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Home My WebLink About188-086 • • Post Office Box 244027 Anchorage,AK 99524-4027 Ji Hilcorp Alaska,LLC L 3 0 2O1 i 3800 Centerpoint Drive Suite 100 AOA C Anchorage,AK 99503 SCANNED AUG2 3 2016 /1•�� Phone: 907/777-8300.-8301 f 1 G (J 9 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster �.6" Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, 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 0Orig • New API_WeilNo l PermitNumberl WellName WellNumber i 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 2-468/513 2-468 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 2-665D12 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/SD9 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/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 150029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A ;50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-178 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 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity, or are viewable by direct inspection of the file. Well History File Identifier Organization (done} RESCAN Color items: [] Grayscale items: Poor Quality Originals: [] Other: DIGITAL DATA D Diskettes, No, [3 Other, No/Type TO~A, PAGES= ~ J ~ NO, ES'. ORGANIZED BY: BEVERLY BREN VINCENT SNERYL MARIA LOWELL DATE; OVERSIZED (Scannable) E3 Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Isl Project Proofing E] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; Isl PAGES: A Iq (at the time of scanning) SCANNED BY: BEVERLY BREN VINCENT SHERYL{f~MAI~I~,'~LOWELL DATE: RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done} Rev 1NOTScanned.v,'tod oLUGG~ ~ LOC_%TIOM ~r,~:J~n'~'c,w REPORT Abn~ Da~e Well hear can off: ~'~.. .Har2~nr pos~ cr pla~a: Locamlon Clearance: Signed STATE OF ALASKA ALAb'7~"A ~iL AND GAS CONSERVATION COI~M~I'~SlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 188-086 301-004 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-02921847-00 4. Location of well at surface '~,A~i- 9. Unit or Lease Name 1944' SNL, 2240' WEL, SEC. 36, T12N, R16E V~ Duck Island Unit/Endicott At top of productive interval ~.~.~~,, ~ 2310' SNL, 1931' WEL, SEC. 36, T12N, R16E ~ ? ~~~ i. '10. Well Number At total depth 2374' SNL, 1894' WEL, SEC. 36, T12N, R16E ~'!'~:'"~-'~-: 2-28/P-19 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Endicott Field / Endicott Pool KBE - 55.00' ADL 034633 I I I 6'if offshore . 16. No. of Completions. 12' MS L Zero 12. Date07/31Spudded/1988 13. Date08/1T.4/1D. 988Reached 14. Date Comp.,2/11Susp.,/2001 or Aband. 15. Water depth, 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSV set1 21. Thickness of Permafrost 10530 10479 FTI 10448 10397 FTI [] Yes [] No I N/A MDI 1465' (Approx.) 22. Type Electric or Other Logs Run DLL / MSFL, SLD / CNL Corrected, Formation Tester, CBT, CBT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Surface 131' Drive 13-3/8" 68# NT-80 Surface 2504' 17-1/2" 3687 cuft Permafrost 9-5/8" 47# NT-S0S/NT95H Surface 9644' 12-1/4" 575 CU ft Class 'G' 7" 29# SM-110 9382' 10527' 8-1/2" 517 cuft Class 'G' 24. Perforations open to. Production (MD+TVD of Top and 25. TUBING RECORD Bottom and intervah size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 9352' (Approx.) 9339' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9675' Set Whipstock 9675' P&A w/25 Bbls Class 'G', Sqzd to 1300 psi 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I Flow 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 0 8 ZOO1 Alaska Oil & Gas Cons. Commission Form 10-407 Rev. 07-01-80 ORiGiiqAL Anchorage Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. HRZ 9387' 9342' ITK 9645' 9598' Top Kekiktuk 9680' 9632' 31. List of Attachments: Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,,~~ ~ Title TechnicalAssistant Date 2-28/P-19 188-086 301-004 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Original Well: 2-28A/P-19 Sidetrack Well: Field: Endicott Field: APl- 50-029-21847-00 APl: Perm it: 188-086 Perm it: 2-28A/O-19 Endicott 50-029-21847-01 201-018 PRE-RIG WORK FOR SIDETRACKING OPERATION 01121/01 Perform successful caliper survey of 4-1/2" tubing from 9350' wlm. 02/06/01 Run in hole with 3.720" mill and motor. Cut off tubing tail at 9329' ctd. Dress cut off. Run in hole to 9800'. Tubing gone to bottom. Pull out of hole. Freeze protect well and CT. Rig down, move off. 02/08/01 - 02/09/01 Set whipstock in 7" liner at 9675', 43 degrees left of high side looking down hole. Well left shut-in and ready for coil. 02/11/01 - 02/12/01 Move in, rig up squeeze equipment. Load well with 1% KCL. RIH w/3" cementing nozzle. Tag whipstock at 9655' ctm. Stack 5K down on whipstock; solid. Mix and lay in plug below whipstock. Pump 25 BBIs 13.8 ppg gel cement. Estimate 3 bbls cement behind pipe. Reached squeeze pressure of 1300psi and held for 30 minutes. Contaminate and circulate out cement. Bbl for Bbl returns. Freeze protect well to 1500' with diesel. BP EXPLO~TION . Operations Summary~ Legal Well Name: 2-28/O-19 Common Well Name: 2-28NO-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYEN Rig Release: Rig Name: DOYEN 15 Rig Number: · · Date From-To Hours ActivityCode NPT Phase ' :: :DeScriPtion °fOperationS 2/19/2001 00:00 - 00:00 24.00 RIGU P PRE PJSM (Rig move) - prepare for rig move - move rig to well 2-28a. 2/20/2001 00:00 - 03:00 3.00 RIGU P PRE Finishing moving rig on to 2-28NO-19 and rigged up. 03:00 - 06:00 3.00 WHSUR P PROD1 ACCEPTED RIG AT 0300 HRS 02-20-2001. Took mud into pits and continued preping rig for spud. 06:00 - 06:30 0.50 WHSUR P PROD1 PJSM-on rigging up choke line, kill line and pulling BPV. 06:30 - 09:30 3.00 VVHSUR P PROD1 Made up choke line and kill line to rig mud line system. 