iiiirl .i ilJl!liii i ii ii i r I I I II I I I II II I I I I IIIII I,111 I I II , I I.I1'11 I1..1!111 II1(I . I REMARKS: M..e.~ane ~n hea..d:#2 fai.~. . :No remo~ light for gas. deteclion,' ,sy,,~em; .... . ....................... ......... No hydrogen sulSde (H25) det~..system as...~,..ui.red Per, , drilling ~. . . ' :--.." ..: . ... ' R,t,~e, !/~ of a'H2$ det~n ~y~tem wi// be.m~ w~. in (7) days, ' : ': .......... Disbibution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File ' c - Inspector i ,. IlU Ill I I, IIII I I I. ._1 I IIIl. I, I I. I I . . . I I I II,llll. I ,IL I} I.II I I .I I , , I , , ,, , .,, I,,, i. r I I .... I II .I .... S~FATE WITNESS RE~UiR.ED~ ' YES X NO . ii i i i _,Il ~1 I , i i i i i 24 HOUR NOTICE GIVEN YES X NO Waived By: W'~essed By: FI-021L (Rev. 7/93) AKHKHKAA.XLS OPERATION: Drig Contr: Operator: Looation: (' STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION RIG I BPS INSPECTION REPORT Drilling X Workover DOYON 'BP EXF~LORATION Section 36 T. 12N .,. Cmpl. UlC DATE: 8/11/93 Well Name: DIU 2-661SD-12 PTD# 93-79 Rig No. 15 Rep. MIKE DROODY Rep. CLARENCE BALL/~D ' 'Rig i=h.# ' 659-6510 R. 16E M. UM STACK fig wkg press press preventer Blind roms Staok anchored Chke/kill line size ( chke & valves & kill Lng) vanes (dike & kill l,n. fire Eh.) MUD SYSTEM floats installed Flow rote sensor Mud gas separator bypass line connections tank valves (dart, ect.) & floor OOnsole monitor, pit level level monitors m.0~. rs dioke .roms handle cover 6ouroe tums targeted choke Trained REUARK$: '~ECOJ~0S': ........... Date of Est Rig: I BPS Inspeclion Resulling Non-Compliance Items: Non-Compliance .not corrected & Reason: ' Date.Correclions Will Be Completed.: 81!8193 '~ .................................. BOP Test & Resu#s Properly Entered'On Daily Record? ? Date of Last BOP Test8/11/93. ii ii i i i i{ i i ..... H2,8 gas d,e,,,t,,e,~ion system, required Per driBng pe,,rrp~t#9,3:7,9~, ~m,, ,to ,be, installed.. FH)22 (Rev. 3/93) QKHKHKAA.XLS arig - Well File Oper,/Rig o- Databaee Trip Rpt File Inspector OPERATOR REP': · , ..... iI i i i i i . i ii iii ij . . Yes Kill. Sheet Current? Ye,s ,, AOGCC REP: .................. .j..e. fly. p. Herring MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David W. Johnst .~,q;~~' Commissione~ thru: Blair E Wondzell Petr Insp Supervisor from: John Spaulding Petr Inspector date: August 13, 1993 , ~e: 072893.doc sub)ect BOP Test, Doyon 15 BPX 2-661SD-1'2 DIU Endicott Field P'~D".93'-'79' "' Wednesda'y, July 28, 1993: I traveled to BPX well 2-66/SD-12 DIU to witness a BOP test on Doyon Rig 15. As the attached AOGCC BOP test report indicates~there was 11 valve failures noted on the choke manifold. These valves were taken apart and inspected for any internal wear or damage, none was found. These valves were lacking in grease. All valves were greased and tested good.. Doyon was allowed to drill out of the surface casing shoe and perform leak off test; but not to proceed with drilling operations until repairs were made and tested. Summary: Witnessed BOP test Doyon 15 BPX 2-66/SD-12 DIU; 11 failures, 16 hours. attachments ! , .~..: :.~, ...~L, . (' ( "'..'" :-~' MEMORANDUM State of Alaska ~'' Oil and Gas Conservation Commission .. TO: David Johnston, DA~: '7- ~ - c), ~ Commissioner THRU: Blair Wondzell, P. I. Supervisor FILE NO: TELE. NO: 279-1433 FROM: John Spaulding, SUBJECT: Petroleum Inspector FIELD REPORT ~,~/i ~.-~/~'?..~^- /..z. ~.~ /o ~,V~,~,~. ,~ ~.,~ ., o OPERATION: Ddg: Ddg Commctor:. Operator. Well Name: ~ - Ca.ing Size:../$ ~/A Test: Initial STATE. OF AL, A~KA OIL AND GA8 CONSERVATION'COMMi~iON BOPE Test Report MISC. INSPECTIONS: I.mmion Gen.: / HouselmepinO: ----- Rmmr~ Pit ----- BOP STACK: Ann. Preventer P~pe Rams Brmd RBms Chk/Ln Velves HCR Valves Kill Line Valves Check Velve (Gert) Dd. Rig .... / Test Qum. Pmm~ FLOOR SAFETY VALVF.~: umw Ka,y I..~r Kelly ~11 Type CHOKE MAlaFOLD: No. Fl~nge~ M~nu~l Cholc~ Hydraulic Chokes ACCUMULATOR SYA"TEM: 8YfTEM: Light Almrm Pre~m~m Afl~r GIo~ure / ~'.f'<) 2oo ~~Albr ClomJre _ minu~ ~ Tdp Tank v/ /- 8yalem ~ .TU~ained -'"T minul~ ~ ~ level ~cat~m / ' ," BUnd 8wib:h CMm Mmmc ~ Ramot.: ,v'e s G~s DetK~m ~ ' '" : F'~g. , , Equipment'shell be m~e ~lled . - wilh Wdllen or FmmcI vedacalion to ,, .ygUr...em, m. not returnee oy me impector wilNn 12 houri please contact the P. I. 8UlXm~-~"- ~.~"'"' . REMARKS: ee ~ ~ ...,-, ' ~ , · . ,,. , , ~ .' .' .~/ ~.~:c,~,~,~,/ .~ ~ /a., ", - o ,~_, ~ . odg-WMI Fib Oper./Rlg Debase Tdp Rpt Flle In~a~ler YE8 L/~5 NO 24 HOUR NOTICE GIVEN 'YES NO _ Wlhmd By:. Wiln.Nd By: FI-O21~T MEMORANDUM TO: David Johns~ Chairma~,'"~~ S TA TE OJ. 4LA SKA ALASKA OIL AND GAS CONSERVATION COMMISSION DATE: July 24, 1993 FILE NO: EKHIGXAA. DOC THRU: Blair Wondzell P.I. Supervisor '~]~, FROM: Bobby Foste'~ Petroleum Inspector PHONE NO.: 279-1433 '~,, SUBJECT: DIVERTER INSPECTION BPX - DIU - MPI - 2-66\SD -12 PTD #, ,931:,~,,~., ~ ENDICOTT FIELD SATURDAY, JULY 24, 1993 I traveled this date to Doyon rig 15 to witness the functioning of the diverter system and varifY' that the system was installed in accordance with AOGCC regulations. I met with Steve Walls, BPX's representative and we inspected and functioned tested the system. The system functioned properly and was installed in accordance with AOGCC regulations. Attachment · EKHIGXAA. XLS KAI'~. STATE OF ALASKA i~I' ALAS .L AND GAS CONSERVATION COM . JION Diverter Systems Inspection Report Drlg Contractor: DOYON Operator: BPX Oper. Rep.: Well Name: 2 - 66 \ SD-12 Rig Rep.: Location: Sec. 36 T. 12N R. 16E Operation: Development Rig No. 15 PTD # Date: X Exploratory: 93-56 RigPh.# 659-4610 STEVE WALLS ALLEN SINCLAIR Merdian U MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: × Well Sign: × Systems Pressure: 3100 psig Housekeeping: X (Gen.) Drlg. Rig: × Pressure After Closure: 1650 psig Reserve Pit: N~A Flare Pit: N~A 200 psi Attained After Closure: min. 22 sec. Systems Pressure Attained: 2 min. 15 sec. DIVERTER SYSTEM INSPECTION: Nitrogen Bottles: 2@ 1900 Diverter Size: 20 Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 10 Vent Line(s) Length: 170 Line(s) Bifurcated: YES Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted / Long Radius: YES in. 2@2200 psig MUD SYSTEM INSPECTION: Light Alarm in. Trip Tank: X X ft. Mud Pits: X X Flow Monitor: X X GAS DETECTORS: Light Alarm Methane X X Hydrogen Sulfide: X X Non Compliance Items Remarks: Repair Items Within Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - Oper/Rep c - Database c - Trip Rpt File c - Inspector FI-022 (Rev. 7/93 AOGCC REP.: OPERATOR REP.: EKIIGXAA.XLS STEVE WALLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF BP ) EXPLORATION (ALASKA) ) INC. for an order granting ) an exception to spacing ) requirements of Title ) ~.0 AAC 25.055 to provide for ) the drilling of the BP Sag Delta ) No. 12 exploratory oil well. ) Conservation Order No. 318 BP Exploration (Alaska), Inc. Sag Delta No. 12. July 1, 1993 IT APPEARING THAT: · BP Exploration (Alaska), Inc. submitted an application dated June 1, 1993 requesting exception to 20 AAC25.055(a)(1) to allow drilling the BP Sag Delta No. 12 exploratory oil well closer than 500 feet to a drilling unit boundary. . Notice of opportunity for public hearing was published in the Anchorage Daily News on June 9, 1993 pursuant, to 20 AAC 25.540." 3. No protest to the application was received. FINDINGS: · The BP Sag Delta No. 12 well as proposed will be directionally drilled from a surface location 3151 feet from the south line (FSL) and 2360 feet from the east line (FEL) of Section 36, T12N, R16E, Umiat Meridian (UM) to a proposed bottom-hole location 2780 feet FSL and 4924 feet FEL of Section 2, TllN, R16E UM. · Offset owners Cook Inlet Region, Inc.; ARCO Alaska, Inc.; Doyon, Limited; NANA Regional Corporation, Inc.; Amoco Production Company; Exxon Company, U.S.A.; and Unocal Corporation have been duly notified· · An exception to 20 AAC 25.055(a)(1) is necessary to allow drilling of this well. Conservation Order { o 318 July 1, 1993 Page 2 CONCLUSION: Granting a spacing exception to allow drilling of the BP Sag Delta No. 12 well as proposed will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: BP Exploration (Alaska), Inc. 's application for exception to 20 AAC 25.055 for the purpose of drilling the BP Sag Delta No. 12 well is approved as proposed. DONE at Anchorage, Alaska and dated July 1, 1993. mission Russell A. Doug~missioner Alaska Oil and Gas Conservation Commission erman A. Babcock, Commissioner Alaska Oil and Gas Conservation Commission ALASKA OIL AND GAS CONSERVATION CO~IHISSION July 1, 1993 Russ Strickland Drilling Engineer Supervisor BP Exploration (Alaska), Inc. 'P O Box 196612 Anchorage, AK 99519-6612 'WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Duck Island Unit/Endicott 2-66/SD-12 BP Exploration (Alaska), Inc. Permit No: 93-79 Sur. Loc. 3151'NSL, 2360'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc. 2780'NSL, 4924'WEL, Sec. 2~ TllN, R16E, UM Dear Mr. Strickland: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commissionmay witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. _r~ printed on ~ecycled paper b y c.D. State: Alaska Borough: well: 2-66 i SD-12 Field: Wildcat St. Perm # 93-79 2-66CSG~1_S Date 6/10/93 Engr: M. Minder Casing Interval Interval Size Bottom Top Length lA 13.375 27~ 37 2816 2A 9.625 10481 86 13924 3A 7 11571 10370 1829 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Description Description Description Tension Lbs Grade Thread Lbs 68 NTSOC BTC 0 47 NTS0-S NSCC 0 29 NTS0-S NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/It psi/It 1B 9.5 0.494 0.394 2B 10.5 0.546 0.446 3B 9.4 0.489 0.389 4B 0.0 0.000 -0.100 5B 0.0 0.000 -0.100 6B 0.0 0.000 -0.100 7B 0.0 0.000 -0.100 8B 0.0 0.000 -0.100 9B 0.0 0.000 -0.100 10B 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 3900 4930 1 .$ 39OO 6870 1.8 3900 8160 2.1 0 0 #DIV/0! 0 0 #DIV/0! o o #DIV/O! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/0! Tension Strength K/Lbs K/Lbs lC' 191.488 1545 2C 654.428 3C 53.041 4C 0 5C 0 6C 0 7C 0 8C: 0 9C 0 10C 0 TDF 8.07 1086 1.66 676 12.74 0 #DNIO! 0 #DNIO! 0 #DIV/O! 0 #DIV/0.1 0 #DIV/O! 0 #DIVJO.I 0 #DN/O! Collapse Collapse Pr-Bot-Psi Resist. CDF 1086 2850 2.625 4675 4750 1.016 4499 7020 1.560 0 0 #DIV/0! 0 0 #DIVJO! 0 0 #DIV/0! 0 0 #DIV/O! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/0! Page 1 ,. 2-66_.CI.4T.XLS Stale: Well: Field: Stale Permit fl: 2-66 ! SD-12 Wildcat 93-79 Engineer. Work S hee~. Date: Ce~'~j Type Ca~ing Size-Inches Cashg Length -Fea Hole Diameter -Inches Ceme~ - Sacks #1 Cement- Yield 111 Cemen~ - ~ Il Cement. Cubic It #1 Cement- Sacks #2 Cement- Y'~I 112 Cement- Cubic It #2 Cement- ~ It 112 ~- Sacks #3 Cement- Cubic tt #3 Cement- Cubic it #3 ~r~-Cubi~ Il IVd Cement- Fill Factor Conduclo~ 0.000 0.000 0.1300 0.000 0.000 0.0130 O.00O 0.000 0.000 0.000 O.000 0.O00 ltDIVtO! Su~lace 13.375 2,816.000 16.000 550.000 2.170 1,193.500 1;193.500 400.000 1.160 484.1700 O. O00 0.OOO 0.000 0.000 1,6'57.500 1.400 7.000 1,829.000 8.500 375.000 1.190 446.250 446.250 0.000 0.0130 0.00O 0.000 446.250 1.924 gang Type C~hg Size -Inches Ca,~g Depth- Fee[ Hole Diameter -Inches Cenent · Sack~~1 C~-Y~ ~1 ~~- C~ It ~1 Ce~- ~ ft ~1 ~- Sa~ ~2 Cema- Cub~ ft ~2 Ceme~ - C~ic ft ~2 ~- S~ ~3 Cema- ~d ~3 Ce~- ~ ft ~3 C~- C~ ft ~3 C~- C~ ft / V~ Cement- Interval tt Top of Cement- Feet Intermediate #1 0.00O 0.000 0.000 0.130 0.130 0.00 0.00 0.O0 0.t30 0.00 0.00 0.00 0.00 0.00 0.O0 0.O0 #DIV,~. fl:DIVtO! Intem~edia~e #2 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 #DIV~ ItDIV/O! Production 9.625 13,960.000 1Z250 1,000.00 3.24 3,240.00 3240.00 4O0.00 1.15 460.00 480.00 0.00 0.00 0.00 0.00 3.700.00 11,814.23 2,145.8 Measured Depth Pdnted 6/10/93 BP EXPLORATION BP Explor~tion (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (0o7) 561.5111 June 1, 1993 Mr. Robert Crandall State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Spacinq Exemption for Saq Delta SW, 2-66/SD-17 Regarding the above'requested exemption to be sent under separate cover and previous telephone conversations, please find enclosed plan and side view plats of the planned wellbore for well 2-66/SD-12. As you are aware, although the well is officially classified as an exploratory well, it will be drilled from the Endicott Main Production Island (MPI). To date, no development wells drilled from the MPI have encountered any hazardous shallow gas zones. In BP's opinion, there is no evidence to suggest that shallow gas will be a factor in drilling SD-12. Finally, the bottom hole location is targeted on the down-thrown side of the field bounding Mikkelsen Bay Fault. Abnormally pressured sands are not expected to be encountered. This statement is based on infill development experience at Endicott as well as Sag Delta 02. Sag Delta 02 penetrated porous and permeable Kekiktuk / Kayak sands between 10980' - 12360' TVDS$. The sands were wet and not tested, however, the mud weight never exceeded 10.1 ppg, or .525 psi/ft gradient. No well "kicks" or swabbing was reported. Our current pressure estimates 'is that in SD-1.2, bottom hole pressure'will be approximately 5500 psia at 11515' TVDSS. Planned mud weight is 9.8 ppg, which yields 5868 psia, a 368 psi overbalance. If you haVe further concerns, or questions, please contact Bob Metzger at 564- 4613. cerely, Manager, Endicott Geoscience RECEIVED JUN - 3 199;~ Alaska Oil & Gas'Cons. Commission' Anchorage Mr. Robert Crandall State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 enclosures (2) rrm Well File Endicott File 06.10 RECEIVED JUN - 3 199~ /~iaska 0ii & Gas Cons. Commission ~chomge FROI"! GREAT LAND D l R DR ! LL I FiG TO "' P-BD- EI..IG PRUDHOE BAY DRILLI~'~.. °-- ~-- , , --- 2-bb/l:::iU-12 I B-- i I ' VERTICAL SECTION VIEW ¢'- i Ii I Section at: 234.06 , TVD Scale' ! inch-- t500 feet Drawn .... '05/04/93 E ~ I I Grea~ .......... Land ~rec~jonaJ Ori]]jng i i , i ...... ) ,, ~ Marker i~en~l~c~tia~ MD BKB SECTN INCLN ~ II BI KOP BUILD l/tO0 BO0 500 0 0.00 i I I C) BEGIN TUrN 5/~00 800 BOO ~ ~.00 )- ................ ' J D) BUILD t.5/]00 END TN ~500 1495 82 IO.O0 I Fl t3-3/8" CASING 2653 2756 550 ~.OG ) .... G) END 2/I00 BUILD 3566 330G tO01 46.35 j J~ N) INTERMEDIATE CASING 13960 10481 652t 46.35 ! ) I) TARGET ' 14D40 IOBB1 8~40 46.3~ i~ ~ J) TD .. ~5539 1157~ 9664 46.35 m ........... ) ~ ..... i i I ,i J " )~ ~ i , , ~ I ) i : i ! i '~ ,~n~ ~r - ' ~ .......... ~ .......... ~ ........... ~ ......... ~ ................. .......... ~ ........... ~ ........... ~ .......... ~ ~x .... '~ .... . ....,,~.~.,- ,.~.; ~ ~ ....... I .....[~ ~-- ~--.. -- -- -,~ ~-~a:~ ........... ~ ........... + ........... ; ..... ~ ~ .... ~ r ~ ¢ ~ ..... ' ...... : .... . ' _ i : ' : I ...... ' ~ JU!1-~199~ " ' ' ", ................. I ; Alas a 0il & las Cons - , i ,JJ ' I ! ,! ,mchor.~ 2250 3000 2750 4500 5250 5000 6750 7500 . · Section Departure 2-66/SD-i2 (P33 PLAN VIEW ~ CLOSURE .....: 9664 feet DECL ]N.~ T] SCALE. DItAIiN. _ _ at Azimuth 234.2! Har'ker o) imp c) D) iltlILD E) BUILD F) Gl END ]1 d) lO ....... PRUDH'OE--BAY DRILLING .~-LU '~ - --- ~l_ , .... m -- - --- , --- .JLa__ _J_ I L___ I ' __ i _ i i i i i i ]NATION.: 30.00 E ' I ...................................................................... -- ....... ! J, inch: 2200 f~et ! · identi itcaLion F~ N/S 0 0 N 0 E -3/8" CAS]~.m 2653 303 S 4rb ) 2/10~ BUILD 3~68 56~ S B~ 'EB.1EDIAIE CASIF¢ 13960 4981 S Gg')4 ti ........ ' ~ ..... :El t,l~40 . 522? S 7253 15539 5652 S 70~3 ti .' ., , ,= .................... ............... . ........ . i ~ '" 7-'~ ' "~ ..... . ~ -~' , -- .....--- . ............ I ~ I ~ ~ , . ~ . , ...... .... : ...~.~ ..... ~_~ ............ : ................................. ~ .................. ~ ........ ~ ............ i" : i - - '~' " ~'J I 1021) 11 !lliO0 '.))OI) B400 7(]00 7200 6600 6000 5400 4809 4200 3600 3000 2400 tOCO I200 60.') 0 600 <- 'tIES1 ' El, SI -> J, _ _ m .... :; · · · j ~J o ;11 I- z -I m {" STATE OF ALASKA {' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill I~1 Redrill Dllb. Type of well. ExploratorylTI 8tratigraphic Test [] Development Oil 1"1 Re-Entry [] DeepenI-!I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 f e et Endicott Field/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612r AnchoragerAlaska 99519-6612 ADL 34636 4. Location of well at surface 7. Unit or property Name 11. Type Bond(=., 2o ~c 2s.o2s) 3151' NSI., 2360' WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval .8. Well number Number 3204' NSL, 4338' WEL, SEC. 2, T11N, R16E 2-66/SD-12 2S100302630-277 At total depth ;). Approximate spud date Amount 2780' NSI., 4924' WEI., SEC.2, T11N, R16E 7/1/93 $200,000.00 , 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(MD~=TVO) property line ADL 34633-2498' feet No close approach feet 2560 15539'MD/11571' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (m~ 20 ,~c 2s.o~s (,)(2)) Kickott depth 500' feet Maximum hole an~le 4~.~ Maximum mur~a~ 3900 p~g At t~ta~ depth (TV;)) 10000Y4890 pelg 18. Casing program Specifications Setting Depth size Top Bottom Quantity of cement Hole Casing Weight Grade CouPling Length M D TVD M D TVD (include stage data) 30" 30" Struct. Drive Pipe 94' 37' 37' 131' 131' Drive 16" 13-3/8" 68lt NT80 B TC 2816' 37' 37' 2853' 2756' SSO sx PF 'E'/4OO sx 'G"/2$O sx 'C' 12-1/4" 9-5/8" 47# NTSOS NSCC 11054' 36' 36' 11090' 8500' 12-1/4" 9-5/8" 47# 'NT95 NSCC 2870 11090' 8500' 13960' 10481' 1400 sx Class "G" 8-I/2" 7" 29# NT80 NSCC 1829 13710' 10370' 15539' 11571' 375 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measur&d.d..epth_ True Vertical depth Structural~J~CE IVED Conductor Surface Intermediate MAY 2 4 199;5 Production Alaska 0il .& Gas Cons. Commission Liner Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth platt [] Refraction analysis [] Seabed report• 20 AAC 25.050 requirementsl-I 21. I hereby/~.~hat t~ljue and correct to the best of my knowledge Si~lned~ ,.,,,,,---- ~,,,,/,--~-,~----,,L J ~LO~ Title Drilling Engineer Supervisor Date~ ~ ~ CSmmission Use Only Permit Number IAPI number IApproval date _ See cover letter ?~' 7? 150- <3 ~. ?.. z. ~ .7 ? y I '~ ~' / -'_~-~ for other requirements Conditions of approval Samples required ,1~ Yes [] No Mud log required l~IYes I- No Hydrogen sulfide measures IR Yes [] No Directional survey reqmred [] Yes [] No Required working pressure for BOPE [] 2M; ' .'J3M; ~5M; I"110M; 1"115M; Other: Approved by Orlgtnat Signed By by order of / ~ ..-. -. ,~, ~,-,hn.