09:30 - 12:00 2.50 VVHSUR P PROD1 Rigged up lubricator from Drill Site Maintenance. Pulled BPV and installed TWC. Pressure test TWC to 5000 psi for 5 minutes. 12:00 - 16:00 4.00 VVHSUR P PROD1 Nipple down tree in three pieces and laid out beaver slide. 16:00 - 00:00 8.00 BOPSUIq P PROD1 Nipple up (7 1/16 x 4 1/16 xo spool - 7 1/16 5M BOPS - test spool- riser- pipe rams - mud cross - blind ram - pipe ram - annular). Attempt to hook up 4" flex steel choke hose. Vvill not make up, hose against cross beam on sub. 2/21/2001 00:00 - 03:00 3.00 BOPSUR P PROD1 Change out choke hose's from 4" steel flex to 4" rubber. 03:00 - 06:00 3.00 BOPSUR P PROD1 i lnstall bell nipple / flow line. Hook up hydralic lines to stack. Change boot in air union. Install turnbuckles on stack. 06:00 - 18:00 12.00 BOPSUR P PROD1 PJSM Testing BOPS - test blind rams, riser, test spool, XO, HCR valves - blind rams would not hold pressure - recylce rams - retest ok - Inside 2 1/16 side valve on test spool grease fitting on stem packing leaking - take off, repair, retest 300 - 5000 against TWC ok. Test Annular 300 - 3500 ok. - test upper rams, HCR valves 300 - 5000 ok. 18:00 - 22:00 4.00 BOPSUF P PROD1 PJSM Testing BOPS - Test lower ram 300 - 5000 ok - test upper ram, choke valves 12, 13, 14, 15, 300 - 5000 ok - test upper rams, choke valves 5, 6, 10, 11,300 - 5000 ok - test upper rams, choke valves 1, 4, 7, 300 - 5000 ok - test upper rams, choke valves 2, 3, 8, 9, 300 - 5000 ok - Function test hyd choke, manual chokes. - Accumulator test - Accumulator 3ressure 3000 - shut pipe rams, hcr valves, annular - accumulator pressure 1900 - accumulator pumps on 200 psi 19 seconds, full pressure 3000, 104 seconds. Nitrogen back up ~ressure's 1- 2500, 2 - 2600, 3 - 2600, 4 - 2400. avg 2525. 22:00 - 00:00 2.00 BOPSUFiN SFAL PROD1 PJSM - Nipple down bell nipple to pull TWC - Pull test plug - Rig up lubicator to pull TWC. Attempt to pull TWC can not get on check. Both o-rings off test plug. Attempt fish o-rings out no SUCCESS. 2/22/2001 00:00 - 02:00 2.00 BOPSUF:N SFAL PROD1 Attempted to fish O-rings from test plug without success. Flushed TWC with water in attempted to clear debris from top of TWC. Attempt to pull TWC with no success. 02:00 - 03:00 1.00 BOPSUF:N SFAL PROD1 Nipple down stack above adapter flange. Cleaned rubber and fine solid from top of TWC. Found ice plug above top of TWC. Thawed ice plug. Set stack back down and nippled up. 03:00 - 03:30 0.50 BOPSUF.N SFAL PROD1 Test stack against blind rams. 250 psi Iow for 5 minutes and Printed: 5F/'/2001 3:08:33 PM BP EXPLORATION ~ page2 of 13 Operations Summar Report :: : : Legal Well Name: 2-28/O-19 Common Well Name: 2-28A/O-19 Spud Date: 7/31/1988 Event Name: REENTER+COMPLETE Start: 2/19/2001 End: Contractor Name: DOYEN Rig Release: Rig Name: DOYEN 15 Rig Number: Date From- To Hours ActivityCode UPI Phase :~ :,DeScriPtion of OPerati°ns 2/22/2001 03:00 - 03:30 0.50 BOPSUF N SFAL PROD1 5000 psi high for 10 minutes. 03:30 - 04:00 0.50 BOPSUF P PROD1 Pulled TWC with lubricator. Laid down TWC and lubricator. 04:00 - 08:00 4.00 BOPSUF',P PROD1 Finished testing IBOP, upper IBOP, and floor valves 250 psi Iow for 5 minutes and 5000 psi high for 10 minutes. Nippled up -- bell nipple and flow line. 08:00 - 00:00 16.00 STWHIP 'P PROD1 PJSM - Picking up dp - m/u milling assembly - pick up 2 3/8 dp rih - tag top whipstock at 9675' set 5k down twice to confirm tag up. 305 joints plus 1 .~' in on joint # 306. 2/23/2001 00:00 - 01:00 1.00 STWHIP P PROD1 Displaced hole with 9.3 # Quikdrill-N mud @ 60 spin @ 2400 psi. Had lots of air from fill on trip in hole. 01:00 - 01:30 0.50 STWHIP P PROD1 Continued circulating until the air was circulated out of the system. 01:30 - 02:00 0.50 S'I'WHIP P PROD1 Dropped steel ball to close PBL sub. Did not see shear out when ball hit. Ran in hole and tagged up on whipstock. Pump pressure increased 100 psi indicating sleeve on PBL closed. 02:00 - 03:30 1.50 STWHIP P PROD1 Worked on #1 pump -Lost prime. Recorded SPRs on both pumps. 03:30 - 10:30 7.00 STWHIP P PROD1 Milled from 9675'-9687'. Top of window 9675' Bottom of window at 9682'. Milled 5' of open hole below bottom of window. Shut down and picked up a single. Milled formation from 9687'-9689' and gas began breaking out at surface. Shut down pump and shut in well. Recorded 8 bbl pit gain. Recorded 375 psi drill pipe pressure and 400 psi casing pressure. 10:30 - 14:30 4.00 STWHIP N DPRB PROD1 Start circulating with drillers method holding 1700 psi on drill pipe (1200 spr @30 spm plus 375 psi shut in drill pipe pressure plus 125 psi safety margin). Casing pressure approximately 500 psi. Circulated 288 strokes (13 bbls) with no returns. Shut down pump and shut in well to confirm pressures. Opened choke bleed pressure to confirm and insure correct drill pipe and casing pressure. SIDPP 325 psi SICP 250 psi. Restarted circulation using driller method holding 1700 psi drill pressue. Pumped and additional 219 stroke for a total of 507 strokes (22.8 bbls) before gaining returns. Pumped a total of 2600 strokes (117 bbls-annular volume 101 bbls). Final circulating pressure 1700 psi on drill pipe and 225 psi on casing. Shut well in. Bled off excess pressure on drill pipe through fill up line. Opened float with float to confirm drill pipe pressure. Shut in drill pipe pressure 340 psi. 14:30 - 00:00 9.50 STWHIP N DPRB PROD1 Circulating drillers method while waiting on kill mud to maintain bottom hole pressure and prevent freeze up of mud. 2/24/2001 00:00 - 00:30 0.50 STWHIP N DPRB PROD1 Continued circulating drilers method while waiting on kill mud to maintain bottom hole pressure and prevent freeze up of mud. 00:30 - 01:00 0.50 STWHIP N DPRB PROD1 Held PJSM on well kill operation. Discussed job assignments Printed: 5/7/2001 3:08:33 PM STATE'OF ALASKA ALASK~'"'OIL AND GAS CONSERVATION COMI~-tl-SSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack . Name of Operator BP Exploration (Alaska)Inc. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface v/ ,/ ,/ 1944' SNL, 2240' WEL, SEC. 36, T12N, R16E At top of productive interval 2310' SNL, 1931' WEL, SEC. 36, T12N, R16E At effective depth 2370' SNL, 1897' WEL, SEC. 36, T12N, R16E At total depth 2374' SNL, 1894' WEL, SEC. 36, T12N, R16E 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service RECEIVED JAN J- 0 Z001 Alaska Oil & Gas Cons. Commission Anchorage 6. Datum Elevation (DF or KB) KBE = 55.00' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number ~,.~ 2-28/P-19 9. Permit Number 188-086 v" 10. APl Number 50- 02921847-00 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured Effective depth: Casing 10530 feet v/' 10479 feet ~' Plugs (measured) true vertical measured 10448 feet Junk (measured) 3 Bowspring Leafs at 10448' MD true vertical 10397 feet Length Size Cemented MD Structural Conductor 92' 30" Driven 131' Surface 2465' 13-3/8" 3687 cu. ft. Permafrost 2504' Intermediate Production 9605' 9-5/8" 575 cu. ft. Class 'G' 9644' Liner 1144' 7" 517 cu. ft. Class 'G' 9383' - 10527' TVD 131' 2503' 9597' 9338'-10476' Perforation depth: measured open: 10140'- 10160'; 10186'- 10212' sqzd: 10002'- 10016'; 10030'- 10034'; 10114'- 10140'; 10180'- 10186'; 10212'- 10246' true vertical open: 10090' - 10110'; 10136' - 10162' sqzd: 9923' - 9967'; 9980' - 9984'; 10064' - 10090'; 10130' - 10136'; 10162' - 10196' Tubing (size, grade, and measured depth) 4-1/2" 12.6#, L-80 tubing with 3-1/2" 9.2# L-80 tailpipe to 9452'. Packers and SSSV (type and measured depth) 9-5/8" SAB Packer at 9339', 4-1/2 SSSV at 1555' 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 14. Estimated date for commencing operation January 25, 2001 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Name of approver Date Approved Contact Engineer Name/Number: Jeff Hupp, 564-5344 Prepared By Name/Number: Sondra Stewman, 564-4750 17. I hereby certify that t/I,l,l,~ foreg,oi~g)s true and correct to the best of my knowledge /,~"'~ ~?'~, Title Senior Drilling Engineer Signed Jeff .upp (,~ - //,~' : .i c0m~issi0n:u~e.:0~Iy Conditions of Approval: Notify Commission ~'o"representative may witness Plug integrity __ BOP Test ~(, Location clearance Mechanical Integrity Test __ Subsequent form required 10- .)I-(iGINAL SIGNED BY Approved by order of the Commission "'~ T~vloF Form 10-403 Rev. 06/15/88 L Approval No. ,~O t ~ OD L'L Commissioner Date Ol Submit In/l'ril~lic'a(e ,/ RECEIVED JAN BP ALASKA DRII. GNG &WELLS Alaska Oil & Gas Cons. Commission Anchorage Date: January 10, 2001 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Blair Wondzell Sr. Petroleum Engineer Re'. Endicott Well MPI 2-28/P-19 Prep for Rig Sidetrack Well 2-28/P-19 is scheduled as a through tubing sidetrack with Doyon Rig 15. The following summarizes the procedure required to prep the 2-28/P-19 well for sidetracking and is submitted as an attachment to Form 10-403. A schematic diagram of this proposed completion is attached. Pre-Rig Summary for the MPI 2-28/P-19 TTRD Sidetrack 1. Test IA & OA packoffs. 2. Install DGLVs. Fluid pack IA. MITIA to 2500 psi 3. Drift tbg with 3.80" OD drift to 7"x 3-1/2" Crossover (Btm of Millout Extension) 4. RU CTU. Mill off 2-7/8" tail pipe below existing prod. Packer 5. Drift tbg with 3.625" OD dummy whipstock assy. 6. Run Kinley caliper on tbg and 7" liner. 7. Set Baker Whipstock in 7", 26# liner at 9650' MD (7° inclination) 8. Pump approx. 22 bbls of cement past whipstock for abandonment 9. Freeze protect top 1500' w/diesel. RD MO CTU. 10. Set BPV and prepare for rig move. 2-28/P-19 well data Last test: Latest H2S value: 713BOPD, 777 BWPD, 20 MMSCFPD (28,200 GOR, 52% WC) 56 ppm (10/16/00) The Pre-rig operations are expected to start 1/25/01 and the rig sidetracking operations are planned to start 2/15/01. ' Senior Drilling Engineer cc' 2-28A/O-19 Well File Petrotechnical Data Center RT. ELEV = 55.0' BF. ELEV = 15.8' MAX. DEV. = 13:33 8000' MD 13-3/8", 68#/ft, NT-80 CYHE, BTRS. CSG. 9-5/8", 47#/ft, I NT80S XOTO I 8348' NT95HS TOP OF 9383' J I 7" LINER 9-5/8", 47#/ft, J 9644, J~ NT95HS, PERFORATION SUMMARY REF: LOG: DLL-GR (08-13-88) SIZEI SPFI INTERVAL 2.1/81 4 I 10114'-10160' 2-1/81 6 I 10145'-10157' 2-1/81 4 I 10180'-10200' ~11//~] ~ I10188''10213' 10216' - 10246' PBTD I 10,448' 7"- 29 #/ft, SM-110,I 10,527' BTRS-TKC DATE REV. BY JLH 5/95 5/1/95 JTP ADD PERFS 4/26/96 JA ADD PERFS 5/11/96 JA ADD PERFS COMMENTS SQUEEZE & RE-PERF TREE: 4-1/16" / 5000 psi,. ,'VOY WELLHEAD: 13-5/8" / 5000 p~""/"McEVOY SSSV LANDING NIPPLE I 1555' I OTIS (3.813" MIN. ID) W/SSSV MIN I.D. 2" 4-1/2", 12.6#/ft, L-80, BTRS NB Mod. TUBING GAS LIFT MANDRELS (MERLA) NO. TVDSS MD-BRT #6 I 4148' #5 6337' #4 7776' #3 8688' #2 8911' #1 9057' 4204' 6393' 7845' 8780' 9007' 9155' SLIDING SLEEVE I 9265 CAMCO BAKER "SBR" (12' I 9324, Innn~ 9-5/8" I 9339' PACKER 3-1/2", 9.2#/ft, L-80 TAILPIPE 3-1/2 .... X" NIPPLE I 9386' I (OTIS) (2.750" lq), ,_~ 19419'1 fOTIS) ,2.635" ID) 3-1/2" 9452' I WLEG ELMD I 9458' R Ai~ka' 3 BOWSPRING LEAFS ENDICOTT WELL 2-28/P-19 APl NO: 50-029-21847 COMPLETION DIAGRAM BP EXPLORATION, INC. ECEiVED JAN i 0 2001 ~il & Gas Cons. Commission Anchorage RT. ELEV: 55.0' BF. ELEV =15.8' MAX. DEV. = 13:33 8000' MD 13-3/8", 68~ft, NT-80 CYHE, BTRS. CSG. 9-5/8", 47#/ft, I NT80S XOTO I 8348' NT95HS TOP OF LINER 9383' 9-5/8", 47#/ft, i 9644, I ~ NT95HS, PERFORATION SUMMARY REF: LOG: DLL-GR (08-13-88) ISiZE I SPF J INTERVAL 2-1/81 4 I 10114'-10160' 