~ton Commissioner me commission Date" - Form 10-401 Rev. Submit in triplicate MPI 2-66/SD-1 2 WELL PLAN SUMMARY SURFACE LOCATION: 3151 FSL 2360' FEL SEC 36 T12N R16E UM TARGET LOCATION: 3204' FSL 4338' FEL SEC 2 T11N R16E UM Bo'n'oM HOLE LOCATION: 2780' FSL 4924' FEL SEC 2 T11N R16E UM TOTAL DEPTH: 15539 MD/11571 TVD ESTIMATED SPUD DATE: 7/1/93 CONTRACTOR: DOYON Rig 15 ELEVATIONS: PAD: 1 O' Pad TO RKB: 46' RKB: 56' DIRECTIONAL INFORMATION: KOP: SOO BUILD RATE: 1,1 .S & 2°/100' EOB: 3308' TVD/ 3568' MD AVG ANGLE: 46.35° DIRECTION: 234.06° DEPARTURE at TD: 9664 FORMATIONS MD ~ SS Degth Permafrost 1471 1466 1410 SURFACE CSG PT 2853 2756 2700 TOP TUFFS 11228 8595 8539 TOP HRZ 11968 9106 9050 TOP LISBURNE 12330 9356 9300 TOP ITKILYARIAK 12801 9681 9625 9-5/8" CSG PT 13960 10481 10425 TOP KAYAK 13960 10481 10425 TARGET (SUBZONE K3A) 14540 10881 10825 OWC 15083 11256 11200 TOP K1 15395 11471 1141 S TD 15539 11571 11515 CASING PROGRAM 1, Intermediate casing point picked by geologist on location and approved by ddlling supervisor, 2. TD picked as 100' TVD below the top of Zone K1, Bit Size ~ ~ Grade Connection ToD Bottom Driven 30" Struct. WELD Preset Preset 16" 13 3/8" 68# NT-80 BTC 37 2853 2816 12 1/4" 9 5/8" 47# NT-80 NSCC 36 11090 11054 12 1/4" 9 5/8" 47# NT-95 NSCC 11090 13960 2870 8 1/2" 7" 29# NT-80 NSCC 13710 15539 1829 RECEIVED M AY 2 4. 199 Alaska Oil & Gas Cons. c0mm%Ss~on Anchorage 2-66/SD-12 (MPI) Casing Design Specifications SURFACE CASING 13-3/8" 68#/FT NT-80CYHE BTC CASING BURST COLLAPSE PBYS (#) TJYS (#) NT-80CYHE 4930 2850 1545000 1545000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. LOT (ppg) TVD (FT) SIPRESSURE 1 4 2756 2006 Burst S.F. 2.46 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2756 1361 Collapse S.F. 2.09 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 2853 PBYS Tension S.F. 9.32 Mud Wt. 9.5 ppg TJYS 9.32 String Wt. (#) 165835 RECEIVED MAY 2 4 199,~ Alaska Oil A Gas Cons. CommiSSiO[~ Anchorage 2-66/SD-12 (MPI) Casing Design Specifications Production Casing 9-5/8", 47#,NT-80S and NT-95HS,NSCC Casing GRADE BURST COLLAPSE NT-80S 6870 4750 NT-95HS 815 0 508 0 PBYS (#) 1086000 1289000 TJYS (#) 1161000 1273000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. srrP 3900 Burst S.F. Burst S.F. 1.76 (NT-80S) 2.09 (NT-95HS) Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Mud Wt. (ppg) 10.2 Collapse S.F. Collapse S.F. Gas Grad. Collapse press Collapse press TVD (FT) (psi/ft) at 8500' TVD at TD 10481 0.1 3658 4511 1.30 (NT-80S @ 8500' TVD) 1.1 3 (NT-95HS @ TD) Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. 47 13906 10.2 PBYS TJYS Tension S.F. 1.97 2.10 Tension S.F. 2.34 2.31 String Wt. (#) 551689 (NT-80S) (NT-95HS) RECE]VED Alaska 0il & Gas Cons. Anchorage 2-66/SD-12 (MPI) Casing Design Specifications PRODUCTION LINER 7', 29#,NT-80,NSCC Casing GRADE BURST NT-80 81 6 0 COLLAPSE PBYS (#) TJYS (#) 7020 676000 746000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid SITP Fluid wt (ppg) back up (ppg) Burst Pressure 3900 9.5 9.7 3808 Burst S.F. 2.14 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 9.7 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 9.7 11571 0.1 4679 Collapse S.F. 1.50 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 29 1829 Tension S.F. PBYS 15.10 Mud Wt. String Wt. (#) 9.7 44772 TJYS 16.66 ,. RECEIVED MAY 2 4 199~5 Alaska 0il & Gas Cons. Commission Anchorage PROPOSED DRILLING AND COMPLETION PROGRAM WELL 2-66/SD-12 (MPI) Ob|ective Well 2-66/SD12 will be drilled from the Endicott MPI to evaluate the potential of hydrocarbons outside the Duck Island Unit. The prospective target is the Kekikituk formation on the down-thrown side of the Mikkelsen Bay Fault. If the well has producible hydrocarbons, a 3-1/2" completion is planned to be run at the time of drilling and will consist of a simple type assembly. Operation Execute a rig move and rig-up. Directionally drill surface hole with a 8.5 - 9.5 ppg mud system to 2756 TVD. Run and cement 1.3-3/8" 68#/ft NT-80CYHE buttress casing to surface. Pressure test casing. Install BOPE. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Directionally drill 12-1/4" hole with a 9.0 - 10.2 ppg mud.system to the intermediate casing point above the Kayak formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal D ressures are expected in the 12-1/4" hole section. Pressure test casing. rill out casing shoe. Drill 8-1/2" hole with a 9.8ppg mud system to TD. Run open hole logs. Clean out to landing collar. Test casing and [,ap to 3000 psi. Change over to a brine packer fluid. Run SBT/GR/CCL in 7 liner. Complete with a simple type assembly. A subsurface safety valve will be installed below base of permafrost. Nipple down BOPE. Install tree on wellhead and release rig. Perforate well and run GCT/gyro after rig release. Fluids incidental to the drilling of the well will be pumped down the 13-3/8" by 9-5/8" annulus of the well. The 13-3/8" x 9-5/8" annulus will be freeze protected with a non-freezing fluid down to 3000 feet once the rig is released. JLH 5/6/93 RECEIVED AJaska Oil & Gas Cons, Commission Anchorage MWD/OPEN HOLE LOGGING PROGRAM 1. 16" hole: MWD Directional 2. 12 1/4" hole: MWD Directional Mud Logging from 100' above LCU to CSG PT. Open hole logs contingent on shows: DLL/MSFL/GR, LDT/CNL/Spectral GR 3. 8 1/2" hole: Sperry MWD EWR4/Neutrort/DEN/GR DLL/MSFL/GIL LDT/CNL/GR, RFT (10-15 Points) GR to surface csg (+/- 2700' MD). Mud Logging from CSG PT to TD. CASED HOLE LOGGING PROGRAM 1. SBT from TD to TOC in 9 5/8" casing. Z. GCT: PBTD to surface (After rig leaves) COMPLETION PROGRAM 1. 3-1/2" completion assembly with Gas Uft Mandrels. (Gaslift design will be determined after OH logs). RIECF.. Naska 0il & Gas Cons. SPUD MUD PROPERTIES Wei0ht Marsh Vis Yield Pt. 10 sec eel 10 min _eel I;~ APl F.L. Hardness Spud 8.7 300 40-60 30-60 60-80 9-10 15-25 <200 Csg Pt. 9.5 100 20-40 15-20 20-30 9-10 15-25 <200 INTERMEDIATE HOLE MUD PROPERTIES Deoth Wei_eht YP 10 sec Gel 10 min Gel APl F.L. I~ Hardness TUFFS 9.5 - 9.8 15 - 25 12 - 15 25 - 30 <12 9.5 - 10.0 < 200 to Csg Pt. 9.8 - 10. S 20 - 30 12 - 15 25 - 30 6.0 - 8.0 9.5 - 10.0 < 200 At the top of the Tuffs, the fluid loss should be controled by the addition of Drispac SL, Resinex, and/or lignite. Polymer sweeps utilizing Biozan should be incorporated into the mud system to improve Iow shear rate rheology. PRODUCTION HOLE MUD PROPERTIES ~ Wei_eht YP 10 sec Gel 10 min Gel APl F.L. Iai:! Hardness to TD 9.Z-9.4 15 - 25 12 - 15 25 - 30 <8 9.5 - 10.0 < 200 The intermediate hole mud should be watered back to build the production hole mud. The fluid loss should be controlled with Drispac. Polymer sweeps utilizing Biozan should be incorporated into the mud system to improve Iow shear rate theology. RECF.]VED Alaska OiJ & {~a,5 COilS. GOt-ftt'R't$S'tO~ Anchorage MPI Z-66/SD-1Z CEMENT PROGRAM HALLIBURTON 13 3/8" SURFACE CASING CASING SIZE: 13 3/8", 68# ~ 40'F LEAD CEMENT TYPE: Type 'E" Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD:Z.17 ft3/sx APPROX #SACKS: 550 THICKENING TIME: 5+ hrs MIX WATER: 11.63 gps TAIL CEMENT TYPE: Premium ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD:1.16 ft3/sx APPROX #SACKS: 400 THICKENING TIME: 4 hrs MIX WATER: 5.00 gps TOP JOB CEMENT TYPE: Type 'C' Permafrost ADDITIVES: retarder WEIGHT: 15.6 ppg YIELD:0.94 ft3/sx MIX WATER: 3.5 gps APPROX #SACKS: 250 ~ 100 bbls fresh water ahead of lead slurry. The mixing temperature should be as cold as possible to prevent acceleration-approximately 35-40F. CEMENT VOLUME 1. Lead slurry + 400 sx Tail slurry w/40% excess over gauge hole. 2. Top job volume 250 sx. 9 5/8" INTERMEDIATE CASING CASING SIZE: 9 5/8", 47# ~ 135'F LEAD CEMENT TYPE: Premium ADDITIVES: 0.5% CFR-3 (Dispersant) + 3% Econolite (Extender) + 0.4% Halad-344 (Fluid Loss) WEIGHT: 11.0 ppg YIELD:3.24 ft3/sx MIX WATER: 20.4 gps APPROX #SACKS: 1000 PUMP TIME: S+hrs TAIL CEMENT TYPE: Premium ADDITIVES: 0.Z% CFR-3 (Dispersant) + 0.Z% Halad-344 (Fluid Loss) + HR-S (Retarder) WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gps APPROX #SACKS: 400 PUMP TIME: 4 hrs Retarder (HR-S) concentration will be based on actual lab tests. SPACERS; Pump 20 bbls ARCO Preflush; S0 bbls ARCO spacer ~ 11 ppg. OTHER CONSIDERATIONS: Continuously mix lead and tail slurries. Displace at 12-1 S bpm with rig pumps. CEMENT VOLUME 1. Lead Slurry based 90% of hole volume from top of tail slurry to surface casing shoe. 2. Tail Slurry to 1000' above shoe w/50% excess. RECEIVED 7" LINER CASING SIZE: 7", 29# CR-13 ~,J~: 140° F CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.5% Halad-344 (Fluid Loss) + 0.25% HR-5 (Retarder) Retarder (HR-5) concentration to be based on actual lab tests. MAY Alaska 0il & Gas Cons. :Anchorage WEIGHT: 15.8 ppg APPROX #SACKS: 375 YIELD: 1.1 5 ft3/sx MIX WATER: 5.00 gps THICKENING TIME: 3 hfs +1 hr ~surface RPA~.FR.~' PROPOSED DRILLING AND COMPLETION PROGRAM ENDICOTt MPI 2-66/SD-12 PROCEDURE 1) MIRU Doyon 15 Drilling Rig. N/U diverter and function test same. 2) Drill 16" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and test to 250 psi (low test) and 5000 psi (high test). 3) P/U 12-1/4" BHA and RIH. Test casing to 3500 psi for 30 minutes. Drill 10' of new hole and perform leak off test. 4) Drill 12-1/4" hole to casing point. 5) MU and run 9-5/8" casing and cement as per well plan. 6) RIH w/8-1/2" BHA and drill through reservoir to TD. 7) RU and run E-line logs. 8) MU 7" liner on 5" DP. RIH to TD. Cement same. Set liner hanger and packer. Circulate excess cement from well bore. POH. 9) MU casing scraper and clean out 7" liner. 10) Run 4-1/2" L-80 tubing and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 4000 psi. 11) NU and tree and test to 5000 psi. Release drilling rig. · Anticipated BHP: · Maximum Anticipated Surface Pressure: · Planned Completion Fluid: Notes: a. 5130 psi @ 10425' TVD SS 5262 psi @ 10825 TVD SS 5500 psi @ 11415' TVD SS RECEIVED 4358 psi 8.6 ppg Filtered Sea water MAY 2' 4 199 A~aska Oil & Gas Cons. Anchoraga The drilling program and surface system will conform to the regulations set forth in 20ACC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). c. Based on Endicott previous logs, no potential productive zones are anticipated above the Kekiktuk formation. d. No potential hazardous levels of H2S are anticipated in this well. DOYON 15 13 5/8" 5,000 psi Stack RKB I I I 9.00 4.65 HYDRIL 3.00 · i2.00 i I,, 2.00 4~ 1.85 5" PIPE RAM BLIND RAM MUD CROSS KR TO RF 4 1/2" x 7" VARIABLE PIPE RAM RI~ i FLO 11.32 R 14.32 16.32 20.17 39.05 13.95 4 FEET ABOVE GROUND LEVEL .- o ~OLE DIVERTER. SYSTE:M -::.:'." ( Twa lines venting 90 deg. apart in directions that ensure safe down wind venting, and ex- lending to a point at least 100' lrom any' potential''-'''' source of Ignition. 10' Full Opening Valves ' ' '35' ar as required ,.__! Dresser' Sleeve 10' Diveder Line 1. All pipe connections 150~ ANSI Flanges or welded connections and secured lo prevent movemenL 2. Manual 10" full opening valves mechanically connected to ensure that one valve is tail-sale open at all limes. 3. All tums are 90 deg. and targeted. 10' Full opening ball valve w/Hydraulic Actuator Cellar RECEIVED 20' Diverter Spool w/10' Side Culler JVJA¥ 2 4 NaS~.,0il & 6as Cons. 60mmissio~ MEM 1/3/90 DOYON RIG #15 MUD PIT SCHEMATIC CUTTINGS CONVEYOR DEGASSER MIX PIT TANK DESANDER PIT MUD CLEANER TANK SUCTION TANK PILL 235 BBLS 115 BBLS 210 BBLS 155 BBLS 235 BBLS PIT 10! BBLS HOLE FILL TANK 90 BBLS EQUIPMENT UTILIZED: 2 SETS OF BRANDT TOTAL FLOW SHALE SHAKERS 1 - DEMCO 3 - 12" CONE DESANDER : 1- TRIFLOW 16 - 4" CONE MUD CLEANER 1- DRILCO DEGASSER 1- PIONEER MARK !1 CENTRIFUGE 1- DRECO POOR BOY DEGASSER 2- PIONEER S-800 SIDEWINER MUD HOPPERS ITEM [1) Fee [2) Loc *;; CHECK LIST FOR NEW WELL PERMITS ;:* APPROVE DATE cas [14 thru 22] (5) BO.P[ ,,~"~. ~.. /, -~- ? ~ [23 thru 28] (6) Other //~' ~,,///_~ /~[ 29 thru 3~1 ] geo 1 ogy: eng i neet Ing' wa MTM A -K RAD Jf PC~. BEW dDH , , ev 12/92 o/6.011 . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. !.9. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33 Is permit fee attached ............................................... Is w.ell to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located'proper distance from other wells ..................... Is sufficient ~qdedicated acreage available in this 10oo1 ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before. 15-day wait ............................ Does operator have a bond in force ..................... · .............. Is a conservation order needed ........................................ Is administrative approval needed ..................... ~ .............. Is lease ntmber appropriate .......................................... Does well have a unique name & ntrnber ................................ Is conductor string provided ............. ; ....................... ~..- Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Wil 1 cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate we11bore separation proposed ............................. Is a dlverter system required ......... . .............................. Is drill ing fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOP[ attached .... Does BOP[ have sufficient pressure rating -- test to~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed condit ions presented... Lease & Well # Name and phone n~nber of contact to supply weekly progress data ...... Add i t i ona 1 requ i rements ...................... , ...................... INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA # SHORE YES NO J j REMARKS UM ~: SM Exp/Dev Inj TYPE' Redrill Rev , 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, informati~)n 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. LIS VERIFICATION LISTING FOR: BP EXPLORATION (ALASKA) WELL 2-66/SD-2 ENDICOTT RECEIVED FEB 0 ,J. 1994 ,Qil & Gas Cons. Commission Anchorage MICIJ(jFILHEP' BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR BP EXPLORATION (ALASKA) WELL 2-66/SD-12 ATCM ATC1 ATDC ATD1 BDCM BDC1 BDEM BDE1 BDIM BDI1 CADE CAD1 CPDE CPD1 DCCM DCC1 DLAM DLA1 DPEM DPE1 DPLM DPL1 DPSM DPS1 DRHM DRH1 DSAM DSA1 GRAM GRA1 GRCM GRC1 NFBM NFB1 NNBM NNB1 NPEM NPE1 NPIM NPI1 NPLM NPL1 NPSM NPS1 NRCM NRC1 PDCM PDCl PDDC PDD1 PDEM PDE1 PDIM PDI1 Attenuation Borehole~Corrected [RWD] Attenuation Borehele Corrected Relog 1 [RWD] Attenuation Dielectric Corrected [RWD] Attenuation Dielectric Corrected Relog 1 [RWD] Bulk Density Compensated [RWD] Bulk Density Compensated Relog 1 [RWD] Bulk Density Time Since Drilled [RWD] Bulk Density Time Since Drilled Relog 1 [RWD] Bulk Density Data Density Integrated [RWD] Bulk Density Data Density Integrated Relog 1 [RWD] Conductivity (AT) Dielectric Corrected [RWD] Conductivity (AT) Dielectric Corrected Relog 1 [RWD] Conductivity (PD) Dielectric Corrected [RWD] Conductivity (PD) Dielectric Corrected Relog 1 [RWD] Calculated Dielectric Constant Calculated Dielectric Constant Relog 1 Density Long Space Apparent [RWD] Density Long Space Apparent Relog 1 [RWD] Photoelectric Cross Section [RWD] Photoelectric Effect Relog 1 [RWD] Density Porosity (LS) [RWD] Density Porosity Umestone Matrix Relog 1 [RWD] Density Porosity (SS) [RWD] Density Porosity Sandstone Matrix Relog 1 [RWD] Delta RHO - Density [RWD] Delta Rho Correction Relog 1 [RWD] Density Short Space Apparent [RWD] Short Space Apparent Relog 1 [RWD] Ray Memory (APl) [RWD] Ray Memory (APl) Relog 1 [RWD] Ray Borehole Corrected [RWD] Ray Borehole Corrected Relog I [RWD] Far Base [Base] Far Base Relog 1 [RWD] Near Base [Base] Near Base Relog 1 [RWD] Porosity Time Since Drilled [RWD] Dens~y Gamma Gamma Gamma Gamma Neutron Neutron Neutron Neutron Neutron Neutron Porosity Neutron Porosity Neutron Porosity Neutron Porosity Neutron Porosity Neutron Porosity Neutron Porosity Neutron Porosity Neutron Porosity Phase Difference Phase Difference Phase Difference Phase Difference Phase Difference Phase Difference Phase Difference Phase Difference Time Since Drilled Relog 1 [RWD] Data Density Integrated [RWD] Data Density Integrated Relog I [RWD] (LS) Borehole Corr [RWD] (LS) Borehole Corr Relog 1 [RWD] (SS) Borehole Corr [RWD] (SS) Borehole Corr Relog I [RWD] Ratio Borehole Corr. [RWD] Ratio Borehole Corr. Relog 1 [RWD] Borehole Corrected [RWD] Borehole Corrected [RWD] Dielectric Corrected [RWD] Dielectric Corrected Relog 1 [RWD] Elapsed Time [RWD] Elapsed Time Relog 1 [RWD] Data Density Integrated [RWD] Data Density Integrated Relog 1 [RWD] -dB -dB -dB -dB g/cc g/cc mins mins pts pts mmho/m mmho/m mmho/m mmho/m g/cc g/cc B/e B/e p.u. p.u. p.u. p.u. g/cc g/cc g/cc g/cc MWD-API MWD-API cps MWD-API cps cps cps cps mins. mins. pts pts p.u. p.u. p.u. p.u. p.u. p.u. deg deg deg deg mins mins pts. pts. R^CM RAC1 RADE RAD1 ROPA ROPS RPCM RPC1 RPDE RPD1 TCDM TCD1 Note: Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Borehole Corrected Relog 1 [RWD] Resistivity (AT) Corrected Dielectric Effect [RWD] Resistivity (AT) Corrected for Dielectric Effect Relog I [RWD] Rate of Penetration Averaged Rate of Penetration - Resistivity (PD) Bor. ehole Corrected [RWD] Resistivity (PD) Borehole Corrected Relog I [RWD] ResistMty (PD) Corrected for Dielectric Effect [RWD] Resistivity (PD) Corrected for Dielectric Effect Relog I [RWD] CDS Temperature [RWD] CDS Temperature Relog 1 [RWD] AT is Attenuation PD is Phase Difference RWD is Recorded While Drilling ohm-m ohm-m ohm-m ohm-m fi/hr fi/hr ohm-m ohm-m ohm-m ohm-m deg F deg F Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Thu 6 JAN 94 10:26a = ECHOING INPUT PARAMETERS INPUT PARAMETER FILE: TAPESCAN.INP I 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 1 AUTOCURV = 0 , ! Automatic Curve renaming: 0--OFF, 1 =ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0--OFF, 1--ON 3 COMMENTS = 1 , ! Decode LIS Comment records: 0--OFF, 1 =ON 4 INFORECS = 1 , ! Decode LIS Information records: 0=NO,1 =YES 5 LISTMETHOD -- 0 , ! Listing Method: O--depth units 1 =tape units 6 ESTFREQ -- 100, ! Listing Frequency: Every n units 7 ESTMAX = 0 , ! Listing Maximum (O--no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0=OFF, 1 =ON 9 FORCETYP = 0 , ! (1 =BIT,2=MS ... thru 35=Array Accoustic) (see table) 10 WRITEASCll -- 0 , ! If 1, all ascii files will be written (file0001.dat, etc.) 11 WRITETAP = I , ! Write Tape-Image File: 0=NO,1 =YES 12 SPETLIS = I , ! If 1 and WRITETAP on, split US logical files to physical 13 SUBFILES -- /0/, ! Tape Subtile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END I= = USER INPUT PARAMETERS AUTOCURV -- 0, AUTOFILE = 0, COMMENTS -- 1 , INFORECS -- 1 , ESTMETHOD-- 0, ESTFREQ = 100, LISTMAX = 0, STATS = 0, FORCETYP -- 0, . WRITEASCll = 0 , WRITETAP = 1 , SPLITES = 1 , SUBFILES --/0/, INTERPOLATE--'YES' END !-- PROCESSING INTERVAL FROM 0.000 TO 0.000 ............. !-- CONSTANT PARAMETERS .......................................... AUTOCURV= O.O00000E+O0 AUTOFILE= O.O00000E+O0 COMMENTS= 1.00000 FORCETYP= O.O00000E+O0 INFORECS= 1.00000 MSTFREQ= 100.000 LISTMAX = O.O00000E+O0 LISTMETH= O.O00000E+O0 SELFTEST= O.O00000E+O0 SPMTLIS= 1.00000 STATS = O.O00000E+O0 WRITEASC= O.O00000E+O0 WRITE-rAP= 1.00000 dpcoef = 1.00000 dpcte = 1.00000 ddength= O.O00000E+O0 Iistwave= O.O00000E+O0 maxrecln= O.O00000E+O0 minrecln= O.O00000E+O0 nsamples= O.O00000E+O0 numcurvs= O.O00000E+O0 numdatar= O.O00000E+O0 numrecfl= O.O00000E+O0 tfendep = O.O00000E+O0 fflevsp = O.O00000E + O0 tfstdep = O.O00000E +00 wcrbot = O.O00000E +00 wcrlevsp= O.O00000E +00 wcrtop = O.O00000E +00 !