2-1/8] 6I 101 5'-10157' 2-1/81 4 I 10180'-10200' 10216'- 10246' STATUS I SQZD I OPEN I SQZD I I OPEN J OPEN I PBTD I 10,448' 7"- 29 #/~t, SM-110,I 10,527' BTRS-TKG DATE 1/9/01 REV. BY COMMENTS JLH 'rop. Pre-rig Schematic TREE: 4-1/16"/5000"'~ McEVOY WELLHEAD: 13-5/8"/5000 psi/McEVOY I SSSV LANDING NIPPLE I 1555' I OTIS (3.813" MIN. ID) W/SSSV MIN I.D. 2" 4-1/2", 12.6#/ft, L-80, BTRS NB Mod. TUBING GAS LIFT MANDRELS (MERLA) NO. TVDSS MD-BRT #6 I 4148' #5 6337' #4 7776' #3 8688' #2 8911' #1 9057' 4204' 6393' 7845' 8780' 9007' 9155' SLIDING SLEEVE CAMCO I 9265 (3.750" MIN. ID) BAKER "SBR" (12' long) I 9324' 9-5/8" PACKER I 9339' (BAKER "SAR") 3-1/2", 9.2#/ft, L-80 TAILPIPE cut and dropped to PBTD Baker Thru-Tbg whipstock set @ 9675' IExisting perforations plugged with 22 bbls of cmt RECE 3 BOWSPRING LEAFS JAN 1 Alaska 0il & Gas C( Anchor, ENDICOTT WELL 2-28/P-19 APl NO: 50-029-21847 PROPOSED PRE-RIG DIAGRAM BP EXPLORATION, INC. VEE) ~s. Commission STATE OP ALAt~KA ALAS~-~ OIL AND GAS CONSERVATION GOMMIS?'~N REPORT L,,': SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate.__ Plugging__ Pull tubing Alter casing Repair well Perforate x Other X 2. Name of Operator BP Exploration (Alaska) Inc. 31 Address P. O. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 1944' SNL, 2240' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 55 feet Unit or Property name Duck Island Unit/Endicott 8. Well number 2-28/P- 19 MPI At top of productive interval 9. Permit number/approval number 2310' SNL, 1930' WEL, Sec. 36, T12N, R16E At effective depth 2370' SNL, 1897' WEL, Sec. 36, T12N, R16E At total depth 2375' SNL, 1895' WEL, Sec. 36, T12N, R16E 02 2000 Oil & Gas Cons. Commission Anchorage 88-86/not reauired 10. APl number 50- O29-21847 11. Field/Pool Endicott Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10530 feet 10479 BKB feet 10448 feet 10397 BKB feet Plugs (measured) Junk (measured) 3 bowspring leafs in the bottom of the weft Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2465' 13 3/8" 3687 c.f. Permafrost 2504' 2503' 9605' 9 5/8" 575 c.f. Class G 9644' 9597' 1144' 7" 517c. f. Class G 9383'- 10527' 9338'- 10476' measured 10140'- 10160'; 10186'-10212' (allopen) 10002'-10016'; 10030'-10034'; 10114'- 10160'; 10145'-10155', 10152'-10157', 10180'-10200', 10188'-10213', 10196'-10206', 10216'-10246' (all squeezed) true vertical (Subsea) 10035'-10055'; 10081'-10107' (all open) 10009'-10055'; 10040'-10050', 10047'-10052', 9898'- 9912';9925'- 9929'; 10075'-10094'; 10083'-10108', 10091'-10101', 10111:10141' (all squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" 9.2# L-80 taflpipe to 9452' Packers and SSSV (type and measured depth) 9 5/8" SAB Packer at 9339', 4 1/2" SSSV at 1555' 13. Stimulation or cement squeeze summary wSO/GSO squeeze 4/6/00; reprforate 4/14/00 Intervals treated (measured) ¢O002'-¢O¢86'(squeezed); 10140'-10160'(perforate) Treatment description including volumes used and final pressure see Attached ORIGINAL 14. Prior to well operation Subsequent to operation Representative Dailv Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 773 11535 7723 0 586 9229 956 0 Tubing Pressure 1542 434 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations × 16. Status of well classification as: Oil x Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~.~~% ,. k- i'~--~-- ) L~~'~ TitleT~chnic~lA.~.qi.~t~ntlVL~zl-.5234) Form 10-404 Rev 06/15/~1~ ~j Date 5/2/00 SUBMIT IN DUPLICATE To: From: Operation: Cost Code: Detail Code: Anchorage Product,_ -'ngineering Nordlander/Dube End 2-28 Squeeze N10228 - etc Nrwo - Squeeze - etc ,. ,ation: Endicott Date: 4~6/00 Pre-Job Costs: $3,300 This Job Costs: $54,021 Post-Job Total: $57,321 Summary Killed well with 355 bbls seawater while rih. Continued sump kool down with seawater. Dry tagged td and corrected -13 ft to 10294. Flagged pipe at 10274 and at 10210. Pre injection test was 1.0 at 320 whp. Jetted 50 bbls acid over perfs. Post injection was 2.0 at 790 psi. Whp continued to rise which lead to believe gas was in well bore, however, spot checks indicated all liquid returns. Laid in 21 bbls cement from 10274 when gas finally surfaced. Had to lay in blind with estimated wctoc at 9713. Pu to safety and began circulating out gas while applying HK squeeze. At shutdowns the squeeze looked good so continued gradual squeeze while circulating out gas. With gas finally displaced, walked squeeze up to 3000 psi and held for 15 mins; lost 70 psi a good squeeze. Dropped ball and jetted with biozan; hit a small aspiring bridge at 9780 but was able to punch through. Cleaned out to 10210 and spotted tea over squeeze perfs and chased solids to surface at 80% while jetting the jewelry. Freeze protected well to 1500 feet with meoh. Left 1000 psi on well. 4~6~00 Initial Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F Shutin 2640 350 0 2200 300 40 Time Operation 7:00 Miru DS #2, 15,280 of 1-3/4" (ctv 33.8 bbls). 9:30 Fill coil. 9:39 Wait on meoh. 10:20 Pressure test. 10:28 Load meoh to squeeze unit and recover from coil. 11:24 Line up to kill well. Time Depth Rate Ctp Whp Stage Out Rtn Remarks ft bpm psi psi bbls Nzl bbls 11:27 surf 2650 2640 32 - Start killing well. 11:57 5.0 700 700 160 Rih. 12:29 3650 600 600 307 Start down coil. 13:23 10225 1.0 1000 320 355 Shut down to tag. 13:26 10294 200 320 Tag td @ 10307, correct -13 feet. 13:33 10274 180 350 Flag pipe. 13:39 10210 1.2 1280 400 Flag pipe. 13:45 9700 Kool sump. 13:50 Cement to weight. 14:06 Hold safety meeting. 14:38 1140 450 428 Open chokes to circulate out any gas. 14:42 400 433/s Freeze protect coil pump. Pressure test cementers. 14:49 Start acid down coil. Rih. IVED tvlAY 02 2000 ~a~ka ~t & Gas Cons. Antoine Operation: End 2-28 Squeeze Page: 2 15:12 10210 0.7 3720 510 25 Park coil. 15:25 3790 560 33 0 Acid to nozzle, iet up. 15:41 10000 3810 600 44 11 Jet down. 15:50 10188 3650 630 50/a 17 Switch to seawater. 15:52 10210 3630 640 1 18 Jet up. 16:15 10000 1.7 3700 750 23 40 Jet down. 16:19 10210 2.7 3200 800 33 50/ Seawater to nozzle. Jet up. 16:22 10118 3080 810 41 Switch to fresh water. Red rate. 16:25 9900 2.0 2100 790 45/s Switch to cement. Open chokes to check for liquid or gas ..... liquids. 16:31 10274 1.6 3610 810 11 Jet up. 16:36 10110 3700 880 21/c Switch to freshwater, rih. 16:43 10274 1.8 2960 1100 10 Red rate. 16:45 1.0 420 1150 13 0 Cement at nozzle. Gas returns. Keep chokes open, but not to exceed down stream pop off pressure. 16:46 400 1280 14 1 16:47 400 1280 15 2 16:48 10260 380 1290 16 3 16:49 10239 370 1310 17 4 16:50 10223 360 1320 18 5 16:51 10201 360 1360 19 6 16:52 10173 350 1380 20 7 16:53 10151 340 1400 21 8 16:54 10133 330 1400 22 9 Liquid returns. 16:55 10093 320 1440 23 10 Close chokes to start gauging tanks. 16:56 10047 310 1510 25 12 16:57 10012 300 1540 26 13 Crack chokes. 16:58 9990 300 1560 27 14 0 Too much gas, ship to green tank. 17:59 9955 300 1570 28 15 17:00 9938 550 1580 29 16 17:01 9913 630 1580 30 17 17:02 9873 730 1570 31 18 17:03 9801 810 1570 32 19 17:05 9757 930 1580 33 20 17:05 9713 900 1580 34 21/c Puh to safety, increase rate. 17:07 9500 1.5 1430 1560 37 Park circulate out gas, switch to coil pump. 17:18 1480 1620 48 Increase rate. 17:22 2.0 2480 1800 57 17:26 2700 1960 65 Shut down and monitor. 17:34 0 700 1960 Continue circulating out gas. 17:42 1.8 3260 2530 85 17:51 1.5 2930 2960 98 17:58 1.0 3100 3050 104 Shutdown and monitor. 18:00 0 2570 3100 Start bleeding gas again while adding water. 18:17 0.5 2820 2880 111 Send gas down flowline. 18:30 0 1980 2100 132 18:43 1.8 3200 1570 158 Shut down. 18:44 0 1780 1780 Walk up. 18:47 0.5 3100 3000 159/s Shut down and monitor. MAY 02 2000 Anchorage 'Operation: End 2-28 Squeeze Page: 3 19:03 0 2900 2930 Good squeeze, line up drop ball, bleed pressure down. 19:15 0 1500 1500 Start biozan down coil. 19:30 9650 2.0 3700 1180 30/b Ball hit, switch to seawater. 19:33 9726 3680 1090 4 Jet down. 19:38 9890 3200 1060 14 Tag, try jetting down. Bump through. 19:49 10210 1.7 2775 980 35 Jet up. 20:07 9710 2.2 3650 1200 68 Park and clean rock filters. 20:14 Continue with cleanout. 20:15 9780 2.1 72/s Switch to tea. 20:20 10004 1.6 3130 1220 9/t Switch to seawater. 20:30 10210 1.7 2870 970 17 Switch to green tank, jet up. 20:36 10210 2950 1060 25 Lay in tea. 20:41 9985 2920 1130 34 Jet ooh. 20:48 9670 2.4 3890 1080 51 Cement to surface. 20:53 9470 61 Jet jewelry really nice and good. 22:14 3080 2.5 3680 1030 256/s Switch to meoh. 22:32 1500 1.6 3900 1030 34 22:48 surf 1.5 3800 1030 61/m Start rig down. 4/7/00 I 1:001 I i I I I I I off location. I Final Well Status Whp lap 0ap GIp FIp Fit psi psi psi psi psi °F Shutin 1000 400 0 2200 300 40 Fluid Summary 965 Seawater & Seawater w/friction reducer. 50 Acid. 21 Cement. 30 Biozan. 9 Tea. 63 Meoh. 1138 Total Squeeze Nozzle Bottom Hole Assembly # 1 Tool String Descriptions O.D. I.D. Length Comments DS ct connector. 2.00 1,00 12 DS straight bar 2.00 69 Squeeze nozzle 2.50 7 Jet swirl with nifty ball drop feature, Total Length 88 MAY 02 2000 ~d~or~e 'Operation: End 2-28 Squeeze Page: 4 DS Cement Summary 15.8 PPG Class G Latex Cement containing: 0.10 gps D047 0.70 % BWOC D800 1.00 % BWOC D020 0.30 % BWOC U117 0.10 %BWOC D135 1.25 gps D600 0.30 % BWOC D065 0.02 % BWOC C359 Thickening Time = 5 hrs and 52 mins. Lab APl fluid Loss = 66 mi @ 170 o F. Requested 50-70 mi., 60 cc target Requested 5-7 hours Field test 69 mi, 0.81 in. DS Acid Summary 10% HCI/10% Xylene containing: Hydrochloric Acid H-36 10.0 % Ammonium Fluoride B-55 0.0 % Acetic Acid L-401 0.0 % Xylene A-26 10.0 % Dispersant U-74 1.5 % Corr Inhibitor A261 0.6 % Inhibitor Aid A-153 8.0 ppt Inhibitor Aid A-179 4.0 ppt Non Emulsifier W-54 0.5 % Anti-Sludge W-35 0.5 % Surfactant F-75N 0.2 % H2S Scavenger A-255 0.5 % Iron Stabilizer L-58 20.0 ppt Water H20 Water Bath Temp 170 °F Initial emulsion volume (mi) Acid phase vol. @ 15 min. (mi) Acid phase vol. @ 30 min. (mi) Acid phase vol. @ 45 min. (mi) 3-1; Wt. Nat. Res/Paper: 3-2; Wt. Filter Paper: 3-3; Wt. Nat. Residue: 3-4; Wt Nat. Res/Sludge/Paper 3-5; Wt. Filter Paper 3-6; Wt. Nat. Res/Sludge: Sludge = 75 A: Live 25 Oil Spent gram gram gram gram gram gram gram 50A: 50 Oil 25A: 75 Oil Live Spent Live Spent 'To: Endicott Producti~ ;ngineer L .~tion: Endicott From: D. Kim 14-Apr-O0 Well: 2-28 Cost Code: N10228-120 Operation: E-line Perf Detail Code: Pert Summary Miru SWS Unit #2150. Well currently S/I. RIH. Tie-in log: Cement Evaluation Log (17-Aug-88). Perforate 10140' - 10160' with 2" PowerJet 6 SPF, 60° phase. POOH. RDMO. Contact PC and Pad Operator to POP well. Well Note: Fluid level = 6,700' md. WHP = 2,100 psi. 1500' diesel for freeze protect. Total BHP at 10,140' = 4,180 psi. Formations Pressure = 4,700 psi Well underbalance by 517 psi. Estimated Total Cost: $12.4k Initial Well Status Siwhp psi lap psi S/I I 2100 2100 0 0ap I GIp psi psi I n/a psi °F I 7:45 Miru SWS Unit #2150. 8:45 Safety meeting. 9:15 Pressure test. 9:30 RIH. TimeI Operation 10:18 Make initial tie-in. 10:29 Pull up to shoot depth, 10133.2' (CCL 6.83' from top shot). WHP = 2,100 psi. 10:32 Fire gun. Perforate 10140' - 10160', with 2" PowerJet 6 SPF, 60° phase. WHP = 2,100 psi. No noticeable change in well condition. 10:41 POOH. 11:15 verified all shots were fired. 