-- ARRAY PARAMETERS SUBFILES(1) = SUBFILES(3) = SUBFILES(5) = SUBFILES(7) = SUBFILES(9) = SUBFILES(11) = SUBFILES(13) = SUBFILES(15) = SUBFILES(17) = SUBFILES(19) = SUBFILES(21) = SUBFILES(23) = SUBFILES(25) = SUBFILES(27) = SUBFILES(29) = SUBFILES(31) -- SUBFILES(33) = SUBFILES(35) -- SUBFILES(37) -- SUBFILES(39) = SUBFILES(41) = SUBFILES(43) -- SUBFILES(45) -- SUBFILES(47) -- SUBFILES(49) = SUBFILES(51) = SUBFILES(53) -- SUBFILES(55) = SUBFILES(57) = SUBFILES(59) -- SUBFILES(61) = SUBFILES(63) = SUBFILES(65) = SUBFILES(67) = SUBFILES(69) = SUBFILES(71) -- SUBFILES(73) -- SUBFILES(75) = SUBFILES(77) = SUBFILES(79) -- SUBFILES(81) -- SUBFILES(83) = SUBFILES(85) = SUaFILES(87) = SUBFILES(89) = SUBFILES(91) -- O.O00000E + O0 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 SUBFILES(2)---9999.00 SUBFILES(4) =-9999.00 SUBFILES(6) =-9999.00 SUBFILES(8) = -9999.00 SUBFILES(10) = -9999.00 SUBFILES(12) = -9999.00 SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( SUBFILES( 14) = -9999.00 16) = -9999.00 18) = -9999.00 20) = -9999.00 22) = -9999.00 24) -- -9999.00 2S) = -9999.00 28) = -9999.00 30) = -9999.oo 32) = -9999.00 34) = -9999.00 36) = -9999.oo 38) = -9999.00 40) = -9=J~.OO 42) = -9999.00 44) = -9999.oo 4s) = -9999.oo 4s) = -9999.oo 5o) = -9999.oo 52) = -9999.00 54) = -9999.00 56) = -9999.oo 58) = -9999.oo 60) = -9999.oo 62) = -9999.00 r,4) = -9999.00 as) = -9999.00 s8) = -9999.oo 70) = -9999.00 72) = -9999.00 74) = -9999.00 76) = -9999.00 TS) = -9999.oo SUBFILES(80) = -9999.00 SUBFILES(.82) = -9999.00 SUBFILES(84) = -9999.00 SUBFILES(86) = -9999.00 SUBFILES(88) = -9999.00 SUBFILES(90) = -9999,00 SUBFILES(92) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(95) = -9999.00 SUBFILES(97) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES(101) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(107) = -9999.00 SUBFILES(109) = -9999.00 SUBFILES(111) = -gggg.0G' SUBFILES(113) = -9999.00 SUBFILES(115) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(121) = -g999.00 SUBFILES(123) = -g999.00 SUBFILES(125) = -9999.00 SUBFILES(127) = -9999.00 SUBFILES(94) = -9999.00 SUBFILES(96) = -9999.00 SUBFILES(98) = -9999.00 SUBFILES(IO0) = -g999.00 SUBFILES(102) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(106) = -9999.00 SUBFILES(108) -- -9999.00 SUBFILES(110) -- -9999.00 SUBFILES(112) = -9999.00 SUBFILES(114) = -9999.00 SUBFILES(116) = -9999.00 SUBFILES(118) = -9999.00 SUBFILES(120) -- -9999.00 SUBFILES(122) = -9999.00 SUBFILES(124) = -9999.00 SUBFILES(126) -- -9999.00 SUBFILES(128) -- -9999.00 !- STRING PARAMETERS INTERPOL= YES Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: J:\1242\1242.TAP (Output Tape-Image file will be created) Usting M~thod ("LISTMETH') = O, Depth Unit oriented listing. Listing Frequency ("LISTFREQ") is every ( 100) units of Depth. Listing output limiting (LISTMAX) not enabled... (to enable list limiting set LISTMAX positive) Data Statistics reporting (~'STATS") has not been enabled. (Specify STATS = 1 to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=O). Automatic "FILE= n" card generation is disabled. (This is the program default, AUTOFILE=O) (Specify AUTOFILE = 1 to enable this feature) LIS comment record decoding (COMMENTS= 1) has been enabled by user input. LIS information record decoding (INFORECS= 1) has been enabled by user input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC= 1) Tape Subtile 1 is type: LIS **** REEL HEADER **** MWD g4/ /s 1242 01 **** TAPE HEADER **** MWD 94/1/6 1242 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subtile 2 is type: US LIS COMMENT RECORD(s): 12345678901234567890123456789012345 678901234567890123456789012345678901234567890 TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS .,. WELL NAME: 2-66/SD-12 APl NUMBER: 50-029-22374 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: BAKER HUGHES INTEQ TAPE CREATION DATE: 06-JAN-94 JOB DATA BIT RUN1 BIT RUN2 BIT RUN3 JOB NUMBER: 1242 1242 1242 LOGGING ENGINEER: T. FOSTER R. ST. PIERRE J. BURTON OPERATOR WITNESS: S. WALLS S. WALLS S. WALLS SURFACE LOCATION SECTION: 36 TOWNSHIP: 12 RANGE: 16 FNL: FSL: 3151 FEL: 2360 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 56.00 GROUND LEVEL: 10.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 16.000 30.000 110.0 2ND STRING 12.250 13.375 2871.0 3RD STRING 8.500 9.625 13496.0 PRODUCTION STRING REMARKS: $ **** FILE HEADER **** MWD .001 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 13911.0 15201.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) ........ EQUIVALENT UNSHIFTED DEPTH ........ BASELINE DEPTH GRAM ROPS RADE RPDE 13906.7 13890.0 13907.7 13921.0 13921.7 13905.0 13924.7 13930.0 13931.7 13915.7 13934.0 13918.0 I 13934.5 13918.5 13934.7 13919.0 13935.2 I 13939.0 13923.2 13939.2 13923.7 13941.0 13943.5 13928.0 I 13945.5 13930.5 13945.7 13950.2 13937.5 13953.5 13941.0 '~ 13956.0 13956.5 13961.0 13975.5 13984.2 13970.5 13989.7 13976.2 13990.0 13976.5 13991.5 13978.7 13994.2 13980.2 13994.7 13980.7 13997.0 14000.7 14002.7 13985.0 14003.7 13986.0 14004.0 14012.5 14014.0 14026.7 14027.7 14007.5 1 4028.0 14034.2 14045.5 14049.2 14032.0 14054.7 ,- 1 4056.7 1 4057.0 1 4040.2 13890.0 13890.0 13890.0 13890.0 13903.2 13905.0 13905.0 13905.0 13906.5 13914.2 13915.7 13915.7 13915.7 13918.0 13918.0 13918.0 13918.5 13918.5 13918.5 13919.0 13919.0 13919.0 13921.0 13923.2 13923.2 13923.2 13923.7 13923.7 13923.7 13926,7 13928.0 13928.0 13928.0 13930.5 13930.5 13930.5 13930.7 13937.5 13941.0 13940.2 13962.2 13970.5 13976.2 13976.5 13978.7 13980.2 13980.7 13983.2 13970.5 13976.2 13985.0 13986.0 13995.5 14009.0 140O7.5 14025.5 14032.0 1 4036.2 14040.2 13941.2 13940.2 13948.5 13962.2 13963.5 13970.5 13976.2 13983.2 13981.7 13987.2 13994.7 13~5.5 14009.0 14011.5 14017.2 14025.5 14036.2 14040.2 NFBM BASEUNE DEPTH 14070.5 14071.5 14O72.0 14O72.5 14O73.0 14O75.0 14075.2 14075.7 14076.2 14080.7 14082.7 14O85.0 14087.7 14092.0 14O97.5 141O0.2 141O6.0 14111.2 14114.5 14120.5 14124.5 14130.0 14133.0 14134.5 14139.7 14140.0 14140.5 14140.7 14142.5 14143.0 14144.5 14144.7 14145.2 14145.5 14145.7 14146.0 14150.0 14150.2 14'152.7 14153.0 14153.2 14153.7 14154.0 14154.2 14157.0 14157.5 14160.7 14163.7 14164.2 14164.7 14165.2 14165.7 14166.2 14167.0 14171.5 14173.5 14173.7 14175.2 14175.7 GRAM ROPS RADE RPDE NFBM 14054.5 14055.5 14055.7 14056.2 14056.5 14O58.5 14059.0 14O59.5 14059.7 14O64.5 14O63.2 14116.2 14129.2 14147.0 14146.5 14060.2 14073.5 14076.0 14082.2 14116.2 14129.2 14135.0 14147.7 14147.0 14146.5 14116.2 14129.2 14069.7 14073.5 14O76.0 14082.2 14081.5 14084.5 14O93.O 14094.7 14103.0 14107.7 14113.5 14116.2 14117.5 14121.7 14122.2 14122.7 14123.2 14125.0 14125.2 14126.7 14127.2 14127.7 14128.2 14128.7 14129.2 14133.0 14133.5 14136.0 14136.2 14136.5 14137.0 14137.5 14135.0 14140.5 14140.7 14147.7 14146.O 141 14146.7 14147.2 14147.5 14148.0 14154.5 14156.5 14157.0 14158.5 14158.7 BASELINE DEPTH GRAM ROPS RADE RPDE NFBM 14178.7 14179.0 14179.5 14182.5 14183.0 14186.2 14186.7 14190.2 14190.5 14190.7 14191.0 14169.7 14192.7 14202.0 14203.7 14206.0 14190.0 14208.2 14208.7 14193.2 14213.2 14197.2 14214.5 14217.5 14221.2 14204.0 14224.7 14233.7 14234.5 14218.2 14237.2 14221.5 14241.5 14243.2 14227.2 14247.2 14249.0 14232.5 14252.5 14257.0 14240.7 14257.5 14241.0 14258.5 14242.0. 14258.7 14242.2 14261.7 14263.7 14246.2 14271.0 14252.0 14274.5 14257.7 14281.7 14265.0 14263.7 14285.5 14267.2 14288.0 14291.7 14272.5 14293.2 14275.0 14294.2 14300.2 14281.0 14301.7 14307.5 14289.0 1 4309.0 1429i .0 14311.2 14317.2 14297.0 14319.7 14321.2 14323.5 14304.7 14323.7 14305.0 14324.0 14305.5 1 4326.2 1 4308.5 14161.7 14162.2 14162.5 14165.5 14165.7 14168.5 14168.5 14169.0 14169.2 14172.7 14173.2 14173.5 14190.0 14193.2 14197.2 14169.7 14177.0 14177.0 14184.2 14184.2 14180.2 14190.0 14190.0 14193.0 14193.2 14193.2 14197.2 14197.2 14199.0 14200.0 14200.0 14204.0 14204.0 14208.0 14220.2 14218.2 14218.2 14218.2 14221.5 14221.5 14221.5 14225.7 14227.2 14227.2 14227.2 14231.0 14232.5 14232.5 14232.5 14235.2 14240.7 14240.7 14241.0 14241.0 14242.0 14242.0 14242.2 14242.2 14245.0 14246.2 14246.2 14252.0 14252.0 14257.7 14257.7 14265.0 14265.0 14262.2 14267.2 14267.2 14267.2 14271.0 14271.0 14272.5 14275.0 14204.0 14240.7 14241.0 14242.0 14242.2 14246.2 14252.0 14257.7 14265.0 1~81.0 14282.7 14289.0 14291.0 14290.5 14297.0 14301.2 14290.5 14274.7 14282.7 14263.5 14304.7 14305.0 14305.5 14308.5 14301.2 143O3.0 14304.7 14304.7 14305.0 14305.0 14305.5 14305.5 14308.5 14308.5 BASEUNE DEPTH GRAM ROPS RADE RPDE NFBM 14329.2 14330.7 14331.0 14331.2 14331.5 14331.7 14336.0 14336.2 14336.5 14336.7 14337.0 14340.2 14341.0 14341.2 14341.5 14342.5 14343.7 14344.2 14345.7 14347.7 14348.0 14348.5 14350.5 14353.0 14354.5 14358.0 14358.2 14358.7 14360.0 14360.5 1 4364.2 14364.5 14369.0 14372.2 14373.0 14375.2 14379.2 14379.5 14379.7 14364.7 14387.5 14388.0 14388.5 14389.5 1 4390.5 14390.7 14391.0 14391.2 14391.7 14392.2 14392.7 14395.0 14398.5 14400.0 144O0.5 144O3.7 14408.2 143O9.7 14311.2 14311.7 14311.2 14311.2 14311.2 14311.2 14312.0 14311.5 14311.5 14311.5 14311.5 14312.5 14312.0 14312.0 14312.0 14312.0 14316.2 "14316.2 14316.2 14316.2 14316.2 14316.5 14317.0 14319.0 14321.2 14321.2 14323.0 14323.5 14320.7 14320.7 14324.7 14324.5 14324.5 14328.5 14328.5 14330.7 14330.7 14326.2 14330.0 14329.5 14329.5 14330.2 14332.2 14334.5 14335.7 14335.7 14339.2 14339.2 14339.2 14339.2 14339.7 14339.7 14339.7 14339.7 14340.2 14340.2 14340.2 14340.2 14341.5 14341.7 14341.7 14341.7 14341.7 14344.7 14344.7 14344.7 14344.7 14345.2 14350.0 14350.0 14350.0 14350.0 14353.2 14353.2 14353.2 14353.2 14352.0 14355.7 14355.7 14355.7 14355.7 14360.7 14358.0 14358.0 14358.0 14358.0 14361.0 14383.2 14383.2 14383.2 14383.2 14368.7 14369.0 14369.2 14370.0 14370.0 14370.0 14370.0 14370.2 14370.5 14370.7 14371.2 14371.7 14372.0 14372.5 14372.7 14373.5 14373.5 14373.5 14373.5 14376.7 14376.7 14376.7 14376.7 14379.0 14379.2 14379.2 14379.2 14379.2 14383.0 14383.0 14383.0 14383.0 14385.7 BASEUNE DEPTH GRAM ROPS RADE RPDE NFBM 14414.2 14414.5 14417.7 14418.0 14418.5 14419.0 14419.2 14420.2 14420.7 1 4426.0 1 4426.2 14429.2 14434.2 1~.~.~5.0 14462.7 14469.5 14472.7 14473.2 14475.0 14485.0 14485.2 14489.5 14493.0 144,94.2 14495.2 14496.0 14496.7 14499.0 14499.2 145O6.5 14512.5 14523.0 14523.7 14526.0 14528.7 14537.2 14544.7 14547.7 14549.7 14552.7 14555.7 14558.5 14560.2 14576.2 14580.2 14582.2 14585.7 14588.2 14590.7 14591.2 14593.7 14596.0 14604.2 14606.7 14609.2 146O9.5 14609.7 14393.7 14395.5 14395.5 14396.5 14396.7 14396.7 14396.7 14396.7 14397.0 14397.0 14397.0 14397.0 14397.5 14397.5 14397.5 14397.5 14398.0 14398.0 14398.0 14398.0 14399.0 14399.0 14399.0 14399.0 14399.2 14399.2 14399.2 14399.2 14404.5 14405.5 14405.5 14408.2 14412.0 14412.0 1 442 3.7 1~,~2.2 14449.2 14449.2 14449.2 14449.2 14452.5 14452.5 14452.5 14452.5 14447.5 14456.2 14456.2 14456.2 14456.2 14464.2 14464.2 14464.2 14464.2 14464.5 14464.5 14464.5 14464.5 14466.2 14472.7 14472.7 14474.0 14474.0 14475.5 14475.5 14475.7 14477.2 14477.2 14480.2 14480.2 1 4479.2 14484.5 14484.5 14492.0 14492.0 14492.0 14492.0 14500.0 14500.0 14500.0 14500.0 14497.2 14501.7 14501.7 14501.7 14501.7 14508.0 1.4508.0 14502.7 14516.5 14516.5 14520.0 14521.0 14521.0 14521.0 14521.0 14523.0 14523.0 14523.0 14523.0 14527.5 14527.5 14529.2 14529.2 14529.2 14529.2 14527.7 14533.2 14533.2 14533.2 14533.2 14532.7 14551.5 14551.5 14555.2 14555.2 14554.5 14554.5 14561.5 14561.5 14564.0 14564.0 14562.5 14562.5 14567.0 14567.0 14569.5 14569.5 14571.5 14571.5 14577.0 14577.0 14587.7 14587.7 14590.2 14590.2 14590.7 14590.7 14591.0 14591.0 · BASELINE DEPTH GRAM ROPS RADE RPDE NFBM 14610.0 14591.2 14591.2 14618.5 14600.2 1 4620.7 146O2.5 14624.2 14608.7 14608.7 14624.7 14609.2 14609.2 14625.2 14601.0 14601.0 14635.2 14612.5 14612.5 14659.5 14637.0 14637.0 14678.2 14656.7 14656.7 14701.7 14682.0 14682.0 14704.2 14689.7 14689.7 14705.2 14691.7 14691.7 14707.7 14684.7 14709.0 14686.2 14686.2 14710.5 14694.5 14694.5 14711.0 14687.7 14687.7 14712.0 14687.5 14714.7 14690.5 14690.5 14715.2 14698.5 14698.5 14715.7 14690.0 14716.2 14694.0 14694.0 14718.5 1 4695.0 14719.2 14701.2 14701.2 14722.5 14700.7 14723.2 146,98.5 14698.5 14724.0 14705.0 14705.0 14725.2 14704.7 14725.5 14701.7 14701.7 14726.7 14707.5 14707.5 14728.7 14708.0 14729.2 14711.0 14711.0 14731.0 14710.7 14731.2 14714.7 14714.7 14734.7 14713.7 14735.0 14713.0 14713.0 14737.2 14716.0 14716.0 14741.0 14719.5 14759.7 14740.5 14740.5 14761.2 14742.0 14742.0 14740.7 14740.7 14762.2 14740.7 14767.2 14747.7 14747.7 14748.0 14748.0 14767.5 14747.0 14770.5 14750.5 14750.5 14770.7 14749.5 14780.2 14760.7 14781.0 14761.2 14761.2 14782.0 14761.0 14761.0 14782.2 14762.7 14782.5 14764.0 14764.0 14784.5 14764.7 14785.2 14766.0 14766.0 14786.2 14767.0 14787.5 14768.7 14768.7 14793.2 14773.2 14773.2 14796.5 14778.0 14778.0 14798.5 14779.5 14779.5 14799.0 14780.7 BASEUNE DEPTH GRAM ROPS RADE RPDE NFBM I . 14802.0 14802.2 14803.7 14807.0 14807.2 14814.0 14815.7 14817.7 14818.0 1 4824.0 14824.5 1 4826.0 1 4826.2 14827.7 1 4829.0 1 4829.5 14833.5 14833.7 14834.5 14848.5 14852.0 14853.2 14854.7 14856.5 14860.0 14862.7 14863.2 14866.2 14866.7 14867.0 14867.2 14867.7 14868.2 14868.7 14869.5 14869.7 14870.0 14870.5 14871.2 14871.7 14873.2 1 4875.0 14876.7 14877.2 14878.0 14878.2 14878.5 14878.7 14881.5 14881.7 14882.0 14882.2 14882.7 14883.0 14883.2 14885.7 14886.2 14784.2 14784.2 14784.2 14783.0 14783.0 14788.5 14788.5 14788.2 14795.2 14795.2 14796.7 14796.7 14799.0 14799.0 14799.5 14799.5 14805.5 14805.5 14806.5 14805.7 14805.7 14807.2 14807.2 14807.7 14807.7 14808.0 14808.0 14810.5 14810.5 14810.7 14810.7 14814.7 14814.7 14815.2 14815.2 14816.0 14816.0 14830.7 14830.7 14832.5 14832.5 14839.2 14839.2 14836.2 14838.0 14838.0 14841.5 14841.5 14841.5 14845.2 14844.7 14844.7 14847.5 14847.5 14848.0 14853.7 14853.7 14848.5 14849.0 14849.5 14849.7 14850.0 14850.0 14851.0 14851.5 14851.7 14852.0 14859.2 14859.2 14853.0 14853.0 14856.2 14856.2 14862.7 14862.7 14854.7 14857.7 14858.0 14858.7 14859.2 14859.5 14860.0 14862.7 14863.0 14865.0 14865.0 14863.7 14864.0 14864.2 14868.7 14868.7 14866.7 14866.7 14866.7 BASELINE DEPTH GRAM ROPS RADE RPDE NFBM 14887.0 14867.7 14887.7 14868.0 14888.2 14868.5 14888.5 14869.0 14889.7 14870.2 148,90.0 14870.7 14890.5 14872.0 "14872.0 14891.0 14871.7 14891.2 1 4872.2 14891.5 14872.0 14872.0 14893.2 14875.0 14893.5 14875.2 14893.7 14875.7 14894.0 14875.0 14875.0 14894.2 14875.5 14875.5 14894.7 14876.0 14876.0 14896.2 14878.2 14896.7 14878.5 14897.7 14879.0 14879.0 14898.7 14880.0 14880.0 14900.0 14881.7 14900.7 14882.5 14882.5 14901.5 14882.5 14882.5 14909.2 14889.5 14889.5 14910.7 14889.0 14889.0 14913.7 14890.7 14915.2 14894.0 14894.0 14916.2 14893.2 14917.2 14893.7 14893.7 14919.2 14896.7 14920.5 14896.5 14896.5 14922.5 14899.7 14923.7 14900.0 14900.0 14926.7 14904.2 14904.2 14903.7 14928.2 14905.0 14905.0 14931.7 14908.5 14'932.5 14908.5 14908.5 14933.2 14909.7 14909.7 14933.7 14910.0 14910.0 14934.0 14909.5 14945.0 14921.5 14947.7 14923.7 14923.7 14948.7 14924.5 14950.7 14926.7 14926.7 14926.7 14926.7 14951.7 14927.2 14952.5 14928.7 14928.7 14928.7 14928.7 14954.0 14929.7 14957.2 14933.5 14958.5 14934.5 14934.5 14934.5 14934.5 14964.2 '14941.2 14941.2 1496 7. 0 14942.7 14969.2 14945.5 14971.2 14946.0 14946.0 14972.0 14947.7 14947.7 14974.0 14950.5 14976.2 14951.2 14951.2 14951.7 14951.7 14978.2 14953.7 14953.7 BASEUNE DEPTH GRAM ROPS RADE RPDE NFBM 14978.7 14955.0 14980.7 14955.5 14955.5 14981.2 14957.2 14957.2 14984.2 14960.0 14987.0 14963.5 14963.5 14989.0 14965.5 14965.5 14,989.2 14967.5 'i4967.5 14999.7 14975.0 14975.0 15001.5 14976.5 14976.5 15003.0 14979.5 15004.2 14980.0 14980.0 15004.5 14981.7 14981.7 15010.5 14986.0 14986.0 15011.0 14982.5 14982.5 15012.0 14988.2 15012.7 14984.0 14984.0 15013.2 14989.2 14989.2 15017.2 14993.0 14993.0 15018.5 14991.2 14991.2 15019.2 14993.0 14993.0 15021.2 14995.0 14995.0 15023.2 14999.7 14999.7 15027.7 15008.7 15008.7 15031.7 15013.2 15013.2 15032.0 15003.5 15035.2 15007.7 15037.2 15018.2 15018.2 15041.5 15014.5 15042.5 15018.2 15018.2 15042.7 15020.0 15020.0 15043.0 15017.7 15045.2 15018.5 15045.7 15023.5 15023.5 15067.2 15037.2 15037.2 15072.2 15042.7 15042.7 15183.2 15210.0 15183.2 15210.0 $ BASELINE DEPTH NNBM NPSM BDCM DPEM DRHM 13892.5 13907.O 13907.7 13910.0 13911.7 13919.O 13921.0 13924.5 13924.7 13927.2 13930.0 13930.2 13935.2 13941.0 13945.7 13949.2 13955.7 13956.0 13890.0 13890.0 13890.0 13904.5 13904.5 13904.5 13890.0 13890.0 13906.7 13906.7 13906.7 13910.7 13910.7 13910.7 13920.2 13920.2 13920.2 13903.2 13903.2 13922.0 13922.0 13922.0 13923.5 13923.5 13923.5 13906.5 13906.5 13926.5 13926.5 13926.5 13914.2 13914.2 13928.7 13928.7 13928.7 13921.0 13921.0 13926.7 13926.7 13930.7 13930.7 13937.2 13937.2 13937.2 13942.5 13942.5 13942.5 13941.2 13941.2 BASEUNE DEPTH GRAM ROPS RADE RPDE NFBM 13961.0 13971.0 13975.5 13975.7 13982.2 13994.7 13997.5 14000.7 140O2.2 14004.0 14005.0 14008.7 14012.0 14012.5 14017.0 14023.5 14027.2 14028.0 14034.2 14043.0 14043.2 14047.0 14O47.5 14047.7 14048.2 14056.7 14070.5 14O71.5 14072.0 14072.5 14073.0 1,4075.0 14075.2 14075.7 14076.2 14O80.0 14080.7 14085.0 14091.2 14096.2 14100.2 14103.5 14106.0 14111.2 14111.5 14114.5 14120.5 14124.5 14124.7 14130.0 14134.5 14139.7 14140.0 14140.5 14140.7 14142.5 14143.0 13948.5 13948.5 13945.7 13945.7 13945.7 13957.7 13957.7 13957.7 13963.5 13963.5 13963.5 13963.5 13963.5 13970.2 13970.2 13970.2 13978.2 13978.2 13978.2 13985.0 13985.0 13985.0 13981.7 13981.7 13988.7 13988.7 13988.7 13987.2 13987.2 13994.7 13994.7 13994.7 13999.5 13999.5 13999.5 14000.7 14000.7 14000.7 13994.7 13994.7 14004.7 14004.7 14004.7 14008.0 14008.0 14008.0 14010.5 14010.5 14010.5 14011.5 14011.5 14017.2 14017.2 14024.2 14024.2 14024.2 14024.5 14024.5 14024.5 14029.0 14029.0 14029.0 14029.5 14029.5 14029.5 14030.0 14030.0 14030.0 14030.5 14030.5 14030.5 14040.2 14040.2 14054.5 14054.5 14055.5 14055.5 14055.7 14055.7 14056.2 14056.2 14056.5 14056.5 14058.5 14058.5 14059.0 14059.0 14059.5 14059.5 14059.7 14059.7 14064.2 14064.2 14064.2 14064.5 14064.5 14069.7 14069.7 14067.2 14067.2 14067.2 14071.7 14071.7 14071.7 14075.7 14075.7 14075.7 14081.5 14081.5 14079.7 14079.7 14079.7 14084.5 14064.5 14093.0 14093.0 14089.7 14089.7 14089.7 14094.7 14094.7 14093.2 14093.2 14093.2 14103.0 14103.0 14107.7 14107.7 14105.5 14105.5 14105.5 14113.5 14113.5 14108.2 14108.2 14108.2 14117.5 14117.5 14121.7 14121.7 14122.2 14122.2 14122.7 14122.7 14123.2 14123.2 14125.0 14125.0 14125.2 14125.2 BASELINE DEPTH GRAM ROPS RADE RPDE NFBM 14144,5 14126,7 14126,7 14144.7 14127.2 14127,2 14145,2 14127,7 14127,7 14145.5 14128.2 14128,2 14145.7 14128,7 14128,7 14146,7 14129.5 14150.0 14133.0 14133.0 14150.2 14133.5 14133.5 14151,7 14135.0 14152,7 14136.0 14136.0 14153.0 14136.2 14136,2 14153,2 14136.5 14136,5 14153.7 14137.0 14137.0 14154,0 14137,5 14137,5 14156,7 14140,7 14157.0 14140.5 14140.5 14157.5 14140.7 14140.7 14163.5 14149,5 14163,7 14146.0 14146,0 14164.2 14146.5 14146.5 14164,7 14146.7 14146.7 14165,2 14147.2 14147,2 14165,7 14147.5 14147.5 14166,2 14146,0 14146,0 14170,0 14152,7 14171.5 14154.5 14154,5 14173,5 14156,5 14156,5 14173,7 14157,0 14157,0 14175,2. 