12:30 Contact PC and Pad Operator to POP well. MO. Final Well Status S/I 2100 Siwhp I lap I Oap psi psi psi I 2100 I o G Ip I FIp JJ Fit II psi psi °F I I - I SWS Perforating Assembly Bottom Hole Assembly # 1 Tool Strin9 Descriptions O,D. I,O, Length MH-22 1 3/8 1.5 Head AH-38 1 11/16 6.3 Cross Over PGGT-CC 1 11/16 6.4 GR/CCL AH-TOOL SAVER 1 11/16 1.5 1 11/16 2.0 AH-SAFE SHM_GUN 1.5 22.5 Comments Safe adapter 2" PowerJet 6 SPF, 600 phase, 20" gun. 000414 2-28 Eline Add Perf.doc Page 1 of 2 'Well: 2-28 Operation: Eline Perf Total Len~lth I 29.8 Maximum Tool String OD = 2.0 in MAY 02 2_000 And~orag. 000414 2-28 Eline Add Perf. doc Page 2 of 2 ~--~- STATE OF ALASKA ALA~ .~)IL AND GAS CONSERVATION COMMIS',., ~ ,I REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate Plugging__ Pull tubing__ Alter casing __ Repair well__ Perforate x Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at surface 1944' SNL, 2240' WEL, Sec. 36, T12N, R 16E 5. Type of Well: Development ._ Exploratory __ Stratigraphic Service __ 6. Datum elevation (DF or KB) KBE = 55 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-28/P- 19 MPI At top of productive interval 2310' SNL, 1930' WEL, Sec. 36, T12N, R16E At effective depth 2370' SNL, 1897' WEL, Sec. 36, T12N, R16E At total depth 2375' SNL, 1895' WEL, Sec. 36, T12N, R16E 9. Permit number/approval number 88-86/not rec/uired 10. APl number 50- 029-21847 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing · Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 10530 feet 10479 BKB feet 10448 feet 10397 BKB feet Size Plugs (measured) Junk (measured) . 3 bowspring leafs in the bottom of the well Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2465' 13 3/8" 3687 c.f. Permafrost 2504' 2503' 9605' 9 5/8" 575 c.f. Class G 9644' 9597' 1144' 7" 517c. f. Class G 9383'- 10527' 9338'- 10476' measured 10002'-10016'; 10030'-10034'; 10140'.- 10160'; 10186'-10212' (allopen) 10114'- 10160'; 10145'-10155', 10152'-10157', 10180'-10200', 10188'-10213', 10196'-10206', 10216'-10246'(all squeezed) true vertical (Subsea) 9898'- 9912'; 9925'- 9929'; 10035'-10055'; 10081'-10107' (all open) 10009'- 10055'; 10040'-10050', 10047'-10052', 10075'-10094'; 10083'-10108', 10091'-10101', 10111'-10141' (all squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" 9.2# L-80 tailpipe to 9452' Packers and SSSV (type and measured depth) 9 5/8" SAB Packer at 9339', 4 1/2" SSSV at 1555' RECE!VE 13. Stimulation or cement squeeze summary Add Perforations 6/11/98 Intervals treated (measured) 10002'-100~6'; ~0030'-10034' Treatment description including volumes used and final pressure see Attached C0mmi~J01~ Anchorao¢. I Representative Daily Average Production or Injection Data ~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure I Prior to well operation 391 469 7935 0 347 Ii ate 7/8/98 ~ 0 1257 Service Date SUBMIT IN DUPLICATE 14. Subsequent to operation 1199 15551 9699 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations × Oil × Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ (~2~~ TitleTechnic~lA.~.~i~t~ntlV Form 10-404 Rev 0~t15/88 ENDICOTT, ALASKA TO: Endicott Prod. Engr. FROM: L. Phong Well Name: 12-281P-19 Main Category: ICS Sub Category: Add Perfs Operation Date: [6111198 Date: 16/11/98 Job ID# N/A Cost Code: N15228- 120 Objective: To Perforate from 10,002' to 10,016', and 10,030' to 10,034'. OPERATIONS SUMMARY: Rigged up SWS. RIH, Tie In. Successfully Shot Perforations from 10,002' to 10,016', and 10,030' to 10,034'; 2 1/8" Enerjets at 6SPF, 90 Degrees Phased Orientation. ~ Initial WellI FWHP SIWHP lAP OAP WHT Status (psi) (psi) (psi) (psi) (° F) II NCA 1400 0 140 TIME OPERATION 1025 MIRU SWS #3441. Inform Well Tender and Control Room of work. 1120 Safety/Spill Meeting. Appoint Mike as Spill Champion. 1140 Call for Radio Silence. Arm Guns. 1210 RIH with 4' Gun. Call Endicott Radio to Confirm Radio Silence. Call Well Tender to SI Well. 1230 GR and CCL Powered Up. Well Tender SI Well. 1305 Log Tie In Pass while RIH w/CCL log 9/27/88, Confirm and Correllate final Tie In with DLL-MSFL 8/13/88. SIWHP @ 780#. 1340 Log Up. Confirm On Depth. Shoot 10,030' to 10,034' with 2 1/8" Enerjets at 6SPF, 90 Degrees Phased Orientation. Positive Confirmation of Shots off, Lost 40#, and SIWHP inc to 850#. Log Up 3 Collars. With the possibility of this zone being Gas Saturated, the well was Shot Shut In and Underbalanced to reduce the risk of the gun being blown uphole and getting stuck, and also to allow the large amount of debris created by Enerjets to fall into the rathole. 1355 POOH 1435 OOH. Inspect Guns, All Shots Off. 1520 Arm 14' Gun. 1545 RIH with 14' Gun. GR and CCL Powered Up. 1620 Log Tie In Pass while RIH w/CCL log 9127188, Confirm and Correllate final Tie In with DLL-MSFL 8/13/88. SIWHP @ 960#. 1655 Log Up. Confirm On Depth. Shoot 10,002' to 10,016' with 2 1/8" Enerjets at 6SPF, 90 Degrees Phased Orientation. Positive Confirmation of Shots off, Lost 50#, and SIWHP inc to approximately 990#. Log Up 3 Collars. With the possibility of this zone being Gas Saturated, the well was Shot Shut In and Underbalanced to reduce the risk of the gun being blown uphole and getting stuck, and also to allow the large amount of debris created by Enerjets to fall into the rathole. 1740 POOH. "1810 OOH. Inspect Guns, All Shots Off. Release Radio Silence. RD. Inspect Site. SIWHP @ 1100#. 1825 Inform Well Tender and Control Room of Job Completion and Well Status (Well left shut in to be PoPed by Well Tender). 1840 Well Tender PoPed Well. MO. STATE OF ALASKA ALAS ',)IL AND GAS CONSERVATION COMMISSI' REPORT Or: SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate × Plugging Pull tubing Alter casing Repair well Perforate x Other × 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 1944' SNL, 2240' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development .. Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55 feet 7. Unit or Property name Duck/s/and Unit/Endicott 8. Well number 2-28/P- 19 MPI At top of productive interval 2310' SNL, 1930' WEL, Sec. 36, T12N, R16E At effective depth 2370' SNL, 1897' WEL, Sec. 36, T12N, R16E At total depth 2375' SNL, 1895' WEL, Sec. 36, T12N, R16E 9. Permit number/approval number 88-86/not required 10. APl number 50- 029-21847 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 10530 feet 10479 BKB feet Plugs (measured) Effective depth: measured true vertical 10448 feet 10397 BKB feet Junk (measured) 3 bowspring leafs in the bottom of the well Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2465' 13 3/8" 3687 c.f. Permafrost 2504' 2503' 9605' 9 5/8" 575 c.f. Class G 9644' 9597' 1144' 7" 517c. f. Class G 9383'- 10527' 9338'- 10476' measured 10140'- 10160'; 10186'-10212' (allopen) 10114'- 10160'; 10145'-10155', 10152'-10157', 10180'- 10200', 10188'-10213', 10196'-10206', 10216'-10246'(all squeezed) true vertical (Subsea) 10035'-10055'; 10081'- 10107' (all open) 10009'- 10055'; 10040'- 10050', 10047'- 10052', Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" 9.2# L-80 tailpipe to 94 ..... Packers and SSSV (~pe and measured depth) 9 5/8" SAB Packer at 9339', 4 1/2" SSSV at 1555' 13. Stimulation or cement squeeze summa~ water Shut off ~15~5~7, Ce~nt Squeeze 5/26~7, Water Shut off ~ 6/1~7, Add Inte~als treated (measured) ~0~40'- 10160'; 10186'-10212'; 10114'- 10160'; 10145'.10155', 10152'-10157', I0180'- 10200', 10188s10213', 10196'-10206', 10216'-10246' Treatment description including volumes used and final pressure SeeA.ached 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 676 44 6086 0 307 Subsequent to operation 1746 11365 5239 0 1129 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereJ3y-ee.rtify that the foreg.oiog is true and~orrect to the best of my knowledge. g ', .... -"¢ ~ ..... _- c,", , ~ .,~ ,, ........ <...¢. Titlesenior TachnEalAssistant IV Form 10-404 Rev,/06/15/88 ~,/ Date 7/16/97 SUBMIT IN DUPLICATE Endicott Produotion Engi,,_..ring Endicott 2-28 From: Operation: Bardwell 2-28/~dd perfs Date: 6/6-7/97 Cost Code: N10228-120 DetailCode: Post Squeeze Initial Well Status SIWHP lap 0ap GIp FIp Fit (shut-in) (psi) (psi) (psi) (psi) (psi) (°F) 650 psi 1000 0 1000 NA 20 rime Operation 6~6~97 0930 Well shut-in. MIRU SWS #3441. Begin MU SOS 2-1/8" EJ III HMX guns at 6 spf, 90° phasing orientation. (Note: GR not working, so will tie-in to collars with CCL.) 1000 Pre-job safety meeting. Call for radio silence. Arm guns 1200 RIH to 10100'. Attempting to tie-in. 1255 Unable to get good collars for tie-in. Gun gamma ray tool not available- will be flown from across river. POOH. Confirm radio silence. 1315 RD, secure well. Wait on tool. 1815 SWS on location. Rig up. 1850 Pre-job safety meeting. Call for radio silence. Arm gun. 1905 RIH with gun #1. 2005 Log tie-in pass from 10285'-10000'. GR counts very high due to scale thru interval to be shot 2030 Log repeat tie-in pass. Still no good for tie-in. 2045 Log up thru tubing tail to 9190'. Tie into CCL log dated 9/27/88 - correct 4' too deep.' 2016 Log confirmation tie-in pass from 10285' 2200 Confirm on depth. Open up well. PU - to shooting depth- CCL at 10190.5 elmd. 2210 Shoot perfs from 10212-10196 elmd with well open (150 psi WHP - pressure dropped to 0). Appears guns fired. 2220 Shut in well. POOH. 2250 OOH. Guns fired. Lift radio silence. 2330 RD BOP. Secure well for night. Flowing and on gas lift. 6-7-97 0715 SWS on location. Rig up. (Note: Well has been f/owing with GL. FWHP: 550 psi, Temp: 80°, IA: ) 0815 Pre-job safety meeting. Call for radio silence. Arm gun. Shut in well and gas lift. 0845 RIH with gun #2. 0930 Log tie-in pass from 10250'-9300'. 0950 Open up well - SIWIHP: 1100 psig, FWHP: 400 psig, Confirm tie-in. 0955 PU to shooting depth: CCL at 180.5 elmd. 1000 Shoot perfs from 10196'-10186' elmd with well open. Appears guns fired. 1005 Shut in well. Log off and POOH. 1030 OOH. Guns fired. LD gun #2 and MU gun #3. 1130 PU and RIH with gun #3. 1215 At 10000'. Open up well - SIWHP: 1200 psig, FWHP: 350 psig, 1230 Log tie in pass from 10275-10000'. 1235 PU to shooting depth: CCL at 1034.5' elmd 1240 Shoot perfs from 10160'-10140' elmd. 1245 Shut in well. Log off and POOH. Lift radio silence. 1320 OOH. SIWHP: 1600 psig. 1335 Open up well. Choke set at 74. Gas lift not on. 1350 Secure well. RD tools. 1415 SWS move off 2-28. Operation: Endicott 2-28 Add perf Summary Shot perfs with 2-1/8" EJ III, HMX 6 spf 90° phasing orientation in three runs at the following depths: · #1: 10212'-10196elmd. · #2: 10196'-10186' elmd. · #3: 10160'-10140' elmd. All logs tied into Jewelry log 9/27/88 which was cross referenced back to open hole log. No fluids pumped. Page: 2 WSA- Well Operations Telex To: Anchorage Engineering From: Powers Operation: 2-28/1>-19 WSO#2 Date: 6/1/97 Circulated well dead and cooled sump with 482 bbls of FSW. Layed in 10 bbls of 15%hcl/10%xylene acid from 10200-10250'. Saw about a 1000 psig injectivity improvement. Final injectivity was 1 BPM at 940 psig. Mixed and layed in 10 bbls of latex cement (see cement details). Ramped pressure aggressively to 3000 psig and held for 1 hr. LRO to 10286'. Jetted from 10000 to 10286 and reversed back same. Recovered 7 bbls of cement from MI. Estimate about 1.5 bbls went behind pipe and the rest is in the sump. Final PT was jug tight. Reversed back 23 bbls with lift gas - saw FL at 3200'. Initial Well Status (psig) (psig) (psig) (psig) (deg F) (psig) 880 I 900 I 50 I 250 I SI I N/A Time l[ Operation 7:30 MIRU DS #2, 14,500' of 1.75" coil. CTV=33 bbls. 8:45 PT hardline and Lubricator 9:00 Recover Methanol 9:21 Begin Bullhead kill. (ft) (bpm) (psig) (psig) (bbls) (bbls) , 9:31 surf 0 1050 1020 31.6 RIH. WHP coming up. Will have to circulate the gas out while RIH. 10:25 5000 .3 470 710 47 9.5K. Begin circulating gas down flowline. 