14158,5 14158,5 14175,7 14158.7 14158.7 14176,7 14158,2 14178,7 14161,7 14161,7 14179,0 14162.2 14162,2 14179,5 14162,5 14162,5 14182,5 14165,5 14165.5 14163,0 14165,7 14165,7 14186,2 14169,0 14169,0 14186,7 14169,2 14169,2 14188.5 14169.5 14190,2 14172,7 14172,7 14190,5 14173,2 14173,2 14190,7 14173,5 14173,5 14193,7 · 14175,2 14203.2 14187,2 14203,7 14180,2 14180,2 14208,2 14193,0 14193,0 14209,0 14190,2 14212,7 14195,2 14214.5 14199,0 14199.0 14218,2 14197,0 14222,0 14210,5 14224.7 14208,0 14208,0 14225,5 14217.0 14229,0 14219,2 14233,7 14220.2 14220,2 14241.5 14225.7 14225,7 14242.2 14224.0 14129,5 14129.5 14135.0 14135.0 14140,7 14140,7 14149,5 14149.5 14152,7 14152.7 14158,2 14158,2 14161,2 14161.2 14161.2 14163,0 14163,0 14163,0 14169.5 14169.5 14175,2 14175,2 14187.2 14187,2 14190,2 14190,2 · 14195,2 14195,2 14197,0 14197,0 14210,5 14210,5 14217.0 14217.0 14219,2 14219.2 14224.0 14224.0 BASELINE DEPTH GRAM ROPS RADE RPDE NFBM 14247.2 14252.5 14253.5 14261.7 14270.7 14275.5 14283.7 14285.0 14288.5 14292.2 14294.2 14296.0 14301.7 14305.0 143O9.5 14314.5 14320.7 14321.2 14329.2 14330.7 14331.0 14331.2 14331.5 14336.2 14336.5 14336.7 14337.0 14340.5 14341.0 14341.2 14342.5 14344.2 14346.5 14348.0 14348.5 14349.2 14350.5 14351.5 14353.0 14360.0 14362.7 14364.5 14369.5 14373.0 14374.7 14379.2 14379.7 14364.7 14387.5 14388.0 14388.5 14389.5 14390.5 14390.7 14391.0 14391.2 14391.7 14231.0 14231.0 14235.2 14235.2 14245.5 14245.5 14245.5 14245.0 14245.0 14253.2 14253.2 14253.2 14262.2 14262.2 14262.2 14262.2 "14262.2 14268.5 14268.5 14268.5 14271.5 14271.5 14271.5 14276.0 14276.0 14276.0 14274.7 14274.7 14277.7 14277.7 14277.7 14283.5 14283.5 14286.2 14286.2 14286.2 14289.7 14289.7 14289.7 14296.0 14296.0 14296.0 14302.5 14302.5 14302.5 14303.0 14303.0 14309.7 14309.7 14311.2 14311.2 14311.7 14311.7 14312.0 14312.0 14312.5 14312.5 14316.2 14316.2 14316.5 14316.5' 14317.0 14317.0 14319.0 14319.0 14319.0 14319.0 14319.0 14323.0 14323.0 14323.5 14323.5 14324.7 14324.7 14321.0 14321.0 14321.0 14326.2 14326.2 14327.0 14327.0 14327.0 14330.0 14330.0 14330.2 14330.2 14329.2 14329.2 14329.2 14332.2 14332.2 14332.7 14332.7 14332.7 14334.5 14334.5 14341.5 14341.5 14345.7 14345.7 14345.7 14345.2 14345.2 14350.0 14350.0 14350.0 14352.0 14352.0 14355.7 14355.7 14355.7 14360.7 14360.7 14361.0 14361.0 14365.5 14365.5 14365.5 14368.7 14368.7 14369.0 14368.0 14369.2 14369.2 14370.2 14370.2 14370.5 14370.5 14370.7 14370.7 14371.2 14371.2 14371.7 14371.7 14372.0 14372.0 BASEUNE DEPTH GRAM ROPS RADE RPDE NFBM 14392.2 14392.7 14398.7 14400.0 14403.2 14408.2 14409.0 14414.2 14414.5 14417.7 14423.5 1 4426.0 1 4426.2 1 4429.2 14434.7 14442.2 1~.~.~.~,.7 14445.0 14'71.9.5 14455.5 14462.2 14462.7 14473.2 14484.7 14489.5 14491.5 14498.0 14496.7 14499.2 14516.5 14523.2 14523.7 14528.7 14544.7 14548.7 14550.5 14554.7 14555.7 14560.2 14577.7 14587.5 14593.7 14818.5 14620.7 14631.2 14642.2 14662.0 14702.0 14707,7 14708.0 14712.0 14713.0 14715.7 14718.5 14721.0 14722,5 14725.2 14372.5 14372.5 14372.7 14372.7 14378.5 14378.5 14378.5 14379.0 14379.0 14382.0 14382.0 14382.0 14385.7 14385.7 14385.5 14385.5 14385.5 14393.7 14393.7 14389.7 14389.7 14389.7 14396.5 14396.5 14402.0 14402.0 14402.0 14404.5 14404.5 14404.7 14404.7 14404.7 14408.2 14408.2 14407.5 14407.5 14407.5 14413.2 14413.2 14413.2 14425.5 14425.5 14425.5 14428.7 14428.7 14428.7 14423.7 14423.7 14433.5 14433.5 14433.5 14441.0 14441.0 1~.~.1.0 14449.0 1~.~.~.9.014449.0 14442.2 14442.2 14447.5 1~.~7.5 14467.0 14467.0 14467.0 14466.2 14466.2 14473.2 14473.2 14473.2 14475.7 14475.7 14475.2 14475.2 14475.2 1.4479.2 14479.2 14477.7 14477.7 14477.7 14497.5 14497.5 14497.5 14503.0 14503.0 14503.0 14497.2 14497.2 14502.7 14502.7 14520.0 14520.0 14518.0 14518.0 14518.0 14519.7 14519.7 14519.7 14527.0 14527.0 14527.0 14527.7 14527.7 14532.7 14532.7 14551.0 14551.0 14551.0 14562.2 14562.2 14562.2 14568.2 14568.2 14568.2 14600.2 14600.2 14602.5 14602.5 14608.5 14608.5 14608.5 14619.5 14619.5 14619.5 14639.7 14639.7 14639.7 14680.5 14680.5 14680.5 14684.7 14684.7 14686.7 14686.7 14686.7 14687.5 14687.5 14689.7 14689.7 14689.7 14690.0 14690.0 14695.0 14695.0 14698.0 14698.0 14698.0 14700.7 14700.7 14704.7 14704.7 BASELINE DEPTH GRAM ROPS RADE RPDE NFBM 14726.0 14728.7 14730.2 14731.0 14734.7 14741.0 14758.0 14762.2 14767.0 14767.5 14770.7 14780.2 14782.2 14784.5 14786.2 14796.2 14799.0 14800.5 148O2.0 14805.2 14807.2 14824.0 14826.7 14838.5 14844.2 14852.2 14854.7 14860.0 14860.2 14862.2 14862.7 14866.0 14866.7 14867.0 14867.2 14867.7 14868.2 14869.2 14869.5 14869.7 14870.0 14870.5 14873.2 14876.7 14877.2 14878.0 14878.2 14878.5 14878.7 14881.5 14882.0 14882.7 14883.0 14883.2 14883.5 14885.7 14887.O 14704.7 14704.7 14704.7 14708.0 14708.0 14708.5 14708.5 14708.5 14710.7 14710.7 14713.7 14713.7 14719.5 14719.5 14739.5 14739.5 14739.5 14740.7 14740.7 14747.7 14747.7 14747.7 14747.0 14747.0 14749.5 14749.5 14760.7 14760.7 14762.7 14762.7 14764.7 14764.7 14767.0 14767.0 14776.2 14776.2 14776.2 14780.7 14780.7 14780.5 14780.5 14780.5 14784.2 14764.2 14785.2 14785.2 14785.2 14788.2 14788.2 14806.5 14806.5 14807.5 14807.5 14807.5 14820.5 14820.5 14820.5 14825.7 14825.7 14825.7 14833.0 14833.0 14833.0 14836.2 14836.2 14841.5 14841.5 14840.0 14840.0 14840.0 14842.7 14842.7 14842.7 14845.2 14845.2 14847.2 14847.2 14647.2 14848.0 14848.0 14848.5 14848.5 14849.0 14849.0 14849.5 14849.5 14849.7 14849.7 14849.7 14849.7 14849.7 14851.0 14851.0 14851.5 14851.5 14851.7 14851.7 14852.0 14852.0 14854.7 14854.7 14857.7 14857.7 14858.0 14858.0 14858.7 14858.7 14859.2 14859.2 14859.5 14859.5 14860.0 14860.0 14862.7 14862.7 14863.0 14863.0 14863.7 14863.7 14864.0 14864.0 14864.2 14864.2 14865.0 14865.0 14865.0 14866.7 14866.7 14867.7 14867.7 BASEUNE DEPTH GRAM ROPS RADE RPDE NFBM 14887.2 14887.7 14888.2 14888.5 14889.7 14890.0 14891.0 14891.2 14893.2 14893.5 14893.7 14896.2 14896.7 14900.0 14907.5 14913.7 14916.2 14918.0 14919.2 14921.2 14922.5 14925.0 14926.7 14929.7 14931.7 14934.0 14936.2 14945.0 14948.7 14949.0 14951.7 14952.0 14954.0 14955.2 14957.2 14963.7 14967.0 14969.2 14971.0 14974.0 14978.7 14984.2 14984.5 14993.2 1'4997.2 15000.2 15003.0 15OO8.5 15012.0 15014.0 15021.0 15030.5 15032.0 15032.7 15035.2 15041.5 15043.0 14869.5 14869.5 14869.5 14868.0 14868.0 14868.5 14868.5 14869.0 14869.0 14870.2 14870.2 14870.7 14870.7 14871.7 14871.7 14872.2 14872.2 14875.0 14875.0 14875.2 14875.2 14875.7 14875.7 14878.2 14878.2 14878.5 14878.5 14876.2 14876.2 14876.2 14881.7 14881.7 14884.2 14884.2 14884.2 14890.7 14890.7 14893.2 14893.2 14892.2 14892.2 14892.2 14896.7 14896.7 14898.7 14898.7 14898.7 14899.7 14899.7 14901.2 14901.2 14901.2 14,903.7 14903.7 14905.5 14905.5 14905.5 14908.5 14908.5 14908.0 14908.0 14908.0 14909.5 14909.5 14911.7 14911.7 14911.7 14921.5 14921.5 14924.5 14924.5 i4925.0 14925.0 14925.0 14927.2 14927.2 14927.5 14927.5 14927.5 14929.7 14929.7 14931.2 14931.2 14931.2 14933.5 14933.5 14940.7 14940.7 14940.7 14942.7 14942.7 14945.5 14945.5 14946.0 14946.0 14946.0 14950.5 14950.5 14955.0 14955.0 14954.7 14954.7 14954.7 14960.0 14960.0 14959.7 14959.7 14959.7 14968.7 14968.7 14968.7 14973.2 14973.2 14973.2 14976.0 14976.0 14976.0 14979.5 14979.5 14984.7 14984.7 14984.7 14988.2 14988.2 14991.0 14991.0 14991.0 14996.0 14996.0 14996.0 15006.5 15006.5 15006.5 15003.5 15003.5 15008.7 15008.7 15008.7 15007.7 15007.7 15014.5 15014.5 15017.7 15017.7 BASEUNE DEPTH GRAM ROPS RADE RPDE NFBM 15044.0 15045.2 15046.5 15066.5 15073.0 15183.2 $ BASEENE DEPTH 13892.5 13907.0 13910.0 13911.7 13919.0 13921.0 13924.5 13927.2 13930.2 13949.2 13955.7 13961.0 13971.0 13975.7 13982.2 13994.7 13997.5 14002.2 14005.0 14008.7 14012.0 14017.0 14023.5 14027.2 14043.0 14043.2 14047.0 14047.5 14047.7 14048.2 14080.0 14085.0 14091.2 14098.2 14103.5 14111.5 14114.5 14124.7 14130.0 14146.7 14151.7 14156.7 14163.5 14170.0 14176.7 14179.0 14182.5 14188.5 14193.7 15014.0 15014.0 15014.0 15018.5 15018.5 15019.0 15019.0 15019.0 15040.7 15040.7 15040.7 15048.5 15048.5 15048.5 15210.0 15210.0 14203.2 14209.0 14212.7 14218.2 14222.0 14225.5 14229.0 14242.2 14253.5 14270.7 14275.5 14285.0 14288.5 14292.2 14296.0 14305.0 14309.5 14314.5 14320.7 14340.5 14342.5 14346.5 14349.2 14351.5 14362.7 14369.5 14374.7 14384.7 14398.7 14403.2 14409.0 14414.5 14423.5 1 4426.2 14429.2 14434.7 14442.2 14444.7 1 ~. ~. ~.~,. 5 14455.5 14462.2 14484.7 14491.5 14496.7 14499.2 14516.5 14623.2 14646.7 14550.5 14554.7 14677.7 14587.5 14693.7 14631.2 14642.2 14662.0 14702.0 14708.0 14713.0 14721.0 14726.0 14730.2 14758.0 14767.0 14796.2 148O0.5 148O5.2 14826.7 14838.5 14844.2 14852.2 14860.2 14862.2 14866.0 14869.2 14883.5 14887.2 14896.7 14907.5 14918.0 14921.2 14925.0 14929.7 14931.7 14936.2 14949.0 14952.0 14955.2 14963.7 14971.0 14978.7 14984.5 14993.2 14997.2 15000.2 15008.5 15014.0 15021.0 15030.5 15'032.7 15044.0 15046.5 15066.5 15073.0 15210.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD 23 MWD 24 MWD 25 $ BIT RUN NO MERGE TOP 13911.0 14311.0 14331.0 14520.0 14520.0 15201.0 MERGE BASE REMARKS: ALL GAMMA RAY AND RATE OF PENETRATION CURVES HAVE BEEN DEPTH SHIFTED TO SCHLUMBERGER WlRELINE GAMMA RAY (GR). ALL RESISTIVITY CURVES HAVE BEEN DEPTH SHIFTED TO SCHLUMBERGER WIRELINE MEDIUM INDUCTION RESISTIVITY (lEU). ALL NEUTRON CURVES HAVE BEEN DEPTH SHIFTED TO SCHLUMBERGER WlREENE NEUTRON POROSITY (NPHI). $ CN : BP Exploration (Alaska) WN : 2-66/SD-12 FN : Endicott COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 123456789012345678901234567890123456789012345678901234567890123456789012345678,90 THIS FILE CONTAINS EDITED MERGED MWD DATA THAT HAS BEEN DEPTH SHIFTED. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 I 0000000 1 000 1 Rep Code Count Bytes 68 10 40 Sum: 10 40 40 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: ... Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod 1 2 3 4 5 6 7 8 9 10 RHOB MWD 68 1 G/CC PEF MWD 68 I BN/E DRHO MWD 68 1 G/CC GR MWD 68 1 GAPI FCNT MWD 68 I CPS NCNTMWD 68 1 CPS NPHI MWD 68 1 PU-S RA MWD 68 I OHMM ROP MWD 68 1 FPHR RP MWD 68 10HMM 4 4 98660 71 6 4 4 9866O 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 9866O 71 6 4 4 98660 71 6 4 4 98 66O 71 6 4 4 98660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 23 FRAMES * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 113 Tape File Start Depth = 13911.000000 Tape File End Depth = 15201.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units -- Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3862 datums Tape Subtile: 2 1199 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subtile 3 is type: US **** FILE HEADER **** MAD .002 1024 US COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 # FILE SUMMARY PBU TOOL CODE START DEPTH MAD 13949.0 14300.0 $ MERGED DATA SOURCE PBU TOOL CODE MAD 1 $ REMARKS: $ STOP DEPTH MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 1 13949.0 14300.0 CN : BP Exploration (Alaska) WN : 2-66/SD-12 FN : Endicott COUN : North Slope STAT : Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS EDITED MERGED MAD PASS DATA THAT HAS BEEN DEPTH SHIFTED. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(68) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 0001 00000001 0001 Rep Code Count Bytes 68 10 40 Sum: 10 40 40 fndun a [F ] 1.00000000 3 ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: ... Name Tool Code Samples Units 1 ROP MAD 68 1 FPHR 2 RHOB MAD 68 I G/CC 3 PEF MAD 68 1 BN/E 4 DRHO MAD 68 I G/CC 5 GR MAD 68 1 GAPI 6 FCNTMAD 68 1 CPS 7 NCNTMAD 68 1 CPS 8 NPHI MAD 68 1 PU-S 9 RA MAD 68 1 OHMM 10 RP MAD 68 1 OHMM 4O APl APl APl APl Log Crv Crv Size Length Typ Typ Cls Mod 4 4 33 821 00 0 4 4 33 821 00 0 4 4 33 821 00 0 4 4 33 821 00 0 4 4 33 821 00 0 4 4 33 821 00 0 4 4 33 821 00 0 4 4 33 821 00 0 4 4 33 821 00 0 4 4 33821 00 0 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 23 FRAMES * DATA RECORD (TYPE~ O) 1018 BYTES * Total Data Records: 31 Tape File Start Depth = 13949.000000 Tape File End Depth = 14300.000000 Tape File Level Spacing -- 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1064 datums Tape Subfile: 3 55 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subtile 4 is type: LIS **** FILE HEADER **** MAD .003 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 3 EDITED MAD PASSES Depth shifted and clipped curves for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MAD 13949.0 14300.0 $ BASEMNE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) ........ EQUIVALENT UNSHIFTED DEPTH ......... BASEUNE DEPTH 13902.2 13906.0 13906.7 13949.2 13949.7 13952.0 13958.0 13961.0 13967.2 13969.2 13969.5 13970.5 13976.7 13989.7 13991.5 13996.5 13998.7 14001.5 14003.0 14004.5 14006.2 14012.2 14017.5 14019.7 1 4020.0 14020.2 GR^I 13890.0 13890.O 13933.2 13937.5 13954.0 13960.0 13962.2 13976.0 13978.7 13983.0 13985.5 13985.2 13967.7 13967.2 14001.2 14004.7 RAD1 RPD1 NFB1 NNB1 13890.0 13890.0 13933.2 13890.0 13936.2 13940.7 13948.0 13955.O 13954.0 13957.0 13936.2 1394O.7 13948.0 13955.0 13957.0 13962.2 13976.O 13983.0 13985.2 13962.0 13982.0 13967.5 13987.5 13989.5 13969.5 14001.5 14001.5 14006.7 14006.7 14004.7 BASEUNE DEPTH GRA1 RAD1 RPD1 NFB1 NNB1 14024.5 14025.2 14026.0 14030.0 14036.7 14039.5 14040.0 14043.2 14045.0 14049.0 14057.2 14060.7 14063.7 14082.0 14082.7 14088.5 14093.7 14102.2 14105.7 14110.7 14111.0 14113.2 14123.7 14132.0 14138.5 14145.7 14147.0 14152.7 14153.0 14157.5 14158.5 14162.0 14163.7 14167.5 14167.7 14169.0 14178.2 14194.0 14201.2 14205.7 14209.5 14209.7 14213.5 14222.0 14227.0 14232.2 14235.0 14235.7 14237.5 14240.7 14241.0 14244.7 14245.5 14251.5 14257.7 14261.2 14261.5 14263.7 14271.0 14005.7 14011.7 14011.7 14010.2 14010.2 14012.2 14015.5 14015.5 14017.2 14017.2 14024.5 14020.0 14020.0 14028.0 14032.2 14040.O 14040.0 14045.7 14046.0 14046.0 14063.7 14063.7 14061.0 14070.0 14070.0 14073.7 14073.7 14084.2 14084.2 14088.0 14088.0 14092.7 14092.7 14094.0 14094.0 14094.7 14094.7 14107.7 14107.7 14116.2 14121.7 14128.0 14128.0 14129.5 14136.2 14136.2 14135.0 14135.0 14139.5 14139.5 14140.7 14140.7 14144.7 14146.5 14146.5 14150.2 14150.2 14149.7 14149.7 14156.0 14156.0 14176.0 14176.0 14177.0 14177.0 14180.0 14180.0 14185.5 14185.5 14190.2 14193.5 14197.0 14197.0 14204.5 14215.2 14218.2 1.4221.2 14223.5 14227.0 14246.7 14252.2 14220.2 14220.2 14225.2 14225.2 1~31.2 1~31.2 1~35.5 1~35.5 1~39.5 14239.5 14243.0 14243.0 14245.0 14245.0 BASEUNE DEPTH GRA1 RAD1 RPD1 NFB1 NNB1 14273.2 14254.2 14275.5 14259.0 14277.5 14261.7 14278.0 14252.2 14252.2 14281.5 14264.5 14284.2 14266.5 ,,. 14289.5 14269.0 14290.5 14275.7 14275.7 14291.0 14277.2 14277.2 14293.7 14275.5 14297.2 14277.0 $ BASELINE DEPTH NPS1 BDCI' DPE1 DRH1 13903.5 13890.0 13890.0 13890.0 13906.7 13890.0 13952.0 13936.2 13958.0 13940.7 13959.5 13946.0 13946.0 13946.0 13961.0 13948.0 13964.5 13952.0 13952.0 13952.0 13967.2 13955.0 13969.5 13957.0 13970.5 13956.7 13956.7 13956.7 13975.0 13963.7 13963.7 13963.7 13981.7 13969.0 13989.0 13969.0 13985.2 13972.2 13972.2 13972.2 13994.7 13978.2 13978.2 13978.2 14001.2 13983.5 13983.5 13983.5 14001.5 13982.0 14003.7 13985.0 13985.0 13985.0 14004.5 13987.5 14006.2 13989.5 14008.7 13989.0 13989.0 13989.0 14017.0 13998.2 13998.2 13998.2 14017.5 14001.5 14019.7 14006.7 14022.5 14005.0 14005.0 14005.0 14025.2 14011.7 14028.0 14010.5 14010.5 14010.5 14034.0 14013.5 14013.5 14013.5 14036.7 14015.5 14039.5 14017.2 14042.5 14025.7 14025.7 14025.7 14043.2 14020.0 14078.2 14053.2 14053.2 14053.2 14082.0 14063.7 14088.5 14070.0 14092.5 14064.0 14064.0 14064.0 14093.7 14073.7 14102.2 14064.2 14109.0 14090.0 14090.0 14090.0 14110.7 14092.7 14123.7 14107.7 14125.7 14104.7 14104.7 14104.7 14144.5 14129.5 14129.5 14129.5 14152.7 14136.2 14157.5 14140.7 14140.7 14140.7 BASEUNE DEPTH NPS1 BDC1 14158.5 14140.7 14162.7 14150.0 14150.0 14169.0 14149.7 14170.0 14159.0 14159.0 14178.2 14156.0 14182.0 14165.7 14165.7 14165.5 14169.0 14169.0 14188.2 14173.2 14173.2 14193.2 14176.5 14176.5 14197.0 14187.2 14187.2 14201.2 14177.0 14205.7 14180.0 14206.7 14197.5 14197.5 14235.0 14220.2 14235.2 14212.7 14212.7 14241.0 14225.2 14245.0 14217.2 14217.2 14245.5 14231.2 14250.2 14219.5 14219.5 14251.5 14235.5 14257.5 14223.7 14223.7 14257.7 14239.5 14261.5 14243.0 14263.7 14245.0 $ REMARKS: $ CN · BP Exploration (Alaska) WN · 2-66/SD-12 FN :Endicott COUN : North Slope STAT :Alaska DPE1 14150.0 14159.O 14165.7 14169.0 14173.2 14176.5 14187.2 14197.5 14212.7 14217.2 14219.5 14223.7 DRH1 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS EDITED MAD PASS DATA THAT HAS BEEN DEPTH SHIFTED. * FORMAT RECORD (TYPE~ 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(68) Datum Specification Block SUb-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 0001 00000001 0001 Rep Code Count Bytes 68 10 40 Sum: fndun a [F 10 4O 4O ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 ROP MAD 68 1 FPHR 4 2 RHOB MAD 68 I G/CC 4 3 PEF MAD 68 I BN/E 4 4 DRHO MAD 68 1 G/CC 4 5 GR MAD 68 1 GAPI 4 6 FCNTMAD 68 1 CPS 4 7 NCNTMAD 68 1 CPS 4 8 NPHI MAD 68 1 PU-S 4 9 RA MAD 68 1 OHMM 4 10 RP MAD 68 1 OHMM 4 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33821 00 0 4 33821 00 0 4 33821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length Indicates: 23 FRAMES * DATA RECORD (TYPE# O) 1018 BYTES * Totai Data Records: '31 Tape File Start Depth = 13949.000000 Tape File End Depth = 14300.000000 Tape File Level Spacing -- 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4926 datums Tape Subtile: 4 224 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subtile 5 is type: LIS **** FILE HEADER **** MWD .OO4 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 23 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 13911.0 14311.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOF'rWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): mD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 18 SEP 93 P2.10 P2.10 MEMORY 0.0 13911.0 14311.0 0 33.9 38.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ TOOL NUMBER 1678-17 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 0.0 BOREHOLE CONDITIONS MUD TYPE: FRESH WATER MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 49.0 MUD PH: 10.2 MUD CHLORIDES (PPM): 4200 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.310 MUD FILTRATE AT MT: 0.200 160.0 MUD CAKE AT MT: 0.000 0.0 0.0 160.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .,. TOOL STANDOFF (IN): EWR FREQUENCY (HZ): SANDSTONE 2.65 8.500 0.0 0 REMARKS: INTERVAL FROM 14288 TO 14331 FEET (10703 TO 10739' TVD) WAS LOGGED 25 HOURS AFTER BEING DRILLED. $ CN : BP Exploration (Alaska) WN : 2-66/SD-12 FN : Endicott COUN : North Slope STAT : Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 23. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 0001 00000001 0001 Rep Code Count Bytes 68 35 140 Sum: 35 140 140 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 35 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod I ATCM MWD 68 I -dB 4 2 ATDC MWD 68 1 -dB 4 3 BDCM MWD 68 1 G/CC 4 4 BDEM MWD 68 1 MINS 4 5 BDIM MWD 68 1 PTS 4 6 CADE MWD 68 I MMHO 4 7 CPDE MWD 68 1 MMHO 4 8 DCCM MWD 68 I 4 9 DLAM MWD 68 1 G/CC 4 10 DPEM MWD 68 1 MINS 4 11 DPLMMWD 68 I PU 4 12 DPSM, MWD 68 1 PU 4 13 DRHMMWD 68 1 G/CC 4 14 DSAMMWD 68 1 G/CC 4 15 GRAMMWD 68 1 GAPI 4 16 GRCMMWD 68 1 GAPI 4 17 NFBMMWD 68 I CPS 4 18 NNBMMWD 68 1 CPS 4 19 NPEM MWD 68 1 MINS 4 20 NPHI MWD 68 I PU-S 4 21 NPIM MWD 68 1 PTS 4 22 NPLM MWD 68 1 PU 4 23 NPSM MWD 68 1 PU 4 24 NRCM MWD 68 1 RATI 4 25 PDCM MWD 68 1 DEG 4 26 PDDC MWD 68 1 DEG 4 27 PDEM MWD 68 1 MINS 4 28 PDIM MWD 68 1 PTS 4 29 RACM MWD 68 1 OHMM 4 30 RADE MWD 68 1 OHMM 4 31 ROPAMWD 68 1 FPHR 4 32 ROPS MWD 68 1 FPHR 4 33 RPCM MWD 68 I OHMM 4 34 RPDE MWD 68 1 OHMM 4 35 TCDM MWD 68 1 DEGF 4 140 498660 71 6 4 98660 71 6 49866O 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98 660 71 6 4 98 660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 9866O 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 51 877 27 0 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE# O) 1014 BYTES * Total Data Records: 229 Tape File Start Depth = 13911.000000 Tape File End Depth = 14311.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subfile reference is: **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 10856 datums Tape Subflle: 5 295 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 32 Tape Subtile 6 is type: US **** FILE HEADER **** MWD .005 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 24 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 14331.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BO'I'I'OM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTI'OM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ 14520.0 STOP DEPTH 22 SEP 93 P2.10 P2.10 MEMORY 0.0 14331.0 1 4520.0 0 28.7 32.9 TOOL NUMBER 1678-17 BOREHOLE AND CASING DATA OPEN HOLE BlT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 0.0 BOREHOLE CONDITIONS MUD TYPE: FRESH WATER MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 0.0 MUD PH: 0.0 MUD CHLORIDES (PPM): 4200 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.200 MUD FILTRATE AT MT: 0.200 162.0 MUD CAKE AT MT: 0.000 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: $ CN · BP Exploration (Alaska) WN · 2-66/SD-12 FN · Endicott COUN · North Slope STAT · Alaska 0.0 162.0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 24. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(68) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 910111213141516 0001 00000001 0001 Rep Code Count Bytes 68 35 140 Sum: 35 140 140 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 35 Curves: Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod -dB 4 98 66O 71 6 -dB 4 98 660 71 6 G/CC 4 98 660 71 6 MINS 4 98 66O 71 6 PTS 4 98 660 71 6 MMHO 4 98 66O 71 6 MMHO 4 98 660 71 6 4 98660 71 6 498660 71 6 4 98 660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 51 877 27 0 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 9866O 71 6 498660 71 6 49866O 71 6 4 98660 71 6 498660 71 6 49866O 71 6 498660 71 6 I ATCM MWD 68 I 4 2 ATDCMWD 68 1 4 3 BDCM MWD 68 1 4 4 BDEM MWD 68 1 4 5 BDIM MWD 68 1 4 6 CADE MWD 68 1 4 7 CPDE MWD 68 1 4 8 DCCM MWD 68 1 4 9 DLAM MWD 68 1 G/CC 4 10 DPEM MWD 68 1 MINS 4 11 DPLMMWD 68 I PU 4 12 DPSMMWD 68 1 PU 4 13 DRHM MWD 68 1 G/CC 4 14 DSAMMWD 68 I G/CC 4 15 GRAMMWD 68 1 GAPI 4 16 GRCMMWD 68 1 GAPI 4 17 NFBMMWD 68 1 CPS 4 18 NNBMMWD 68 I CPS 4 19 NPEM MWD 68 1 MINS 4 20 NPHI MWD 68 1 PU-S 4 21 NPIM MWD 68 1 PTS 4 22 NPLM MWD 68 1 PU 4 23 NPSM MWD 68 1 PU 4 24 NRCM MWD 68 1 RATI 4 25 PDCM MWD 68 1 DEG 4 26 PDDC MWD 68 1 DEG 4 27 PDEM MWD 68 1 MINS 4 28 PDIM MWD 68 1 PTS 4 29 RACM MWD 68 I OHMM 4 30 RADE MWD 68 1 OHMM 4 31 ROPAMWD 68 1 FPHR 4 32 ROPS MWD 68 1 FPHR 4 33 RPCM MWD 68 I OHMM 4 34 RPDE MWD 68 1 OHMM 4 35 TCDM MWD 68 1 DEGF 4 140 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 7 FRAMES * DATA RECORD (TYPE# O) 1014 BYTES * Total' Data Records: 109 Tape File Start Depth = 14331.000000 Tape File End Depth = 14520.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: **** FILE TRAILER **** US representation code decoding summary: Rep Code: 68 9639 datums Tape Subtile: 6 174 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 32 Tape Subtile 7 is type: LIS **** FILE HEADER **** MWD .006 1024 LIS COMMENT RECORD(s)' 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 25 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 14520.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFI'WARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCMNATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 15201.0 STOP DEPTH 24 SEP 93 P2.10 P2.10 MEMORY 0.0 14520.0 15201.0 0 25.2 28.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD NEUTRON/DENSITY $ TOOL NUMBER 2628-07 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 0.0 BOREHOLE CONDITIONS MUD TYPE: FRESH WATER MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 15.0 MUD PH: 10.1 MUD CHLORIDES (PPM): 3500 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: 0.000 MUD CAKE AT MT: 0.000 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): 0.0 EWR FREQUENCY (HZ): 0 0.000 0.0 0.000 0.0 0.0 0.0 REMARKS: INTERVAL FROM 14520 TO 14900 FEET (10905 TO 11236' TVD) WAS LOGGED WHILE REAMING TO BO'I'I'OM FOR RUN 3 APPROXI- MATELY 32 HOURS AFTER BEING DRILLED. INTERVAL FROM 15150 TO 15201 FEET (11450 TO 11511' TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET FROM THE BIT AND A TOOL FAILURE. $ CN : BP Exploration (Alaska) WN : 2-66/SD-12 FN : Endicott COUN : North Slope STAT : Alaska US COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 25. * FORMAT RECORD (TYPE~ 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: I 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 35 140 Sum: 35 140 140 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 35 Curves: Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod I ATCM MWD 68 I -dB 4 2 ATDC MWD 68 I -dB 4 3 BDCM MWD 68 I G/CC 4 4 BDEM MWD 68 1 MINS 4 5 BDIM MWD 68 1 PTS 4 6 CADE MWD 68 1 MMHO 4 7 CPDE MWD 68 1 MMHO 4 8 DCCM MWD 68 1 4 9 DLAM MWD 68 1 G/CC 4 10 DPEM MWD 68 I MINS 4 11 DPLMMWD 68 1 PU 4 12 DPSMMWD 68 I PU 4 13 DRHMMWD 68 1 G/CC 4 14 DSAMMWD 68 1 G/CC 4 15 GRAMMWD 68 I GAPI 4 16 GRCMMWD 68 1 GAPI 4 17 NFBMMWD 68 1 CPS 4 18 NNBMMWD 68 1 CPS 4 19 NPEMMWD 68 1 MINS 4 20 NPHI MWD 68 1 PU-S 4 21 NPIM MWD 68 1 PTS 4 22 NPLM MWD 68 I PU 4 23 NPSM MWD 68 1 PU 4 24 NRCMMWD 68 .1 RATI 4 25 PDCM MWD 68 1 DEG 4 26 PDDC MWD 68 1 DEG 4 27 PDEM MWD 68 1 MINS 4 28 PDIM MWD 68 1 PTS 4 29 RACM MWD 68 1 OHMM 4 30 RADE MWD 68 I OHMM 4 31 ROPAMWD 68 I FPHR 4 32 ROPS MWD 68 1 FPHR 4 33 RPCM MWD 68 1 OHMM 4 34 RPDE MWD 68 I OHMM 4 35 TCDM MWD 68 1 DEGF 4 140 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 9866O 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 49866O 71 6 4 51 877 27 0 498660 71 6 4 98 66O 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 ** Routine LEVONE detects data discrepancy: DSB Indicates: I FRAMES Data Record Length Indicates: 7 FRAMES * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 390 Tape File Start Depth = 14520.000000 Tape File End Depth = 15201.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet NOTE: max curves transferable to WDF per tape subtile reference is: 32 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27512 datums Tape Subtile: 7 461 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 8 is type: LIS **** FILE HEADER **** MAD .OO7 1024 LIS COMMENT RECORD(s)' 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MAD 13949.0 14300.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTI'OM) VENDOR TOOL CODE TOOL TYPE MAD NEUTRON/DENSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): STOP DEPTH 24 SEP 93 P2.10 P2.10 MEMORY 0.0 13949.0 1 4300.0 0 0.0 0.0 TOOL NUMBER 1678-17 8.500 0.0 FRESH WATER 0.00 0.0 0.0 3500 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.000 MUD FILTRATE AT MT: 0.000 0.0 MUD CAKE AT MT: 0.000 0.0 0.0 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 13950 TO 14331 FEET (10433 TO 10739' TVD) WAS RELOGGED DURING A MAD PASS BEGINNING 3.75 HOURS AFTER BEING DRILLED. $ CN : BP Exploration (Alaska) WN : 2-66/SD-12 FN : Endicott COUN : North Slope STAT :Alaska US COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MAD PASS DATA. * FORMAT RECORD (TYPE~ 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: I 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 32 128 Sum: 32 128 128 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 32 Curves: Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod 1 ATC1 MAD 68 I -dB 4 2 ATD1 MAD 68 1 -dB 4 3 BDCl MAD 68 1 G/CC 4 4 BDE1 MAD 68 I MINS 4 5 BDI1 MAD 68 1 PTS 4 6 CAD1 MAD 68 1 MMHO 4 7 CPD1 MAD 68 1 MMHO 4 8 DCC1 MAD 68 1 4 9 DLA1 MAD 68 I G/CC 4 10 DPE1 MAD 68 1 MINS 4 11 DPL1MAD 68 1 PU 4 12 DPS1 MAD 68 1 PU 4 13 DRH1 MAD 68 1 G/CC 4 14 DSA1 MAD 68 1 G/CC 4 15 GRA1 MAD 68 1 GAPI 4 16 GRCl MAD 68 I GAPt 4 17 NFB1 MAD 68 I CPS 4 18 NNB1 MAD 68 1 CPS 4 19 NPE1 MAD 68 1 MINS 4 20 NPI1 MAD 68 I PTS 4 21 NPL1 MAD 68 I PU 4 22 NPS1 MAD 68 1 PU 4 23 NRC1 MAD 68 1 RATI 4 24 PDCl MAD 68 I DEG 4 25 PDD1 MAD 68 1 DEG 4 26 PDE1 MAD 68 1 MIN$ 4 27 PDI1 MAD 68 I PTS 4 28 RACl MAD 68 1 OHMM 4 29 RAD1 MAD 68 1 OHMM 4 30 RPCl MAD 68 1 OHMM 4 31 RPD1 MAD 68 I OHMM 4 32 TCD1 MAD 68 I DEGF 4 128 4 33 821 00 0 4 33 821 00 0 4 33821 00 0 4 33 821 00 0 4 33 821 00 0 4 33821 00 0 4 33821 00 0 4 33 821 00 0 4 33 821 00 0 4 33821 00 0 4 33821 00 0 4 33821 00 0 4 33 821 OO 0 433821OO 0 433821 00 0 4 54 433 96 6 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 4 33 821 00 0 433821 00 0 433821 00 0 4 33 821 00 0 4 33821 00 0 4 59 602 51 0 4 33821 00 0 4 33821 OO 0 4 33821 00 0 433821 00 0 4 33821 00 0 4 33 821 00 0 4 33 821 00 0 ** Routine LEVONE detects data discrepancy: DSB Indicates: I FRAMES Data Record Length Indicates: 7 FRAMES * DATA RECORD (TYPE~ O) 930 BYTES * Total Data Records: 201 Tape File Start Depth = 13949.000000 Tape File End Depth = 14300.000000 Tape File Level Spacing -- 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17637 datums Tape Subtile: 8 269 records... Minimum record length: 62 bytes Maximum record length: 930 bytes Tape Subtile 9 is type: US **** TAPE TRAILER **** MWD 94/lis 1242 01 **** REEL TRAILER **** MWD 94/lis 1242 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 6 JAN 94 10:28a Elapsed execution time -- 1 minute, 41.6 seconds. SYSTEM RETURN CODE -- 0 Tape Subtile 1 is type: US Tape Subtile 2 is type: LIS DEPTH RHOB FCNT NCNT RP 13911.0000 2.5988 40.2936 6974.6738 9.2402 13911.5000 2.6197 40.5033 7022.5039 8.6296 14000.0000 2.4186 35.1394 6955.2422 7.0011 14100.0000 2.3956 20.1113 6518.5781 4.6164 14200.0000 2.3696 88.1922 7631.5869 8.3750 14300.0000 2.0579 17.0975 6267.6025 8.1894 14400.0O00 2.5405 36.2984 7142.7246 8.1408 14500.0000 2.4965 71.0630 7531.0527 26.5946 14600.0000 2.2491 41.4030 7193.0566 1.6554 14700.0000 1.8786 11.41 79 6067.9580 8.2661 14800.0000 2.3059 49.2963 7246.7236 2.0620 14900.0000 2.5262 36.9515 7305.6914 16.7424 15000.0000 2.3360 55.3625 7291.8906 2.5962 PEF NPHI 4.3899 20.7930 4.4080 20.6326 3.7369 24.2798 3.0966 44.6989 2.1017 9.1765 2.9792 53.1009 3.2916 24.1249 2.8478 13.2109 3.6815 23.4447 5.7929 117.0737 3.5897 19.3323 5.4239 27.2741 3.6367 17.0508 DRHO RA 0.1171 10.8058 0.0811 9.9006 0.0242 7.5442 0.0929 5.5295 0.1088 8.0563 0.1390 8.2655 0.0554 8.2423 0.0261 32.6423 0.0883 1.4955 0.1699 18.3994 0.1208 1.8324 0.0452 44.9068 0.1344 2.9543 GR ROP 77.4806 -999.2500 74.4659 -999.2500 85.3765 8.8414 106.7548 7.8858 53.5731 11.6928 68.9045 8.2539 88.6093 10.8672 72.5961 17.1893 77.7895 90.4499 113.1821 63.9169 20.4170 65.1462 168.0984 7.0491 19.8756 32.0263 DEPTH RHOB PEF FCNT NCNT NPHI RP 15100.0000 2.4200 4.0700 57.9894 7400.5039 ' 16.4374 14.6259 15200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15201.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 DRHO RA 0.1316 11.8256 -999.2500 -999.2500 -999.2500 -999.2500 GR ROP 55.2957 27.2118 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 13911.000000 Tape File End Depth = 15201.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 3 is type: US DEPTH ROP RHOB GR FCNT NCNT RP PEF NPHI DRHO RA 13949.0000 12.6767 2.1953 78.1696 33.5751 -999.2500 8.3998 2.5225 25.7810 0.2164 9.3714 13949.5000 12.2852 2.1355 76.6322 28.1740 -999.2500 7.5985 2.6435 30.4642 0.2188 8.9035 14000.0000 8.8414 2.5726 73.8788 23.6026 -999.2500 6.1513 3.2774 35.0133 -0.0058 6.5641 14100.0000 7.8858 1.7551 95.4535 15.0370 0.0000 4.6332 2.9415 61.2313 0.1929 5.2559 14200.0000 11.6928 2.6261 41.9895 48.2284 -999.2500 7.9404 14300.0000 8.2539 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.3036 17.4829 -999.2500 -999.2500 0.1088 6.9130 -999.2500 -999.2500 Tape File Start Depth = 13949.000000 Tape File End Depth -- 14300.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 4 is type: US DEPTH ROP RHOB GR FCNT NCNT RP ' PEF NPHI DRHO RA 13949.0000 12.6767 2.1953 78.1696 33.5751 -999.2500 8.3998 2.5225 25.7810 0.2164 9.3714 13949.5000 12.2852 2.1355 76.6322 28.1740 -999.2500 7.5985 2.6435 30.4642 0.2168 8.9035 14000.0000 8.6414 2.5726 73.8766 23.6026 -999.2500 6.1513 14100.0000 7.8858 1.7551 95.4535 15.0370 0.0000 4.6332 14200.0000 11.6928 2.6261 41.9895 48.2284 -999.2500 7.9404 14300.0000 8.2539 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.2774 35.0133 2.9415 61.2313 3.3036 17.4829 -999.2500 -999.2500 -0.0058 6.5641 0.1929' 5.2559 0.1068 6.9130 -999.2500 -999.2500 Tape File Start Depth = 13949.000000 Tape File End Depth = 14300.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 5 is type: US DEPTH ATCM ATDC BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM GRCM . 'NFBM NNBM NPEM NPHI NPIM NPLM NPSM NRCM PDCM PDDC PDEM PDI M RACM RADE ROPA ROPS RPCM RPDE TCDM 13911.0000 -999.2500 -999.2500 2.5364 -999.2500 61.0000 -999.2500 -999.2500 -999.2500 2.4500 4.3443 10.1502 6.8830 0.1337 2.3609 -999.2500 -999.2500 55.3527 7047.9092 -999.2500 18.3011 100.0000 11.4966 14.5823 114.7219 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13911.2500 -999.2500 -999.2500 2.5445 63.5000 -999.2500 -999.2500 -999.2500 4.3353 9.6787 6.3943 0.1417 -999.2500 -999.2500 57.7517 7036.9648 17.4951 101.5000 10.8070 13.6491 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.4614 2.3669 -999.2500 109.7856 -999.2500 -999.2500 14000.0000 0.3666 0.4286 2.3674 204.0000 538.5000 105.0059 125.7172 85.1503 2.2990 2.1157 20.0335 17.1256 0.0767 2.2479 32.4802 34.3325 64.8343 7111.1045 243.0000 23.2493 561.0000 9.2813 12.2233 98.8227 7.6933 7.4463 117.0000 627.0000 11.1095 9.5233 12.4183 14.1640 7.5379 7.9544 158.9000 14100.0000 0.4498 0.5095 2.3441 434.0000 11 43.5999 125.5381 137.0121 88.5251 2.2626 3.3639 21.4005 18.5423 0.0738 2.2134 86.9426 91.9006 23.8281 6694.1260 464.0000 40.3455 1172.0000 33.1375 37.0535 253.1213 8.1476 7.8966 290.0000 1381.0000 9.0343 7.9657 9.3707 9.8698 6.9292 7.2986 164.0750 2.4063 94.3~6 0.0~2 6794.0244 34.27~ 2216.5000 6.0336 14200.0000 0.5337 0.5930 1779.5000 147.4313 158.2558 2.9515 17.7612 14.7707 110.7062 117.0194 25.3885 11.2621 1809.0000 30.4085 8.9810 8.7010 144.0000 6.7828 7.6057 8.0666 167.0000 204.0000 2.3323 2.2888 223.0000 237.9154 7.5762 6.3189 DEPTH ATCM ATDC BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM GRCM NFBM NNBM NPEM NPHI NPIM NPLM NPSM NRCM PDCM PDDC PDEM PDIM RACM RADE ROPA ~OPS RPCM RPDE TCDM 14300.0000 0.3831 0.4453 2381.5000 109.1947 131.4790 2.8966 38.9433 36.7230 105.8914 111.9301 15.9840 30.7496 2401.5000 55.7950 7.9276 7.6782 165.0000 9.1580 9.6502 9.8635 171.2750 2.0441 86.7475 0.1589 6325.2412 59.4642 2999.500O 7.2402 2319.0000 1.8651 1.7792 2332.0000 356.5477 10.6489 7.6O58 14311.0000 0.3063 0.3710 1.8620 2312.5557 2421.0903 90.7917 121.3397 63.6370 1.7901 3.0335 49.5922 47.7592 0.0718 1.7423 129.8136 137.2164 16.1323 6340.6477 2321.0000 13.0663 2422.5000 55.1675 58.6589 354.1397 7.5108 7.2670 2225.0000 3096.5000 13.2631 11.0142 12.3752 13.3771 7.6372 8.2413 171.9500 Tape File Start Depth -- 13911.000000 Tape File End Depth -- 14311.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subflle 6 is type: US DEPTH ATCM ATDC BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM GRCM NFBM NNBM NPEM NPHI NPIM NPLM NPSM NRCM PDCM PDDC PDEM PDIM RACM RADE ROPA ROPS R PCM RPDE TCDM 14331.0000 0.2143 0.2693 2.5361 2216.0000 2503.0000 66.4036 64.2067 62.9903 2.4643 3.0231 10.1717 6.9052 0.0645 2.4079 94.3680 99.7494 47.2269 7324.2383 2225.0000 22.4238 2517.0000 15.0318 18.3244 139.7328 4.8066 4.6042 625.5000 3207.8569 18.6498 15.0594 10.3711 9.9746 14.6429 15.5747 172.6352 1 4331.2500 0.2129 0.2680 2.5341 176.0000 2504.5000 66.0930 64.1368 62.9598 2.4643 3.0942 10.2875 7.0253 0.0868 2.4077 99.4674 105.1397 44.9746 7317.4668 185.0000 21.8454 -999.2500 16.0180 19.3633 1 46.5946 4.8027 4.6004 369.7500 3208.0000 18.7607 15.1302 10.3711 10.2390 14.6588 15.5917 172.1954 14400.0000 0.2448 0.2975 2.5582 289.0000 2915.5000 73.0709 63.1977 62.5543 2.5277 3.0080 8.8765 5.5629 -0.0152 2.5430 52.6981 55.7032 71.9928 7334.7490 338.0000 28.2822 2951.5000 8.3062 11.1814 91.7955 4.7512 4.5501 198.0000 3746.5000 16.4580 13.6853 11.8136 11.5530 14.8726 15.8234 162.7250 1 4500.0000 0.3425 0.3972 2.5614 263.0000 3481.5000 97.2024 68.8737 72.7744 2.4744 2.5494 8.6918 5.3715 0.0959 2.4104 60.1930 63.9648 64.3862 7355.5879 798.0000 15.7045 3515.5000 9.8613 12.8420 102.9317 6.0626 5.6390 208.0000 4567.0000 11.8992 10.2878 14.3812 13.8546 10.6253 11.2519 167.2250 14520.0000 0.0786 0.1315 2.4960 703.0000 3613.5000 34.4581 34.5066 46.3313 2.4343 2.7525 12.5126 9.3312 0.0617 2.3931 37.2981 39.6353 74.4280 7394.6398 4110.9990 15.0081 3629.0000 9.2945 12.2373 98.8562 3.0072 2.8480 603.0000 4684.5000 42.9462 29.0207 21.2450 20.3506 26.8137 28.9799 163.1750 Tape File Start Depth = Tape File End Depth = 14331.000000 14520.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 7 is type: LIS DEPTH ATCM ATDC BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM GRCM . NFBM NNBM NPEM NPHI NPIM NPLM NPSM NRCM PDCM PDDC PDEM PDIM RACM RADE ROPA ROPS RPCM RPDE TCDM 14520.0000 0.0786 0.1315 2.4960 703.0000 3613.5000 34.4581 34.5066 48.3313 2.4343 2.7525 12.5126 9.3312 0.0617 2.3931 37.2981 39.6353 74.4280 7394.6396 4110.9990 15.0081 3629.0000 9.2945 12.2373 96.8562 3.0072 2.8480 603.0000 4684.5000 42.9462 29.0207 21.2450 20.3506 26.8137 28.9799 163.1750 14520.2500 0.0777 0.1310 2.4961 705.0000 3615.0000 34.3568 35.2265 48.7525 2.4335 2.7312 12.5104 9.3289 0.0626 2.3918 38.7960 41.2269 73.0971 7396.0049 4111.0000 16.2095 -999.2500 9.5473 12.5071 100.6745 3.0563 2.8954 603.0000 4687.0000 45.3695 29.1064 21.2450 20.9469 26.2767 28.3877 163.1750 14600.0000 0.6105 0.6654 2.3158 3268.0000 3780.9995 167.0130 151.9441 92.6936 2.2748 3.1809 23.0499 20.2517 0.0407 2.2476 23.1474 24.5978 41.8044 6818.0586 3416.0000 21.3760 -999.2500 18.3293 21.7896 162.2768 8.7243 8.4674 3255.0000 5197.5000 6.5623 5.9676 30.1934 32.6974 6.2741 6.5814 157.5500 14700.0000 1.0612 1.1137 2.3559 4023.0000 301.01 95 252.1429 117.0551 3.8713 20.7079 17.8246 0.1179 15.8679 16.8622 48.7604 7243.3359 63.6823 -999.2500 16.2108 19.5681 12.0527 11.7696 3499.0000 5732.5000 3.3220 33.3638 30.5259 3.8115 158.0000 3529.0000 2.2607 2.1656 3536.0000 147.8069 3.5141 3.9660 14800.0000 0.7046 0.7717 2.2756 4260.5000 196.8068 274.7062 121.8297 3.7586 25.4024 22.6896 0.0684 46.0292 48.9134 44.2499 7211.0137 19.5765 4264.0000 18.3096 21.7691 12.7068 12.4205 2920.0000 6258.0000 5.0811 18.8679 19.9117 3.5023 164.5250 2961.0000 2.2048 2.1592 2972.0000 162.1463 5.6125 3.6403 DEPTH ATCM ATDC BDCM BDEM BDIM CADE CPDE DCCM DLAM DPEM DPLM DPSM DRHM DSAM GRAM GRCM NFBM NNBM NPEM NPHI NPIM NPLM NPSM NRCM PDCM PDDC PDEM PDIM RACM RADE ROPA ~ROPS RPCM RPDE TCDM 14900.0000 0.4553 0.5118 2.5292 2888.0000 4529.0000 126.1486 122.2942 83.9857 2.4375 6.0779 10.5732 7.3213 0.0457 2.4070 37.7755 40.1426 56.7486 7496.3604 2916.0000 29.0568 -999.2500 13.8638 17.0911 131.4373 7.5503 7.3063 2851.0000 6858.0000 8.9319 7.9272 23.2092 25.0434 7.7687 8.1770 168.8650 15000.0000 0.0093 0.0647 2.5338 156.0000 4967.5000 18.8378 25.6374 42.7595 2.3989 4.7081 10.3052 7.0436 0.1279 2.3137 55.2850 58.7491 72.6966 7330.6006 198.0000 16.9880 5007.5000 9.5000 12.4568 100.3341 2.3758 2.2357 107.0000 7541.5000 238.4026 53.0849 21.1250 21.7095 35.8025 39.0054 171.2750 15100.0000 1.6837 1.7399 2.3387 549.0000 5391.5000 525.2770 523.1659 164.9342 2.2239 3.6907 21.7132 18.8664 0.1148 2.1474 36.1853 38.6576 58.4635 7382.4697 588.0000 -999.2500 5433.0000 13.0567 16.2371 125.6436 18.6403 18.3283 482.0000 8258.5000 1.9843 1.9038 48.7651 48.0665 1.8553 1.9114 172.8500 15200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.0000 0.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9.7228 13.0877 -999.2500 15201.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ************** 0.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4.1147 4.1147 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 14520.000000 Tape File End Depth = 15201.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units -- Feet Tape Subtile 8 is type: US DEPTH ATCl ATD1 BDC1 BDE1 BDI1 CAD1 CPD1 DCCl DLA1 DPE1 DPL1 DPS1 DRH1 DSA1 GRA1 GRCl NFB1 NNB1 NPE1 NPI1 NPL1 NPS1 NRC1 PDCl PDD1 PDE1 PDI1 RAC1 RAD1 RPCl RPD1 TCD1 13949.0000 0.1368 0.1805 2.4958 2674.0000 64.6000 46.7463 27.5839 43.9850 2.3956 3.4157 12.5290 9.3483 0.0918 2.3344 60.8233 64.2918 94.3859 -999.2500 2690.0000 71.2000 5.2735 7.9277 69.9316 2.5191 2.3748 2659.0000 1.0000 27.9583 21.8597 33.4714 36.2530 -999.2500 13949.2500 0.1326 0.1763 2.4879 2687.0000 64.8000 44.7793 27.0499 43.6343 2.3981 3.4424 12.9903 9.8263 0.0749 2.3482 59.1695 62.5437 104.2203 -999.2500 2683.0000 71.4000 4.4684 7.0604 64.1449 2.4800 2.3369 2652.0000 2.5000 28.7322 22.3317 34.1146 36.9687 -999.2500 14000.0000 0.2886 0.3540 2.4034 2535.0000 181.3333 86.6463 118.9769 82.8969 2.3230 2.2234 17.9295 14.9451 0.0978 2.2578 34.2397 36.1922 31.3286 -999.2500 2541.0000 193.5000 22.7988 26.4481 191.8766 7.4110 7.1691 2508.0000 273.0000 14.0680 11.5412 7.9901 8.4050 161.3750 14100.0000 0.4307 0.4939 2.3979 2124.0000 370.2500 121.5249 150.6216 92.2865 2.3035 3.3649 18.2535 15.2809 0.0813 2.2493 87.2806 92.2579 17.9120 0.0000 2129.0000 381.0000 46.0845 49.9993 316.6773 8.6755 8.4179 2112.0000 777.0000 9.4603 8.2268 6.3339 6.6392 159.8000 14200.0000 0.5704 0.6303 2.5468 1310.7690 522.3844 157.4693 172.6064 98.2264 2.3424 3.3499 9.5447 6.2555 0.2044 2.2061 109.3619 115.5984 19.0708 -999.2500 1314.0000 527.6000 41.6901 46.6471 296.5850 9.4821 9.2165 1304.0000 -999.2500 7.0602 6.3504 5.5391 5.7935 159.6594 14300.0000 0.4663 0.5273 -999.2500 -999.2500 -999.2500 130.1488 149.3983 91.91 79 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 65.9182 90.8178 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8.6275 8.3719 902.0000 1637.0000 8.7227 7.6835 6.3888 6.6935 160.1751 Tape File Start Depth = 13949.000000 Tape File End Depth = 14300.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units -- Feet Tape Subtile 9 is type: LIS Tape SUbfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA BIT RUN 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD D. WESLEY C. BALLARD 2-66 / SAG DELTA 12 500292237400 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 01-DEC-93 BIT RUN 2 36 12N 16E BIT RUN 3 3151 2360 56.00 10.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 12.250 REMARKS: 13.375 2870.0 13227.0 MWD - DGR/EWR4 ALL DEPTHS ARE MEASURED BIT DEPTHS. RUN 1 WAS a MAD PASS THROUGH a PREVIOUSLY DRILLED INTERVAL. MAD PASS LOGGED AT APPROXIMATELY 200-250 FEET PER HOUR AND 70-100 RPM. FILE HEADER FILE NUMBER: 1 EDITED MAD PASSES Depth shifted and clipped curves for each pass of each run in separate files MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 12282.0 RP 12282.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 12276.5 12286.5 12296.0 12302.5 12344.0 12354.0 12364.8 12390.0 12415.5 12426.0 12507.0 12527.0 12533.4 12555.5 12572.1 12628.2 12632.0 12643.8 12671.0 12675.2 12697.0 12847.0 13002.5 13033.7 13089.7 13106.8 13121.0 13154.0 13157.0 13232.5 $ REMARKS: STOP DEPTH 13187.0 13196.0 ......... EQUIVALENT UNSHIFTED DEPTH GR 12280.0 12290.0 12298.0 12304.5 12350.0 12359.5 12370.6 12396.2 12423.0 12433.3 12517.0 12537.4 12544.7 12563.8 12580.7 12636.2 12642.0 12654.0 12680.3 12684.4 12706.0 12860.0 13019.0 13050.0 13107.5 13123.8 13138.5 13170.0 13174.5 13250.0 MAD PASS 1. ALL CURVES WERE SHIFTED WITH GR. CN /??SHIFT. OUT $ : BP EXPLORATION : 2-66 / SAG DELTA 12 ~N : ENDICOTT COUN : NORTH SLOPE STAT .- ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 3 RPX MWD 68 I OHMM 4 4 RPS MWD 68 1 OHMM 4 5 RPM MWD 68 1 OHM]4 4 6 RPD MWD 68 1 OHMM 4 4 91 948 38 6 4 99 789 97 5 4 54 501 47 1 4 54 501 47 1 4 54 501 47 1 4 54 501 47 24 * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 70 Tape File Start Depth = 13300.000000 Tape File End Depth = 12056.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17424 datums Tape Subfile: 2 177 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 12286.0 EWR4 12286.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13204.0 13214.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 07-SEP-93 MWD 1.70 3.65 MEMORY 13227.0 12286.0 13227.0 0 0.0 0.0 TOOL NUMBER P0167CGR8 P0167CGR8 12.250 2870.0 LSND 10.40 63.0 10.6 4100 5.4 1.100 0.590 0.840 1.400. 76.0 147.0 76.0 74.0 0.00 0.000 TOOL STANDOFF (IN): 0.0 EWR' FREQUENCY (HZ): REMARKS: MAD PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION : 2-66 / SAG DELTA 12 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves- · Name Tool Code Samples Units i GR MWD 68 2 ROP MWD 68 3 RPX MWD 68 4 RPS MWD 68 5 RPM MWD 68 6 RPD MWD 68 I ~PI i FPHR i OHMM i OHM]4 i OHMM I OHMM API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 91 948 38 6 4 4 99 789 97 5 4 4 54 501 47 1 4 4 54 501 47 1 4 4 54 501 47 1 4 4 54 501 47 1 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 70 Tape File Start Depth = 13300.000000 Tape File End Depth = 12056.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17424 datums Tape Subfile: 3 136 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS 93/1~/30 O1 **** REEL TRAILER **** 93/12/ 1 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 1 DEC 93 3:40p Elapsed execution time = 13.74 seconds. SYSTEM RETURN CODE = 0 ,,~ ~ . ALASKA C0MPUTTNG CENTER !.-I c~ , . ....... SCHLUMBERGER ....... [~ ~ ~ . ............................ . ****************************** -x.. WELL NAME : 2-56/SD~.2 MPT ~ ~ FT,.ELD NAME : ENDTCOTT r,~ ~-~ ~ BOROUGH : NORTH SLOPE " ,. APT NUMBER : 50-029-22574-00 REFERENCE NO : 934S4 LIS Tape Verification Lis%lng Schlumberger Alaska Computing Center 28-0CT-1993 17:50 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 93/10/28 ORIGIN : FLIC REEL NAME : 93454 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION,ENDICOq-F,2-66/SD12 MPI,50-029-22374-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 93/10/28 ORIGIN : FLIC TAPE NAME : 93454 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION,ENDICOTT,2-66/SD12 MPI,50-029-22374-00 TAPE HEADER ENDICO~-F OPEN HOLE WlRELINE LOGS WELL NAME: AP1 NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 2-66/SD12 MPI 500292237400 BP EXPLORATION SCHLUMBERGER WELL SERVICES 28-0CT-93 RUN 1 RUN 2 RUN 3 JOB NUMBER: 93454 LOGGING ENGINEER: SARBER OPERATOR WITNESS: ZARNDT/WAELS SURFACE LOCATION SECTION: 35 TOWNSHIP: 12N RANGE: 16E . FNL: FSL: 3151 FEL: 2350 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 57.00 DERRICK FLOOR: 57.00 GROUND LEVEL: 10.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BlT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 13502.0 2ND STRING PAGE: ' LIS Tape Verifica%ion Lis%ing 28-0CT-1993 17:50 Schlumberger Alaska Compu%ing Cen%er 3RD STRING PRODUCTION STRING REMARKS: NO DEPTH-ADJUSTMENTS WERE MADE BECAUSE LDT/CNTH WAS LOGGED IN COMBINATION WITH THE DITE. $ LIS FORMAT DATA LIS FORMAT DATA PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01C01 DATE : 93/10/28 MAX REC SIZE : 1024 Flee TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES All ~ool s~rings; DepSh shi~ed and clipped curves; all runs merged; no cased hole da~a. DEPTH INCREMENT: 0.5000 Flee SUMMARY LDWG TDDL CODE START DEPTH STOP DEPTH DTE lS058.0 SDN 15050.0 CNTH 15021.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 13473.0 13473.0 13473.0 E~UIVALENT UNSHIFTED DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE RUN NO. PASS NO. MERGE TOP MERGE BASE $ REMARKS: ND DEPTH-ADJUSTMENTS WERE MADE BECAUSE LDT/CNTH WAS LOGGED IN COMBINATION WITH THE DITE. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-OCT-1993 17:50 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 6 66 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 API AP1 AP1 FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) DEPT FT 619'154 O0 000 O0 0 1 I 1 4 58 IDPH DTE OHMM 619154 O0 000 O0 0 1 I 1 4 68 IMPH DTE OHMM 619154 O0 000 O0 0 i I I 4 66 ILD DTE OHMM 619154 O0 000 O0 0 I I I 4 68 ILM DTE OHMM 619154 O0 000 O0 0 I I I 4 68 SFL DTE 619154 O0 000 O0 0 I I I 4 68 SP DTE MV 619154 O0 000 O0 0 I I 1 4 68 GR DTE GAPI 619154 O0 000 O0 0 I I I 4 66 TENS DTE LB 619154 O0 000 O0 0 I I I 4 68 MTEM DTE DEGF 619154 O0 000 O0 0 i I 1 4 68 MRES DTE OHMM 619154 O0 000 O0 0 I I 1 4 68. RHDB SDN G/C3 619154 O0 000 O0 0 I I I 4 68 DRHO SDN G/C3 619154 O0 000 O0 0 I I I 4 68 PEF SDN BN/E 619154 O0 000 O0 0 I I I 4 68 CALl SDN IN 619154 O0 000 O0 0 I I I 4 68 NPHI CNTH PU-S 619154 O0 000 O0 0 I I I 4 68 CRAT CNTH 619154 O0 000 O0 0 I I I 4 58 NRAT CNTH 619154 O0 000 O0 0 I I I 4 58 NCNT CNTH CPS 619154 O0 000 O0 0 I I 1 4 58 FCNT CNTH CPS 619154 O0 000 O0 0 I I I 4 68 CNTC CNTH CPS 619154 O0 000 O0 0 I I I 4 68 CFTC CNTH CPS 619154 O0 000 O0 0 I 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** DATA DEPT. 15100 ILM.DTE -999 TENS.DTE 6085 DRHD.SDN -999 CRAT.CNTH -999 CNTC.CNTH -999 28-0CT-1993 17:50 DEPT ILM TENS DRHO CRAT CNTC 14000 DTE 8 DTE 7065 SON 0 CNTH 2 CNTH 2740 000 IDPH.DTE -999.250 IMPH.DTE -999.2S0 250 SFL.DTE -999.250 SP.DTE -999.2S0 000 MTEM.DTE -999.250 MRES.DTE -999.250 250 PEF.SDN -999.250 CALI.SDN -999.2S0 250 NRAT.CNTH -999.250 NCNT.CNTH -999.250 250 CFTC.CNTH -999.250 DEPT. 13473 ILM.DTE 1950 TENS.DTE 6690 DRHD.SDN 0 CRAT.CNTH 2 CNTC.CNTH 2310 000 IDPH.DTE 162 SFL.DTE 000 MTEM.DTE 134 PEF.SDN 548 NRAT.CNTH 069 CFTC.CNTH .000 IDPH.DTE .000 SFL.DTE .000 MTEM.DTE .148 PEF.SDN .322 NRAT.CNTH .174 CFTC.CNTH ** END OF DATA 8.350 IMPH.DTE 9.295 6.976 SP.DTE -16.813 184.071 MRES.DTE 0.197 3.260 CAL1.SDN 13.688 2.496 NCNT.CNTH 2676.176 1093.011 S 986 I 417 177 890 4 386 2 548 903 729 IMPH.DTE SP.DTE MRES.DTE CAL1.SDN NCNT.CNTH 1950.000 -73.750 0.200 10.287 2430.322 ILD.DTE GR.DTE RHOB.SDN NPHI.CNTH FCNT.CNTH ILD.DTE GR.DTE RHOB.SDN NPHI.CNTH FCNT.CNTH ILD.DTE GR.DTE RHOB.SDN NPHI.CNTH FCNT.CNTH PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 8.220 85.963 2.567 23.249 1130.682 16.362 69.641 2.302 21.555 893.594 **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE .: FLIC VERSION : O01CO1 DATE : 93/10/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 93/10/28 MAX REC SIZE : 1024 FlEE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Dep%h shi~ed and clipped curves for open hole logs run in~o casing. PASS NUMBER: 2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-0CT-1993 17:50 DEPTH INCREIvlENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CNTH 13473.0 12285.0 GRCH 13473.0 2410.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH CNTH GRCH REMARKS: NO DEPTH-ADJUSTMENTS WERE MADE TO THIS CASED HOLE DATA. LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ~ 66 0 2 66 0 3 73 5 66 6 73 T 8 68 0.5 9 65 FT 13 66 0 14 65 FT 66 LIS Tape Veri~ica%ion Listing Schlumberger Alaska Computing CenSer ** SET TYPE - CHAN ** 28-0CT-1993 17'50 PAGe- NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) DF_PT FT 619154 O0 000 O0 0 2 1 1 4 68 NPHI CNTH PU-S 619154 O0 000 O0 0 2 1 1 4 68 CRAT CNTH 6i9154 O0 000 O0 0 2 i 1 4 68 NRAT CNTH 619154 O0 000 O0 0 2 1 1 4 68 NCNT CNTH CPS 619154 O0 000 O0 0 2 1 1 4 68 FCNT CNTH CPS 619154 O0 000 O0 0 2 1 1 4 68 CNTC CNTH CPS 619154 O0 000 O0 0 2 1 1 4 68 CFTC CNTH CPS 619154 O0 000 O0 0 2 1 1 4 68 GRCH CNTH GAPI 619154 O0 000 O0 0 2 i i 4 68 TENS CNTH LB 619154 O0 000 O0 0 2 I 1 4 68 TEND CNTH LB 619154 O0 000 O0 0 2 1 1 4 68 MRES CNTH OHMM 619154 O0 000 O0 0 2 1 1 4 68 MTEM CNTH DEGF 619154 O0 000 O0 0 2 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 13473.000 NPHI.CNTH 27.027 CRAT.CNTH 2.885 NCNT.CNTH 2127.495 FCNT.CNTH 805.467 CNTC,CNTH 2342.i22 GRCH.CNTH 55.573 'TENS.CNTH 6620.000 TEND.CNTH 947.568 MTEM.CNTH 177.584 DEPT. 12000.000 NPHI.CNTH -999.250 CRAT.CNTH -999.250 NCNT.CNTH -999.250 FCNT.CNTH -999.250 CNTC.CNTH -999.250 GRCH.CNTH B9.746 TENS.CNTH 6215.000 TEND.CNTH 964.062 MTEM.CNTH 161.954 DEPT. 10000.000 NPHI.CNTH -999.250 CRAT.CNTH -999.250 NCNT.CNTH -999.250 FCNT.CNTH -999.250 CNTC,CNTH -999.250 GRCH.CNTH 61,935 TENS.CNTH 5135.000 TEND.CNTH 869.802 MTEM.CNTH 145.245 NRAT.CNTH CFTC.CNTH MRES.CNTH NRAT.CNTH CFTC.CNTH MRES.CNTH NRAT.CNTH CFTC.CNTH MRES.CNTH DEPT. 8000.000 NPHI.CNTH -999.250 CRAT.CNTH -999.250 NRAT.CNTH NCNT.CNTH -999.250 FCNT.CNTH -999.250 CNTC.CNTH -999.250 CFTC.CNTH GRCH.CNTH 38.903 TENS.CNTH 4575.000 TEND.CNTH 928.941 MRES.CNTH MTF_.M.CNTH 130.264 DEPT. 6000.000 NPHI.CNTH -999.250 CRAT.CNTH -999.250 NCNT.CNTH -999.250 FCNT.CNTH -999.250 CNTC.CNTH -999.250 GRCH.CNTH 42.559 TENS.CNTH 3610.000 TEND.CNTH 915.615 MTF_.M.CNTH 114.414 DEPT. 4000.000 NPHI.CNTH -999.250 CRAT.CNTH -999.250 NCNT.CNTH -999.250 FCNT.CNTH -999.250 CNTC.CNTH -999.250 GRCH.CNTH 35.057 TENS,CNTH 2815.000 TEND.CNTH 909.298 MTEM.CNTH 100.562 NRAT.CNTH CFTC.CNTH MRES.CNTH NRAT.CNTH CFTC.CNTH MRES.CNTH 3.130 894.250 0.200 -999.250 -999,250 0.222 -999.250 -999.250 0.222 -999.250 -999.250 0.270 -999.250 -999.250 0.300 -999.250 -999.250 0.371 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-0CT-1993 17:50 DEPT. 2410.000 NPHI.CNTH -999.250 CRAT.CNTH NCNT.CNTH -999.250 FCNT.CNTH -999,250 CNTC.CNTH GRCH.CNTH 22.414 TENS.CNTH 2420.000 TEND.CNTH MTF_M.CNTH 90,283 -999,250 NRAT.CNTH -999.250 CFTC.CNTH 1073.868 MRES.CNTH PAGE: -999,250 -999,250 0.499 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · 001C01 DATE · 93/10/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : OOlCO1 DATE : 93/10/28 MAX REC SIZE : 1024 FILE TYPE · LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN. PASS Curves and log header da%a for each run and tool s~ring in separa%e files; Tool S~ring ~1 fo Sadlerochi~ run presented firs% (primary depth con~rol s~ring used ~o depth shif~ ~he Sadler interval) followed by files for o%her main pass %ool s~rings per run. RUN NUMBER: 1 TOOL STRING NUMBER: [ Pass NUMBER: 1 DEPTH INCREMENT: 0,5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH DTE LDT CNL $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: 15123.0 13359.0 15123.0 13359.0 15123.0 13359.0 25-SEP-93 5C0-423 2230 25-SEP-93 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-0CT-1993 17:50 TIME LOGGER ON BO'FrOM: TD DRILLER (FT): 'rD LOGGER (FT): TOP LOG INTERVAL (FT): B03-r0M LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 1742 26-SEP-93 15203.0 115170.0 2600.0 115048.0 0.0 TOOL NL~BER AMM SGT CNL LDT DTE DTE $ AUXILLIARY MEASUREMENTS AMM-AA GAMMA RAY SGT-L COMPENSATED NEUTRON CNT-H LITHO-DENSITY TOOL LDT-D PHASOR INDUCTION CART. DIC-EB 3TT PHASOR INDUCTION SONDE DIS-HO 379 BOREHOLE AND CASING DATA OPEN HOLE Blt 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 (0HMM) 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): 8.1500 13502.0 13473.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): LSND 9.70 59.00 10.10 197.0 0.930 0.710 1.1150 63.0 63.0 63.0 REMARKS: THERMAL SANDSTONE 2.615 TOOL STANDOFF (IN): THIS LOG TIED INTO THE GAMMA RAY CURVE FROM THE RET WHICH WAS THE FIRST WIRELINE LOG RUN. THE DUAL INDUCTION TOOL WAS RUN WITH 5 1.215" TEFLON STANDOFFS, AND A 2~ HOLE FINDER. THE DENSITY TOOL WAS RUN ON A MATRIX DENSITY OF 2.65 G/CC., AND A FILTRATE DENSITY OF 10. G/CC. THE NEUTRON WAS RUN ON SANDSTONE MATRIX, HOLE CORRECTION USED WAS THE DENSITY CALIPER. THERE WERE MANY LARGE WASHOUTS IN THE SHALES AND COALS WHICH ADVERSELY EFFECTED THE PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-0CT-1993 17:50 LOGS. THE POROSITY AND RESISTIVITY LOGS ARE INVALID IN THE LARGE WASHOUTS. FOR THE CSG CNL, THE BOREHOLE STATUS WAS SET TO CASED, HC=BS, BS=12.25. $ LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 240 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) DEPT FT 619154 O0 000 O0 0 3 1 I 4 68 CIDP DTE MMHO 519154 O0 000 O0 0 3 I 1 4 68 IDPH DTE OHMM 619154 O0 000 O0 0 3 I I 4 68 ClMP DTE MMHO 619154 O0 000 O0 0 3 1 1 4 68 tMPH DTE OHMM 619154 O0 000 O0 0 3 1 I 4 66 CILD DTE MMHO 519154 O0 000 O0 0 3 1 I 4 68 1ED DTE OHMM 619154 O0 000 O0 0 3 I 1 4 68 ClLM DTE MMHO 619154 O0 000 O0 0 3 I I 4 66 ILM DTE OHMM 619154 O0 000 O0 0 3 I I 4 68 ID~F DTE 619154 O0 000 O0 0 3 I I 4 68 IM~F DTE 619154 O0 000 O0 0 3 I I 4 68 IIRD DTE MMHO 619154 O0 000 O0 0 3 1 I 4 68 IIXD DTE MMHO 619154 O0 000 O0 0 3 I [ 4 68 IIRM DTE MMHO 619154 O0 000 O0 0 3 1 1 4 68 IIXM DTE MMHO 619154 O0 000 O0 0 3 1 1 4 68 SFLU DTE OHMM 619154 O0 000 O0 0 3 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-0CT-1993 17:50 PAGE: 10 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS CHEX) SP DTE MV 619154 O0 000 O0 0 3 1 I 4 68 GR DTE GAPI 619154 O0 000 O0 0 3 1 1 4 66 TENS DTE LB 619154 O0 000 O0 0 3 I I 4 58 MTEM DTE DEGF 619154 O0 000 O0 0 3 I I 4 68 MRES DTE OHMM 619154 O0 000 O0 0 3 I I 4 68 HTEN DTE LB 619154 O0 000 O0 0 3 I 1 4 66 DPHI LDT PU 619154 O0 000 O0 0 3 1 I 4 68 RHDB EDT G/C3 619154 O0 000 O0 0 3 1 1 4 66 DRHO LDT G/C3 619154 O0 000 O0 0 3 I 1 4 56 PEF LDT 619154 O0 000 O0 0 3 1 I 4 66 ~LS LDT 619154 O0 000 O0 0 3 I I 4 68 USS LDT 619154 O0 000 O0 0 3 I 1 4 66 LS LDT CPS 619154 O0 000 O0 0 3 I I 4 68 LU LDT CPS 619154 O0 000 O0 0 3 I 1 4 68 LL LDT CPS 619154 O0 000 O0 0 3 1 I 4 68 LITH gDT CPS 619154 O0 000 O0 0 3 I I 4 68 SS1 LDT CPS 619154 O0 000 O0 0 3 1 I 4 68 SS2 LDT CPS 619154 O0 000 O0 0 3 I 1 4 68 LSHV LDT V 619154 O0 000 O0 0 3 1 I 4 68 SSHV EDT V 619154 O0 000 O0 0 3 I I 4 68 SIRH LDT G/C3 619154 O0 000 O0 0 3 I 1 4 68 LSRH LDT G/C3 619154 O0 000 O0 0 3 I 1 4 68 LURH LDT G/C3 619154 O0 000 O0 0 3 I I 4 68 CALI LDT IN 619154 O0 000 O0 0 3 1 1 4 66 GR LDT GAPI 619154 O0 000 O0 0 3 I I 4 68 TENS LDT LB 619154 O0 000 O0 0 3 I I 4 66 MTEM LDT DEGF 619154 O0 000 O0 0 3 I I 4 68 MRES LDT OHMM 619154 O0 000 O0 0 3 I I 4 68 HTEN EDT LB 619154 O0 000 O0 0 3 I I 4 68 NPHI CNL PU 619154 O0 000 O0 0 3 I I 4 68 RTNR CNL 619154 O0 000 O0 0 3 I I 4 68 TNPH CNL PU 619154 O0 000 O0 0 3 I I 4 68 TNRA CNL 619154 O0 000 O0 0 3 I I 4 68 NPOR CNL PU 619154 O0 000 O0 0 3 I I 4 68 RCNT CNL CPS 619154 O0 000 O0 0 3 I I 4 66 RCFT CNL CPS 619154 O0 000 O0 0 3 I 1 4 68 CNTC CNL CPS 619154 O0 000 O0 0 3 I I 4 66 CFTC CNL CPS 619154 O0 000 O0 0 3 I I 4 68 GR CNL GAPI 619154 O0 000 O0 0 3 I I 4 68 CALl CNL IN 619154 O0 000 O0 0 3 1 I 4 68 TENS CNL LB 619154 O0 000 O0 0 3 I I 4 68 MRES CNL OHMM 619154 O0 000 O0 0 3 1 1 4 66 MTEM CNL DEGF 619154 O0 000 O0 0 3 1 I 4 68 HTEN CNL LB 619154 O0 000 O0 0 3 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 '0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 15123 IMPH.DTE 2 ILM.DTE 2 IIXD.DTE 67 SP.DTE -70 MRES.DTE 0 DRHO.LDT 0 LS.LDT 405 SSl.LDT 258 SlRH.LDT 2 GR.LDT 17 HTEN.LDT -111 TNRA.CNL 3 CNTC.CNL 2511 TENS.CNL 2035 000 363 360 69.5 000 184 O62 .566 212 143 367 297 344 922 000 CIDP DTE CILD DTE IDUF DTE IIRM DTE GR DTE HTEN DTE PEF LDT LU.LDT SS2 LDT LSRH LDT TENS LDT NPHI CNL NPOR CNL CFTC CNL MRES CNL DEPT. 14000 IMPH.DTE 9 ILM.DTE 8 IIXD.DTE 1 SP.DTE -16 MRES.DTE 0 DRHO.LDT 0 LS.LDT 306 SSI.LDT 269 SlRH.LDT 2 GR.LDT 8.5 HTEN.LDT 1108 TNRA.CNL 2 CNTC.CNE 2740 TENS.CNL 70~.5 000 29.5 162 632 813 197 134 833 314 168 963 668 .548 O69 000 CIDP DTE ClLD DTE IDUF DTE IIRM DTE GR DTE HTEN DTE PEF EDT LU LDT SS2 LDT LSRH LDT TENS LDT NPHI CNL NPOR.CNL CFTC.CNL MRES.CNL DEPT IMPH ILM IIXD SP MRES DRHO LS SS1 SIRH GR HTEN TNRA CNTC TENS DTE DTE DTE DTE DTE LDT LDT LDT LDT · EDT ·LDT . CNL . CNL . CNL 13358..500 19.50.000 19.50.000 -440.472 -47 688 0 200 -0 916 286 241 6.5 643 4 402 43 61g 988 08.5 3 439 1386 162 670.5 000 ClDP DTE ClLD DTE IDUF DTE IIRM DTE GR DTE HTEN DTE PEF.LDT LU.LDT SS2.LDT LSRH.LDT TENS.LDT NPHI.CNL NPDR.CNL CFTC.CNL MRES.CNL END OF DATA 28-0CT-1993 17'50 456 158 459 878 0 000 392 .593 17 367 -111 297 2 366 370 390 374 046 2 284 203.5 000 46 77.5 39 6.51 7.59 873 0 184 119 767 121 6.52 0 000 11.5 819 8.5 963 1108 668 3 260 289 499 361 323 2 433 7065 000 23 249 26 210 1093 011 0 197 85 `5`58 83 919 0 000 -468 10`5 43 619 988 08`5 2.5 .523 272 265 130.418 2.419 670`5.000 41.861 32.963 447.87`5 0.200 IDPH.DTE ILD.DTE IUUF.DTE IIXM.DTE TENS.DTE DPHI.LDT ULS.LDT LL.LDT LSHV.LDT LURH.LDT ~TEM.LDT RTNR.CNL RCNT.CNL GR.CNL MTEM.CNL IDPH.DTE ILD.DTE IMUF.DTE IIXM.DTE TENS.DTE DPHI.LDT ULS.LDT LL LDT LSHV LDT LURH LDT MTEM LDT RTNR CNL RCNT CNL QR.CNL ~TEM.CNL IDPH.DTE ILD.DTE IMUF.DTE IIXM DTE TENS DTE DPHI LDT ULS LDT LL LDT LSHV LDT LURH LDT MTEM LDT RTNR CNL RCNT.CNL GR.CNL MTEM.CNL 2 192 2 174 0 000 -0 104 2035 000 18 454 000S 220 372 1476 010 2 291 196 963 3 `500 2622 738 17 367 196 963 8 350 8 220 0 000 -28 798 7065 000 `5 028 -0 004 162 083 1479 100 2.441 184.071 2.496 2676.176 8`5.963 184.071 11 688 11 916 0 000 1321 4.52 6705 000 69 486 -0 O62 1.50 109 1477.47.5 2,454 178.243 3.2.50 1.564.634 43,619 178.243 CIMP.DTE CILM.DTE IIRD.DTE SFLU.DTE MTEM.DTE RHOB.LDT USS. LDT LITH.LDT SSHV.LDT CALI.LDT MRES.LDT TNPH.CNL RCFT.CNL CALI.CNL HTEN.CNL CIMP DTE CILM DTE IIRD DTE SFLU DTE MTEM DTE RHOB LDT USS EDT LITH LDT SSHV LDT CALl LDT MRES LDT TNPH CNL RCFT CNL CALl CNL HTEN CNL CIMP.DTE ClLM.DTE iIRD.DTE SFLU.DTE MTEM.DTE RHOB.LDT USS. LDT LITH.LDT SSHV.LDT CALl. EDT MRES.LDT TNPH.CNL RCFT.CNL CALI.CNL HTEN.CNL PAGE' 423.170 423 714 372 018 3 776 196 963 2 346 0 014 1.59 330 1345 206 2 928 0 184 39 6.51 738 016 2 928 -111 297 107 .588 122 518 106 742 6 976 184 071 2 .567 0 040 88 440 1345 219 13 688 0 197 23 959 1130 682 13 688 1108 668 -347.796 -406.458 78.04.5 9700.000 178.243 1..503 -0.186 31.80.5 1343.022 8.6.59 0.200 36.199 488.710 8.669 988.08.5 LIS Tape Veri~ica%ion Listing Schlumberger Alaska Computing Cen%er **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE · 93/10/28 MAX REC SIZE : 1024 FILE TYPE : LO ~T FILE : 28-0CT-1993 17:50 PAGE: 12 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C0! DATE : 93/10/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE REPEAT PASSES Curves and log header da~a ~or each pass, tool string, and run in separate Giles. RUN NUMBER: 1 TDDL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH DTE LDT CNL $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: 'rD DRILLER (F-T): 'rD LOGGER(FT): TOP LOG INTERVAL (FT). BOTTOM LOG INTERVAL (F-T). LOGGING SPEED (FPHR): 13793.0 13417.0 13793.0 13417.0 13793.0 13417.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 26-SEP-93 5C0-423 2230 25-SEP-93 1742 26-SEP-93 15203.0 15170.0 2600.0 15048.0 0.0 TOOL NUMBER AMM SGT AUXILLIARY MEASUREMENTS AMM-AA GAMMA RaY SGT-L LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Computing Cen%er 28-OCT-lg93 17:50 PAGE: 13 CNL LDT DTE DTE $ COMPENSATED NEUTRON LITH0-DENSITY TOOL PHASOR INDUCTION CART. PHASOR INDUCTION SONDE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH CFT): BDREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF)- RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)' MUD AT MEASURED TEMPERATURE (MT)- MUD AT BOTFOM HOLE TEMPERATURE (BHT) · MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL)' MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): REMARKS: TOOL STANDOFF (IN): CNT-H LDT-D DIC-EB 377 DIS-HB 379 8.500 13502.0 13473.0 LSND 9.70 59.00 10.10 197.0 0.930 0.710 1.150 THERMAL SANDSTONE 2.65 63.0 63.0 63.0 THIS LOG TIED INTO THE GAMMA Ra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ape Veri~ica%ion Lis%ing Schlumberger Alaska Compu%ing Cen~er 28-0CT-1993 17:50 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 240 4 66 1 5 66 6 73 ? 65 8 66 0.5 9 65 FT 11 55 4 12 56 13 66 0 14 65 FT 15 56 66 16 66 1 0 66 I PAGE: 14 · ~ 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 ELF_J~ CODE (HEX) DEPT FT 619154 O0 000 O0 0 4 I I 4 66 0000000000 CIDP DTR MMHO 619154 O0 000 O0 0 4 I I 4 66 0000000000 IDPH DTR OHMM 519154 O0 000 O0 0 4 1 I 4 66 .0000000000 CIMP DTR MMHO 619154 O0 000 O0 0 4 I I 4 66 0000000000 IMPH DTR OHMM 619154 O0 000 O0 0 4 I I 4 68 0000000000 CILD DTR MMHO 619154 O0 000 O0 0 4 I I 4 66 0000000000 ILD DTR OHMM 619154 O0 000 O0 0 4 1 I 4 68 0000000000 CILM DTR MMHO 619154 O0 000 O0 0 4 I I 4 68 0000000000 ILM DTR OHMM 619154 O0 000 O0 0 4 1 1 4 68 0000000000 ID~F DTR 619154 O0 000 O0 0 4 1 I 4 68 0000000000 IM~F DTR 619154 O0 000 O0 0 4 1 I 4 68 0000000000 IIRD DTR MMHO 619154 O0 000 O0 0 4 1 I 4 68 .0000000000 IIXD DTR MMHO 619154 O0 000 O0 0 4 1 I 4 68 0000000000 IIRM DTR MMHO 619154 O0 000 O0 0 4 I I 4 68 0000000000 IIXM DTR MMHO 619154 O0 000 O0 0 4 I I 4 6B 0000000000 SFLU DTR OHMM 619154 O0 000 O0 0 4 I 1 4 68 0000000000 SP D'IR MV 619154 O0 000 O0 0 4 I I 4 68 0000000000 GR DTR GAPI 619154 O0 000 O0 0 4 I I 4 68 0000000000 TENS DTR LB 619154 O0 000 O0 0 4 I I 4 66 0000000000 MTEM DTR DEGF 619154 O0 000 O0 0 4 I I 4 68 0000000000 MRES DTR OHMM 619154 O0 000 O0 0 4 I I 4 66 0000000000 HTEN DTR LB 619154 O0 000 O0 0 4 I 1 4 68 0000000000 DPHI LDR PU 619154 O0 000 O0 0 4 I I 4 68 0000000000 RHOB LDR G/C3 619154 O0 000 O0 0 4 I I 4 66 0000000000 DRHO LDR G/C3 619154 O0 000 O0 0 4 I I 4 66 0000000000 PEF LDR 619154 O0 000 O0 0 4 I I 4 68 0000000000 LIS Tape VerificaSion LisSin9 Schlumberger Alaska Computing Cen%er 28-0CT-1993 17-50 PaGe. 15 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ~LS LDR 619154 O0 000 O0 0 4 1 1 4 68 0000000000 ~SS LDR 619154 O0 000 O0 0 4 1 I 4 68 0000000000 LS LDR CPS 619154 O0 000 O0 0 4 1 1 4 68 0000000000 LU LDR CPS 619154 O0 000 O0 0 4 1 1 4 68 0000000000 LL LDR CPS 619154 O0 000 O0 0 4 i I 4 68 0000000000 LITH LDR CPS 619154 O0 000 O0 0 4 1 1 4 68 0000000000 SS1 LDR CPS 619154 O0 000 O0 0 4 1 1 4 68 0000000000 SS2 LDR CPS 619154 O0 000 O0 0 4 1 1 4 68 0000000000 LSHV LDR V 619154 O0 000 O0 0 4 1 1 4 68 0000000000 SSHV LDR V 619154 O0 000 O0 0 4 1 1 4 66 0000000000 S1RH LDR G/C3 619154 O0 000 O0 0 4 I 1 4 68 0000000000 LSRH LDR G/C3 619154 O0 000 O0 0 4 I I 4 68 0000000000 LURH LDR Q/C3 619154 O0 000 O0 0 4 1 I 4 68 0000000000 CALl LDR IN 619154 O0 000 O0 0 4 I I 4 66 0000000000 GR LDR GAPI 619154 O0 000 O0 0 4 I I 4 68 0000000000 TENS LDR LB 619154 O0 000 O0 0 4 I I 4 68 '0000000000 MTEM LDR DEGF 619154 O0 000 O0 0 4 I I 4 68 0000000000 MRES LDR OHMM 619154 O0 000 O0 0 4 I I 4 66 0000000000 HTEN LDR LB 619154 O0 000 O0 0 4 I I 4 68 0000000000 NPHI CNR PU 619154 O0 000 O0 0 4 1 I 4 68 0000000000 RTNR CNR 619154 O0 000 O0 0 4 I I 4 68 0000000000 TNPH CNR PU 619154 O0 000 O0 0 4 1 1 4 68 0000000000 TNRA CNR 619154 O0 000 O0 0 4 1 1 4 68 0000000000 NPOR CNR PU 619154 O0 000 O0 0 4 1 1 4 68 0000000000 RCNT CNR CPS 619154 O0 000 O0 0 4 1 1 4 68 0000000000 RCFT CNR CPS 619154 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNR CPS 619154 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNR CPS 6i9154 O0 000 O0 0 4 i 1 4 68 .0000000000 GR CNR GAPI 619154 O0 000 O0 0 4 1 1 4 66 0000000000 CALl CNR IN 619154 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNR LB 619154 O0 000 O0 0 4 I 1 4 68 0000000000 MRES CNR OHMM 619154 O0 000 O0 0 4 1 I 4 68 0000000000 MTEM CNR DEGF 619154 O0 000 O0 0 4 1 I 4 68 0000000000 HTEN CNR LB 619154 O0 000 O0 0 4 I I 4 66 0000000000 ** DATA ** DEPT. IMPH. DTR ILM. DTR I IXD. DTR SP. DTR MRES. DTR DRHO. LDR LS. LDR SS1. LDR SIRH. LDR GR. LDR HTEN. LDR 13793 SOO 5 602 5 517 11 078 -60 000 0 200 0 144 609 569 302 339 I 765 86 177 413 582 CIDP DTR CILD D'IR ID~F DTR IIRM DTR GR D'IR HTEN DTR PEF LDR LU.LDR SS2,LDR LSRH,LDR TENS.LDR NPH1.CNR 215 004 IDPH.DTR 217 0 170 86 413 25 604 439 2 2245 22 616 ILD,DTR 000 IM~F.DTR 681 IIXM,DTR 177 TENS,DTR 582 DPHI,LDR 523 ~LS,LDR 016 LL.LDR 501 LSHV.LDR 047 LURH.LDR 000 MTEM.LDR 206 RTNR.CNR 4 651 CIMP DTR 4 0 -26 2245 27 -0 3O7 I472 2 178 1 595 CILM 000 IIRD 084 SFLU 000 MTEM 857 RHOB 129 USS 580 LITH 446 SSHV 018 CALI 733 MRES 957 TNPH DTR DTR DTR DTR LDR LDR LDR LDR LDR LDR CNR 178.512 181 273 187 401 3 603 178 733 2 190 0 036 157 133 1340 790 2 928 0 200 17 512 LIS Tape Verification Listing Schlumberger Alaska Computing Center TNRA.CNR 1.870 NPOR.CNR CNTC.CNR 5481.197 CFTC.CNR TENS.CNR 2245,000 MRES.CNR DEPT. IMPH DTR ILM DTR IIXD DTR SP DTR MRES DTR DRH0 LDR LS LDR SS1 LDR SIRH LDR GR LDR HTEN LDR TNRA CNR CNTC CNR TENS CNR 13416 500 1950 000 1950 000 -439 932 -8 438 0 199 -0 736 115 125 71 737 46 961 1031 134 2 429 2238 570 6745 000 ClDP. DTR CILD. DTR IDQF. DTR IIRM.DTR GR.DTR HTEN.DTR PEF.LDR LU LDR SS2 LDR LSRH LDR TENS LDR NPHI CNR NPOR CNR CFTC CNR MRES CNR ** END OF DATA ** 28-0CT-1993 17:50 17.512 RCNT.CNR 2949.377 GR.CNR 0.200 MTEM.CNR 51 607 89 124 0 000 -395 954 46 961 1031 134 32 388 128 021 105 400 3 045 6745 000 25 204 23 463 925 099 0 199 IDPH D'IR ILD DTR IMQF DTR IIXM DTR TENS D'IR DPHI LDR I~LS LDR LL LDR LSHV LDR LURH LDR MTEM LDR RTNR CNR RCNT CNR GR CNR MTEM CNR 5723.006 RCFT.CNR 86.177 CALI.CNR 178.733 HTEN.CNR 19 377 CIMP.DTR 11 0 1055 6745 20 -0 51 1475 3 178 2 2506 46 178 22O CILM.DTR 000 IIRD.DTR 180 SFLU.DTR 000 MTEM.DTR 661 RHOB.LDR 096 ~SS.LDR 115 LITH.LDR 667 SSHV.LDR 044 CALI.LDR 814 MRES.LDR 4O6 TNPH.CNR 845 RCFT.CNR 951 CALI.CNR 814 HTEN.CNR PAGE: 16 2864.544 2.928 413.582 -830 322 -386 879 79 398 9700 000 178 814 2 309 -0 068 11 961 1342 019 8 621 0 199 25 798 932 282 8 621 1031 134 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : DATE · 93/10/28 MAX REC SIZE ,: 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 93/10/28 · MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW CASED HOLE MAIN PASS Curves and log header da~a for open hole logs run in~o casing, RUN NUMBER: TOOL STRING NUMBER: 2 PASS NUMBER: DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Compu%ing Cen~er 28-0CT-1993 17'50 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CNL 13556.0 GR 13556.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON B0q-FOM: TD DRILLER (F-r): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 12285.0 2410.0 25-SEP-93 $C0-423 2230 2S-SEP-93 1742 26-SEP-93 15203.0 15170.0 2600.0 15048.0 TOOL NUMBER AMM SGT CNT LDT DTE DTE $ AUXILLIARY MEASUREMENTS AMM-AA GAMMA RaY SGT-L COMPENSATED NEUTRON CNT-H LITHO-DENSITY TOOL LDT-D PHASOR INDUCTION CART. DIC-EB 377 PHASOR INDUCTION SONDE DIS-HB 379 BOREHOLE AND CASING DATA OPeN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 13502.0 13473.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) 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): LSND 9.70 59.00 10.10 197.0 0.930 0.710 1.1SO NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 63.0 63.0 63.0 PaGe- 17 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-0CT-1993 17:50 TOOL STANDOFF (IN) : REMARKS: THIS LOG TIED INTO THE GAMMA RaY CURVE FROM THE RFT WHICH WAS THE FIRST WlRELINE LOG RUN. THE DUAL INDUCTION TOOL WAS RUN WITH 5 1.25" TEFLON STANDOFFS, AND A 2' HOLE FINDER. THE DENSITY TOOL WAS RUN ON A MATRIX DENSITY OF 2.65 G/CC., AND A FILTRATE DENSITY OF 10. G/CC. THE NEUTRON WAS RUN ON SANDSTONE MATRIX, HOLE CORRECTION USED WAS THE DENSITY CALIPER. THERE WERE MANY LARGE WASHOUTS IN THE SHALES AND COALS WHICH ADVERSELY EFFECTED THE LOGS. THE POROSITY AND RESISTIVITY LOGS ARE INVALID IN THE LARGE WASHOUTS. FOR THE CSG CNL, THE BOREHOLE STATUS WAS SET TO CASED, HC=BS, BS=12.25. $ LIS FORMAT DATA PAGE: i8 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64LB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 64 4 65 5 65 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 I SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 API API AP1 FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP' ELEM CODE PROCESS (HEX) DEPT FT 619154 O0 000 O0 0 5 I 1 4 68 NPHI CSG PU 619154 O0 000 O0 0 5 I I 4 68 RTNR CSG 619154 O0 000 O0 0 5 1 I 4 68 TNPH CSG PU 619154 O0 000 O0 0 5 1 1 4 68 0000000000 0000000000 0000000000 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-0CT-1993 17:SO PAGE: 19 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TNRA CSG 619154 O0 000 O0 0 5 I 1 4 68 NPOR CSG PU 619154 O0 000 O0 0 5 I I 4 68 RCNT CSG CPS 619154 O0 000 O0 0 5 I I 4 68 RCFT CSG CPS 619154 O0 000 O0 0 5 1 1 4 68 CNTC CSG CPS 619154 O0 000 O0 0 5 I I 4 68 CFTC CSG CPS 619154 O0 000 O0 0 5 I I 4 68 GR CSG GAPI 619154 O0 000 O0 0 5 1 1 4 68 CALl CSG IN 619154 O0 000 O0 0 5 1 1 4 68 TENS CSG LB 619154 O0 000 O0 0 5 I I 4 68 MRES CSG OHMM 619154 O0 000 O0 0 5 1 1 4 68 MTEM CSG DEGF 619154 O0 000 O0 0 5 I I 4 68 HTEN CSG LB 619154 O0 000 O0 0 5 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 13556.500 NPHI.CSG 15.136 RTNR.CSG 2.250 TNRA.CSG 2.150 NPOR.CSG 15.852 RCNT.CSG 2223.540 CNTC.CSG 2129.591 CFTC.CSG 1007.796 GR.CSG 68.942 TENS.CSG 2090.000 MRES.CSG 0.201 MTEM.CSG 177.504 DEPT. 12000.000 NPHI.CSG -999.250 RTNR.CSG -999.250 TNRA.CSG -999.250 NPOR.CSG -999.250 RCNT.CSG -999.250 CNTC.CSG -999.250 CFTC.CSG -999.250 GR.CSG 89.746 TENS.CSG 6215.000 MRES.CSG 0.222 MTEM.CSG 151.954 DEPT. 10000.000 NPHI.CSG -999.250 RTNR.CSG -999.250 TNRA.CSG -999.250 NPOR.CSG -999.250 RCNT.CSG -999.250 CNTC.CSG -999.250 CFTC.CSG -999.250 GR.CSG 51.935 TENS.CSG 5135.000 MRES.CSG 0.222 MTEM.CSG 145.245 DEPT. 8000.000 NPHZ.CSG -999.250 RTNR.CSG -999.250 TNRA.CSG -999.250 NPOR.CSG -999.250 RCNT.CSG -999.250 CNTC.CSG -999.250 CFTC.CSG -999.250 GR.CSG 38.903 TENS.CSG 4575.000 MRES.CSG 0.270 MTEM.CSG 130.264 DEPT, 6000.000 NPHI.CSG -999.250 RTNR.CSG -999.250 TNRA.CSG -999.250 NPOR.CSG -999.250 RCNT.CSG -999.250 CNTC.CSG -999.250 CFTC.CSG -999.250 GR.CSG 42.559 TENS.CSG 3610.000 MRES.CSG 0.300 MTEM.CSG 114.414 DEPT. 4000.000 NPHI.CSG -999.250 RTNR.CSG -999.250 TNRA.CSG -999.250 NPOR.CSG -999.250 RCNT.CSG -999.250 CNTC.CSG -999.250 CFTC.CSG -999.250 GR.CSG 35.057 TENS.CSG 2815.000 MRES.CSG 0.371 MTEM.CSG 100.552 DEPT. 2409.500 NPHI.CSG -999.250 RTNR.CSG -999.250 TNRA.CSG -999.250 NPOR.CSG -999.250 RCNT.CSG -999.250 CNTC.CSG -999.250 CFTC.CSG -999.250 GR.CSG 22.414 TENS.CSG 2420.000 MRES.CSG 0.499 MTEM.CSG 90.223 TNPH.CSG RCFT.CSG CALI.CSG HTEN.CSG TNPH.CSG RCFT.CSG CALI.CSG HTEN.CSG TNPH.CSG RCFT.CSG CALI.CSG HTEN.CSG TNPH.CSG RCFT.CSG CALI.CSG HTEN.CSG .TNPH.CSG RCFT.CSG CALI.CSG HTEN.CSG TNPH.CSG RCFT.CSG CALI.CSG HTEN.CSG TNPH.CSG RCFT.CSG CALI.CSG HTEN.CSG 15.852 978.809 2.928 434.329 -999.250 -999.250 -999.250 964.052 -999.250 -999.250 -999.250 869.802 -999.250 -999.250 -999.250 928.941 -999.250 -999.250 -999.250 915.615 -999.250 -999.250 -999.250 909.298 -999.250 -999.250 -999.250 1043.720 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center 28-0CT-1993 17:50 PAGE: 20 END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .OOS SERVICE : FLIC VERSION : OO1CO1 DATE : 93/10/28 MAX REC SIZE : 1024 FILE TYPE · LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 93/10/28 ORIGIN : FLIC TAPE NAME : 93454 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION,ENDICOq-F,2-66/SD12 MPI,50-029-22374-00 **~* REEL TRAILER **~ SERVICE NAME : EDIT DATE · 93/10/28 ORIGIN : FLIC REEL NAME .: 93454 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION,ENDICOTT,2-66/SD~2 MPI,50-029-22374-00 Schlumberger Page ***************************** SCHLUMBERGER SCHLUMBERGER GEOQUEST ALASKA DIVISION COMPUTER CENTER 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 907/562-7669 TAPE VERIFICATION LISTING LIS FORMAT LIS TAPE VERIFICATION FOR RFT FIELD TAPE Job Number 93454 Company Name BP EXPLORATIDN Well Name 2-66/SD12 MPI Field Name ENDICOTT County NORTH SLOPE S~a~e ALASKA Service Order Number 619154 Da~e Acquired 26-SEP-93 Run Number ONE Da~e'Processed Files Included 28-0CT-93 RFT FILES .017 THRU .036 Schlumberger Page 3 LIST Command List,lng KEY I LIST SUMMARY MNEMONICS Summary ou%put, is creat,ed by LIST/SUMMARY summaries writ,~en for Logical LIS st,ruct,ures: FILE (Abbrev: F) LIS logical file info TAPE (Abbrev: T) LIS logical t,ape info REEL (Abbrev: R) LIS logical reel info and for ~he entire LIS/A input, logical unit,: LU (Abbrev: L) LIS/A logical unit, info The field labels appear on some or all of t,hese summaries, as indicat,ed by t,he abbrev, on right,. Summary Field Labels: REELS TAPES FILES #PR #LR #DR #ENC #FM PI PI UNITS MAXPI MINPI Number of logical reels on (L ) Number of logical t,apes on (LR ) Number o~' Iog'ica[ fi les on (LRT) Number of physi ca I records (LRTF) Number of Iogica I records (LRTF) Number of dat,a records ( F) Number of encrypt, ed records ( F) Number of dat,a frames ( F) Primary index channel name ( F) Primary index unit,s mnemonic ( F) Maximum primary index value ( F) Minimum primary index value ( F) NOTE - DEPTH OF PRESSURE.TEST IS RECORDED AS CHANNEL FDEP. FDEP IS ALSO LISTED IN "CONS" TABLE ON TESTS WHERE THE CSU TABLES WERE DUMPED TO TAPE. FOR FORMATION TEST FILES, "DEPT" INCLUDED IN THESE LISTINGS DOES NOT REFER TO DEPTH OF MEASUREMENT BUT IS AN INTERNAL COUNTER USED WHEN MEASURING IN TIME. IN AN ATTEMPT TO KEEP THIS LISTING TO A REASONABLE LENGTH, ONLY SPECIFIC CHANNELS AND CONSTANTS ARE LISTED. THIS LISTING DOES NOT INCLUDE MANY OF THE CHANNELS AND CONSTANTS INCLUDED ON THE FIELD TAPE. Schlumberger LIST MUBO-[]LISA.DAT; 28-0CT-93 19:09'38 Page 4 Reel header DEFAULT ** REEL HEADER SERVICE NAME : RFTB DATE : 93/09/25 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY Tape header DEFAULT ** TAPE HEADER SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY (EOF) Fi le header RFTB .036 ** FILE HEADER FILE NAME : RFTB .036 SERVICE NAME : SPLICE VERSION # : 5C0-423 DATE : 93/09/26 MAX. REC. LEN.: 8~92 FILE TYPE : DL PREVIOUS FILE : Table t~vpe CONS LisCing of sec 12 Cype CONS OBJNAM STAT TUNI PUNI DESC VALU FDEP ALLO F F FormaCion DepCh 1S083.92 End of sec Table type CONS Listing of set 13 type CONS 0BJNAM STAT TUNI PUNI DESC VALU End of sec Sch I umberger LIST MUB0: [] LISA. DAT; Tab I e t,ype CONS List, lng of set, 14 t,ype CONS OBJNAM STAT TUNI PUNT DF_SC VALU 28-OCT-g3 19:09:38 Page End of set, Table t,ype CONS List,lng of set, 16 CONS OBJNAM STAT TUNI PUNI DF_SC VALU End of set FLIC comment, FLIC comment, ext,ract,ed from SET: DEFAULT Dat,a format, specificat,ion record SPLICE segment, from 15121.00 t,o 14490.00 FT FILE: RFTB .029 List,ing of set, I t,ype 64EB object, 0 ENTRY VALUE REPCODE SIZE I 0 66 1 2 O. 66 1 3 146 79 2 4 I 66 1 S I 66 1 6 0 73 4 ? IN 65 2 8 60 73 4 9 .lIN 65 4 11 S6 66 1 12 -999.25 68 4 13 I 66 1 14 .lIN 65 4 15 73 66 1 16 I 66 1 0 66 0 End of se5 Lis~ing of set, 0 t,ype CHAN NAME SERV ID UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REP PROCESS ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB GR RFTB S 63 621 0 I I I 4 68 0000000000 GAPI 0 I I I 4 68 0000000000 End of set, Schlumberger LIST MUBO:[]LISA.DAT; 28-0CT-93 19:09'38 Page 6 Da~a record %ype 0 DEPT 1814580 .lin 15121.5 FT 4609.0332 M ETIM 0.412 GR 11.49032 Fi let, railer RFTB .036 ** FILE TRAILER ** FILE NAME : RFTB .036 SERVICE NAME : SPLICE VERSION # : 5C0-423 DATE : 93/09/26 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY #LR #PR #ENC #DR #FM PI PI_UNITS MAXPI MINPI 83 107 0 42 2349 DEPT .lIN 1814580 1673700 DEPT F 15121.5 13947.5 DEPT M 4609.0332 4251.198 (EOF) Tape ~railer DEFAULT ** TAPE TRAILER ** SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: 1 NEXT TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY TAPE SUMMARY FILES #ER #PR 1 8,5 109 Ree I ~,ra i I er DEFAULT Schlumberger LIST MUBO:[]LISA.DAT; 28-0CT-93 19:09:38 Page 7 ** REEL TRAILER ** SERVICE NAME : RFTB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: 1 NEXT REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY REEL SUMMARY FILES TAPES #LR #PR Reel header DEFAULT ** REEL HEADER ** SERVICE NAME : RFTB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: l PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY Tape header DEFAULT ** TAPE HEADER ** SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: 1 PREVIOUS TAPE : COMMENT · PROCESSED BY SCHLUMBERGER DLiS TO LIS CONVERTER UTILITY (EOF) File header RFTB .0~7 ** FILE HEADER FILE NAME : RFTB .017 SERVICE NAME : STATIO VERSION # : SC0-423 DATE : 93/09/26 MAX. REC. LEN.: 8~92 FILE TYPE : DL PREVIOUS FlEE : Schlumberger LIST MUBO:[]LISA.DAT; Table ~ype CONS Lis~ing of'se~ 7 ~ype CONS 28-0CT-93 I9:09:38 Page OBJNAM STAT TUNI PUNI DESC VALU FDEP ALLO F F Forma%ion Dep%h 13984, ~ype CONS End Table ~ype CONS Lis~ing of se~ 8 OBJNA~ STAT TUNI PUNI DESC VALU End of Table %ype CONS Lis~ing of se~ 9 · bype CONS OBJNAM STAT TUNI PUNI DESC VALU End of se~ · Da~a formaC specification record Lis~ing of se~ 3 ~ype 64EB objec~ 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 55 1 3 102 79 2 4 2S5 $6 1 S 0 $6 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 11 80 66 1 12 -999.25 68 4 13 1 66 l 14 .SaS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of se~ Schlumberger LIST MUBO:[]LISA.DAT; 28-0CT-93 19:09:38 Page 9 Listing of set 0 type CHAN NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 13 I I 4 68 0000000000 SGP RFTB PSI 81 400 0 13 I I 4 68 0000000000 PONE RFTB 81 400 0 13 1 I 4 88 0000000000 PTEN RFTB 81 400 0 13 1 I 4 68 0000000000 PHUN RFTB 81 400 0 13 1 1 4 68 0000000000 PTHO RFTB 81 400 0 13 I I 4 68 0000000000 End of set Data record type 0 TIME 21015942 .SMS ETIM O. SGP 5282.002 PONE 2. PTEN 8. PHUN 2. PTHO 5. Data record type 0 TIME 21495942 .5MS ETIM 240. SGP 5272.237 PONE 2. PTEN 7. PHUN 2. PTHO 5. Data record type 0 TIME 21975942 .SMS ETIM 480. SGP 5265.991 PONE 6. PTEN 6. PHUN 2. PTHO 5. File trailer RFTB .017 ** FILE TRAILER ** FILE NAME : RFTB .017 SERVICE NAME : STATIO VERSION # : 5C0-423 DATE : 93/09/26 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : Schlumberger LIST MUBO'[]LISA.DAT; 28-0CT-93 19:09:38 Page FILE SIJIVlMARY #ER #PR #ENC #DR #EM PI P~_UNITS MAXPI MINPI 47 58 0 23 1771 TIME .5MS 21015942 22077942 (EOF) Tape ~ra i I er DEFAULT ** TAPE TRAILER ** SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: 1 NEXT TAPE : COMMENT ' PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY TAPE SUMMARY FILES #LR #PR 1 49 60 Reel ~railer DEFAULT ** REEL TRAILER ** SERVICE NAME : RFTB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: 1 NEXT REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY REEL SUMMARY FILES TAPES #LR #PR 1 1 S1 62 Reel header DEFAULT Schlumberger LIST MUBO: []LISA.DAT; 28-0CT-93 19:09:38 Page ** REEL HEADER ** SERVICE NAME : RFTB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: 1 PREVIOUS REEL : COMMENT : PRDCESSED BY SCHLUMBERGER DLIS TO LIS CDNVERTER UTILITY Tape header DEFAULT ** TAPE HEADER ** SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY (EOF) File header RFTB .019 ** FILE HEADER ** FILE NAME : RFTB .019 SERVICE NAME : STATIO VERSION ~ : SC0-423 DATE : 93/09/26 MAX. REC. gEN.: 8192 FILE TYPE : DE PREVIOUS FILE : Table ~ype CONS Lis%lng of se% 7 %ype CONS OBJNAM STAT TUNI PUNI DESC VALU FDEP ALLO F F Forma%ion Depth 14510. End of se~ Table ~ype CONS Listing o4 se~ 8 type CONS 0BJNAM STAT TUNI PUNI DESC VALU 11 End of set Schlumberger LIST MUBO:[]LISA.DAT; Table ~ype CONS Listing of set 9 type CONS OBJNAM STAT TUNI PUNI DESC VALU 28-0CT-93 19:09:38 Page 12 End of set Data formaC specification record Listing of set S type 64EB object 0 ENTRY VALUE REPCODE SIZE 2 0 66 1 3 [02 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .$MS 65 4 11 80 66 1 Z2 -999.25 68 4 13 I 66 1 14 .SMS 65 4 15 73 66 1 16 I 66 1 0 66 0 End of set Listing of se~ 0 ~ype CHAN NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 15 I I 4 SGP RFTB PSI 81 400 0 15 I I 4 PONE RFTB 81 400 0 15 I I 4 PTEN RFTB 81 400 0 15 , I I 4 PHUN RFTB 81 400 0 15 I I 4 PTHO RFTB 81 400 0 15 I I 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 End of set Da~a record ~ype 0 TIME 24689078 .6MS ETIM O. SGP 5496.524 PONE 6. PHUN 4. PTHO 5. PTEN 9. Schlumberger LIST MUBO'[]LISA.DAT; 28-0CT-93 19'09'38 Page 13 Da%a record ~ype 0 TIME 25169078 .5MS ETIM 240. SGP 5210.56 PONE O. PHUN 2. PTHO 5. PTEN 1. Da~a record ~ype 0 TIME 25649078 .SMS ETIM 480. SGP S250.302 PONE O. PHUN 2. PTHO 5. PTEN 5. Da~a record ~ype 0 TIME 26129078 .5MS ETIM 720. SGP 5485.151 PONE 5. PHUN 4. PTHO 5. PTEN 8. File ~railer RFTB .O19 ** FILE TRAILER ~. FILE NAME : RFTB .019 SERVICE NAME : STATIO VERSION # : 5C0-423 DATE : 93/09/26 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY #LR #PR #ENC #DR #FM PI PI_UNITS MAXPI MINPI 57 68 0 33 2574 TIME .SMS 24689078 26232878 (EOF) Tape ~railer DEFAULT ** TAPE TRAILER ** SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: 1 NEXT TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TD LIS CONVERTER UTILITY Schlumberger LIST MUBO' []LISA.DAT; 28-0CT-93 19:09:38 Page 14 TAPE SUMMARY FILES #LR #PR 1 59 70 Reel ~railer DEFAULT ** REEL TRAILER SERVICE NAME : RF'TB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: ! NEXT REEL : COMMENT · PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY REEL SUMMARY FILES TAPES #LR #PR 1 1 61 72 Reel header DEFAULT ** REEL HEADER SERVICE NAME : RF"I'B DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: ! PREVIOUS REEL : COMMENT · PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER. UTILITY Tape header DEFAULT ** TAPE HEADER SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: PREVIOUS TAPE : COMMENT · PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER LITIL[TY (EOF) File header RFTB .020 Schlumberger LIST MUBO:[]LISA.DAT; 28-0CT-93 19:09:38 Page ** FILE HEADER FILE NAME : RFTB .020 SERVICE NAME : STATIO VERSION # : SC0-423 DATE : 93/09/26 MAX. REC. LEN.: 8192 FlEE TYPE : DL PREVIOUS FlEE : Table Cxpe CONS LisCing of sec 7 Cype CONS OBJNAM STAT TUNI PUNI DESC VALU FDEP ALLO F F FormaCion DepCh 14596. End of sec Table Cype CONS LisCing of sec 8 ~ype CONS OBJNAM STAT TUNI PUN1DESC VALU End of sec Table Cype CONS LisCing o~ sec g CONS OBJNAM STAT TUNI PUNI DESC VALU End of sec Da~a forma~ specification record LisCing o~ sec 7 ~ype $4EB objecC 0 ENTRY VALUE REPCODE SIZE 3 102 79 2 4 255 66 $ 0 66 6 0 73 4 7 IN 65 2 8 600 73 4 g .SMS 65 4 11 80 66 12 -999.25 68 4 13 I 66 14 .5MS 65 4 Schlumberger LIST MUBO'[]LISA.DAT; 15 73 66 16' 1 66 0 56 End 28-0CT-93 19'09-38 Page Lis~,ing of se~, 0 t, ype CHAN NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 621 0 16 1 I 4 68 0000000000 SGP RFTB PSI 81 400 0 16 1 I 4 68 0000000000 PONE RFTB 81 400 0 16 1 1 4 68 0000000000 PTEN RF'i'B 81 400 0 16 I I 4 68 0000000000 PHUN RFTB 81 400 0 16 1 I 4 58 0000000000 PTHO RFTB 81 400 0 16 1 I 4 68 0000000000 End of se~ Da~,a record ~,ype 0 TIME 26460914 .E, MS ETIM O. SGP 5540.511 PONE O. PTEN 4. PHUN 5. PTHO 5. Da~a record %ype 0 TIME 26940914 .SMS ETIM 240. SGP 5221.501 PONE 1. PTEN 2. PHUN 2. PTHO 5. Fi le %rai let RFTB .020 ** FILE TRAILER ** FILE NAME : RFTB .020 SERVICE NAME : STATIO VERSION # : 5C0-423 DATE : 93/09/26 MAX. REC. gEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY #LR #PR #ENC #DR #FM PI PI_UNITS MAXPI MINPI 42 53 0 18 1379 TIME .5MS 25460914 27287714 (EOF) Tape ~railer DEFAULT Sch I umberger LIST MUBO: [] LISA. DAT; 28-0¢T-93 19:09:38 Page 17 ** TAPE TRAILER SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: 1 NEXT TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY TAPE SUMMARY FILES #LR #PR :L 44 55 Reel trailer DEFAULT ** REEL TRAILER SERVICE NAME : RFTB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: NEXT REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY REEL SUMMARY FILES TAPES #LR #PR 1 1 46 57 Reel header DEFAULT ** REEL HEADER SERVICE NAME : RFTB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATIDN #: PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LiS CONVERTER UTILITY Tape header DEFAULT Schlumberger LIST MUBO:[]LISA.DAT; 28-0CT-93 19:09:38 Page 18 ** TAPE HEADER ** SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY (EOF) Fi le header RFTB .021 ** FILE HEADER ** FILE NAME : RFTB .021 SERVICE NAME : STATIO VERSION # : 5C0-423 DATE : 93/09/26 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table t,ype CONS List,lng of set, 7 %ype CONS OBJNAM STAT TUNI PUNI DESC VALU FDEP ALLO F F Format,ion Dept,h 14651. End of set, Table t,ype CONS List,lng of set, 8 ~,ype CONS OBJNAM STAT TUNI PUNI DF_SC VALU End of set, Table t, ype CONS List,ing of set, 9 t,ype CONS 0BJNAM STAT TUNI PUNI DESC VALU End of set, Schlumberger LIST MUBO:[]LISA.DAT; 28-0CT-93 19:09:38 Page Da~a forma~ specification record Lis~ing of se~ 9 ~ype 64EB objec~ 0 ENTRY VALUE REPCODE SIZE 2 0 66 3 102 79 2 4 255 66 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 I 66 1 0 66 0 End of se% Lis~ing of se~ 0 ~ype CHAN 19 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 521 0 17 I I 4 68 0000000000 SGP RFTB PSi 81 400 0 17 1 I 4 68 0000000000 PONE RFTB 81 400 0 17 1 1 4 68 0000000000 PTEN RFTB 81 400 0 17 I I 4 68 0000000000 PHUN RF'I'B 81 400 0 17 I I 4 68 0000000000 PTHO RFTB 81 400 0 17 I I 4 68 0000000000 End of se% Da~a record ~ype 0 TIME 27473728 .5MS ETIM O. SGP 5559.823 PONE 9. PTEN 5. PHUN 5. PTHO 5. Data record ~ype 0 TIME 27953728 .SMS ETIM 240. SGP 5382.38 PONE 2. PTEN 8. PHUN 3. PTHO 5. Sch I umberger LIST MUBO: [] LISA. DAT; 28-0CT-93 19:09:38 Page 20 Dat, a record t,>,pe 0 TIME 28433728 .,5MS ETIM 480. SGP 5546.372 PONE 6. PHUN .5. PTHO .5. PTEN 4. File ~railer RFTB .021 ** FILE TRAILER ** FILE NAME : RFTB .02! SERVICE NAME : STATIO VERSION # : .5C0-423 DATE : 93/09/26 MAX. REC. LEN.: 8192 FILE TYPE · DL NEXT FILE : FILE SUMMARY #LR #PR #ENC #DR #FM PI PI_UNITS MAXPI MINPI 46 `57 0 22 1694 TIME .`SMS 27473728 28489.528 {EOF) Tape ~rai let DEFAULT ** TAPE TRAILER ~. SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN · DLIS TAPE NAME : DEFAULT CONTINUATION 4:1 NEXT TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY TAPE SUMMARY FILES #LR #PR 1 48 .59 Reel ~railer DEFAULT Schlumberger LIST MUBO:[]LISA.DAT; 28-OCT-g3 19:09:38 Page 21 ** REEL TRAILER SERVICE NAME : RFTB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: 1 NEXT REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY REEL SUMMARY FILES TAPES #ER #PR I 1 50 61 Reel header DEFAULT ** REEL HEADER ** SERVICE NAME : RFTB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: 1 PREVIOUS REEL : COMMENT' ':. 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PHUN 4. PTHO S. File Crailer RFTB .031 Sch~umber9er LIST MUBO'[]LISA.DAT; ** FILE TRAILER ** FILE NAME : RFTB .051 SERVICE NAME : STATIO VERSION # : 5C0-423 DATE : 93/09/26 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : 28-0CT-93 19:09'38 Page 43 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI_UNITS MAXPI MINPI 3! 42 0 7 525 TIME .SMS 36823036 37137436 (EOF) Tape ~railer DEFAULT ** TAPE TRAILER ** SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: 1 NEXT TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY TAPE SUMMARY FILES #LR #PR I 33 44 Reel trailer DEFAULT ** REEL TRAILER SERVICE NAME : RFTB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: 1 NEXT REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LiS CONVERTER UTILITY REEL SUMMARY FLEES TAPES #LR #PR 1 1 35 46 Sch I umberger LIST MUBO: [] LISA. 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SGP 5486.766 PONE 6. PHUN 4. PTHO PTEN 8. Schlumberger LIST MUBO' []LISA.DAT; 28-0CT-93 19'09'38 Page 46 Da~a record type 0 TIME 37759740 .SMS ETIM 240. SGP 5485,852 PONE 5. PHUN 4. PTHO 5. PTEN 8. File ~railer RFTB .032 ** FILE TRAILER ** FILE NAME : RFTB .032 SERVICE NAME : STATIO VERSION # : 5C0-423 DATE : 93/09/26 MAX. REC. LEN.: 8Z92 FILE TYPE · DL NEXT FILE : FILE SUMMARY #LR #PR #E. NC #DR #FM PI PI_UNITS MAXPI MINPI 36 47 0 12 948 TIME .SMS 37279740 37847940 (EOF) Tape tra i ler DEFAULT ** TAPE TRAILER .~ SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: 1 NEXT TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY TAPE SUMMARY FILES #LR #PR [ 38 49 Reel trailer DEFAULT Sch I umberger LIST MUBO: [] LISA. DAT; 28-0CT-93 19:09:38 Page 47 ** REEL TRAILER SERVICE NAME : RFTB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: ! NEXT REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY REEL SUMMARY FILES TAPES #LR #PR 1 1 40 51 Reel header DEFAULT ** REEL HEADER SERVICE NAME : RFTB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY Tape header DEFAULT ** TAPE HEADER ** SERVICE NAME : FRFTB DATE : 9'3/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY (EOF) File header RFTB .034 ** FILE HEADER ** FILE NAME : RFTB .034 SERVICE NAME : STATIO VERSION # : SC0-423 DATE : 93/09/26 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Schlumberger LIST MUBO'[]LISA,DAT; Table Cype CONS LisCing o~ sec 7 Cype CONS 28-0CT-93 19:09:38 Page 48 OBJNAM STAT TUNI PUNI DF_SC VALU FDEP ALLO F F FormaCion DepCh 13983.75 Cype CONS End o~ sec Table Cype CONS LisCing o~ sec 8 0BJNAM STAT TUNI PUNI DESC VALU End o~ sec Table Cype CONS LisCing o~ sec 9 Cype CONS 0BJNAM STAT TUNI PUNI DF_SC VALU End of sec DaCa formaC specificaCion record LisCing o~ sec 27 Cype 64EB objecC 0 ENTRY VALUE REPCODE SIZE I 0 66 1 2 0 66 1 3 102 T9 2 5 0 66 1 6 0 73 4 T IN 6S 2 8 600 73 4 9 .SMS 65 4 11 80 66 1 12 -999.25 68 4 13 I 66 1 14 .SMS 65 4 15 73 66 1 16 I 66 1 0 66 0 End o~ sec Schlumberger LIST MUBO:[]LISA.DAT; Lis~,ing of set~ 0 t, ype CHAN 28-OCT-93 19:09:38 Page 49 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) ETIM RFTB S 63 62! 0 30 1 1 4 68 0000000000 SGP RFTB PSI 81 400 0 30 1 1 4 68 0000000000 PONE RF-I'B 81 400 0 30 I I 4 68 0000000000 PTEN RFTB 81 400 0 30 1 1 4 68 0000000000 PHUN RFTB 81 400 0 30 1 1 4 68 0000000000 PTHO RF'I'B 81 400 0 30 1 I 4 68 0000000000 End o4 se~ Da~a record ~ype 0 TIME 39534220 .SMS ETIM O. SGP 5273.009 PONE 3. PTEN 7. PHUN 2. PTHO 5. Da~a record ~ype 0 TIME 40014220 .SMS ETIM 240. SGP 2.105921 PONE 2. PTEN O. PHUN O. PTHO O. Da~a record ~ype 0 TIME 40494220 .SMS ETIM 480. SGP 3.804468 PONE 3. PTEN O. PHUN O. PTHO O. Da~a record ~ype 0 TIME 40974220 .SMS ETIM 720. SGP 60.24989 PONE O. PTEN 6. PHUN O. PTHO O. Da~a record ~¥pe 0 TIME 41454220 .SMS ETIM 960. SGP 2359.446 PONE 9. PTEN PHUN 3. PTHO 2. Schlumberger LIST MUBO'[]LISA.DAT; 28-0CT-93 19'09'38 Page 50 DaCa record ~ype 0 TIME 41934220 .5MS ETIM 1200. SGP 4929.039 PONE 9. PHUN 9. PTHO 4. PTEN 2. Da~,a record ~,ype 0 TIME 42414220 .SMS ETIM 1440. SGP 5020.551 PONE O. PHUN O. PTHO 5. PTEN 2. Da%a record ~ype 0 TIME 42894220 .SMS ETIM 1580. SGP 5043.834 PONE 3. PHUN O. PTHO 5.. PTEN 4. Da~a record ~ype 0 TIME 43374220 .SMS ETIM 1920. SGP 5265.737 PONE 5. PHUN 2. PTHO 5. PTEN 6. File ~railer RFTB .034 ** FILE TRAILER FILE NAME : RFTB .034 SERVICE NAME : STATIO VERSION # : 5C0-423 DATE : 93/09/26 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY ~LR #PR #ENC #DR #FM PI PI_UNITS MAXPI MINPI 108 :[19 0 84 6694 TIME .SMS 39534220 43550020 (EOF) Tape 'bra i I er DEFAULT Schlumberger LIST MUBO:[]LISA.DAT; 28-0CT-93 19:09:38 Page ** TAPE TRAILER ** SERVICE NAME : FRFTB DATE : 93/09/26 ORIGIN : DLIS TAPE NAME : DEFAULT CONTINUATION #: 1 NEXT TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY TAPE SUMMARY FLEES #ER #PR 1 110 121 Reel ~railer DEFAULT ** REEL TRAILER SERVICE NAME : RFTB DATE : 93/09/26 ORIGIN : DLIS REEL NAME : DEFAULT CONTINUATION #: NEXT REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY REEL SUMMARY FILES TAPES #LR #PR 1 1 112 123 (EOF) (EOD) LU SUMMARY FILES TAPES REELS #LR #PR 14 14 14 726 893 End of Iist, ing MUBO: []LISA.DAT;