10:33 6000 2 3400 790 63 10:59 9300 2 3400 520 125 16.5K up wt. 11:14 10280 2 3600 1000 163 Park coil. Perfs or choke plugged. Open choke some more and flag coil. 11:56 2 3600 750 255 Trip to safety and back. 17K off bottom. 12:12 10280 1 1550 290 SD to check hydrostatics and injectivity. 12:17 1 630 660 Hydrostatics looked fine - check injectivity. 12:19 1 1440 Increse rate 12:27 1.8 1725 306 Batch up cement. 12:47 2 3600 1533 330 Open chokes to keep liner cool. 14:02 0.8 1750 1300 482 Safety meeting. Close chokes. FP coil. 14:08 PT dowell 5/0 SW to acid 14:21 1.4 3250 1790 10/0 SW to FSW. PU to 10200'. 14:36 10200 1.0 3400 2100 23 Acid at nozzle. BH in at 1 bpm while recip across perfs. 14:46 10200 1/0 2050 1200 33 SD and let acid soak. Had a good break down to 950 psig than started coming back. 15:01 0/1 330 260 43 Field test was 92 ml with 1.3" filter cake. Check injectivity to see if it continues to deteriorate will trying to bring cement into spec. 15:17 10100 1 1500 809 53.6 Injectivity appears to be lining out. RIH to flag. 15:43 10280 1 1710 940 68 New field test. 76 ml and 1.0" filter cake. Decide to pump. 15:55 82/0 SW to FW. Take returns holding 500 psig back pressure. 16:01 1500 500 10/0 SW to Cement 16:09 3730 10/0 SW to FW 16:11 1.6 3200 516 5/0 SW to FSW 16:22 18 cmnt at nozzl 16:23 1.7/1.3 1600 500 20 PUH at 35 FPM. 20K off bottom. 16:24 22 4.5 Ramp pressure to 1500. Start live cell 16:27 1500 26 8 PUH at 70 FPM 16:29 1.3/.5 28 9.5 PLF 16:30 9850 .5 1500 29 10 At safety. 16:32 30 11 Go to 2000 16:34 2000 31 11.5 16:36 32 12.5 Go to 3000 16:38 2300 33 13 16:40 3060 34 13.5 SD and trap pressure 17:16 3043 Circulate some fluids. 17:24 3565 Trap 3500 psig. Live cell at 73cc @ 60 mins. 17:30 3547 Bleed off pressure and line up for LRO. 17:35 0/1.6 1500 1500 38/0 Begin LRO 18:12 10135 1.4 60 1980 55 Cmnt returns at surface. 18:30 10213 1.3 70 2030 80 Reduce rate to try and keep WHP down. 18:51 10287 1.5 77 1862 103 Past flag. Wait for returns to clean up. 18:56 110 PU to WCTOC 19:21 10000 0 1800 1800 147/0 Returns are clean. Line up to jet. 19:41 10280 1.7 3400 1500 29 At flag jet up. 19:51 10000 0 1700 1700 44/0 Line up for final reverse out. 20:09 10286 1.7 2000 2000 24 On btm. Wait on btms up. 20:26 10286 1.7 1700 1700 50 Come off btm. 20:47 9591 0 2020 2020 80 SD for PT 21:01 2009 0 Reverse in lift gas. 21:43 6832 0 900 1850 23 Close chokes. 7 bbls of cement back. 22:21 3200 750 1930 Saw FL 22:52 surf 0 1950 1950 Close swab and FP coil. 23:14 35 RDMO Final WellStatus II SIWHP I] IAP II OAP [[ FLP (psig) (psig) (psig) (psig) [ 1900 [ 900 [ 0 Tool String Description I TC I 2.25,, Cement Nozzle 2.5" BHA # 1 OD ID Total Length Length Comments ,,, .37 .55 0.92' Cement Details Lab Data - Pilot Test 15.6 PPG, Ash Grove Class G Latex Cement D020 1.50 %BWOC D047 0.10 GAL/SAC D065 0.35 %BWOC D134 1.0 GAL/SAC D135 0.10 GAL/SAC D800 0.60 %BWOC MI 17 0.30 %BWOC API Fluid Loss= 60.2 ml Filter Cake = 0.82" Thickening Time= 8hrs. 35mins (inc. 2hfs surface time) Field Test # 1 API Fluid Loss= 92 ml Filter Cake = 1.3" Density= 16.0 PPG Field Test #2 (Added 5 gallons of Latex) This is the one we pumped AP1 Fluid Loss= 76 ml Filter Cake = 1.0" Density= 16.0 PPG Live Cell Data: 60 min FL was 73 ml. Final FL was 100 ml and a 2.4" filter cake. All filter cakes looked very good (hard) BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 5/26/97 WELL N°: 2-28/P-19 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: POST SQUEEZE G. McBRIDE HES/TILBURY DATE/TIME OPERATIONS SUMMARY 1300 MIRU. 1330 DROP 3 ~ XN CATCHER. RIH w/KJ, 4 ½ OM-l, 7" EXT. & 2" JDC TO STA #6 @ 4186' WLM. PULL 1 ~,~ DGLV & RA. POOH. 1430 RIH w/1 ½ GENERIC OGLV & RA TO SAME. SET. POOH. 1530 RIH w/3 ½ GS TO 9380' WLM. PULL 3 ½ CATCHER. POOH. 1630 RIH w/KJ, 2.50 CENT. & 2 1/8 DUMMY GUN. LOCATE TT @ 9438' WLM, (ELMD=9458'). TAG TD @ 10311' WLM, (CORRECTED TD =10331 '). POOH. 1830 RDMO. S1=650 IA=500 OA=0 SUMMARY: SSSV: POST SQUEEZE. INSTALLED GENERIC ORIFICE, (5/16" PORT), IN TOP GLM. DRIFTED WITH 2 1/8" DUMMY GUN TO 10331' CORRECTED TD. OUT WSA PRODUCTION TEAM To: Endicott Reservoir, Anchorage From: Luecker Date: 5-25-97 Re: 2-28 NRWO, Water Shutoff 5-25-97 Time Operational Summary 07:00 MIRU Dowell CTU #6, ctu vol. 33.3 bbls, squee3ze unit in place. 08:17 Pressure test 4000. 09:00 Safety meeting 09:15 Recover methanol. 09:32 SIWHP-1260, IAP-850, OAP-0, Start RIH, POP at minimum rate. 13:30 Spill prevention walk through with cementers, ctu and squeeze personnel. 5-25-97 TIME CTD WHP CTP RATE VOL RTNS COMMENTS 10:19 3500 730 600 .25 41 10:48 6500 720 400 .25 48 Pull test 11.5k 11:23 10100 430 3100 2.3 68/0 Start jetting through perfs, open choke 11:32 10300 330 3800 2.4 20 RIH and start jetting and reciprocating sump. tag TD. 12:25 9450 280 3720 2.4 116 Well is dead 12:47 10300 290 3700 2.3 154 Divert to tank, some gas and crude. 13:58 10300 260 230 1.0 304 S/D, perform injectivity test. 1 bpm @275. 15:29 10275 250 1230 1.0 466 Good fluid rtns, injectivity of 1 bpm,@ 250. f/l cell 15:15. 15:45 Safety meeting, P/t lines 4000. 16:12 10275 260 2800 2.0 532/0 Switch to EW 16:17 9935 279 2381 2.2 10/0 Switch to cement 16:26 10035 287 3063 2.0 13/0 switch to EW 16:31 10175 282 3500 2.2 10/0 Switch to SW 16:34 10266 293 3491 2.1 8 Start guaging. 16:35 10271 2.2 9 .5 16:35 279 3484 2.2 10 0.75 Cmt @ nozzle 16:36 10275 289 2069 1.5 11 1 16:36 10276 279 12 1.75 16:37 10276 289 1366 1.6 13 1.75 Start PUH 16:38 10243 14 16:38 10230 292 1392 1.6 15 3 16:39 10210 285 1423 1.6 16 3.75 Perfs covered. 16:40 10186 291 1461 1.6 17 4.5 16:40 10152 291 18 5.25 Ramp 700 psi 16:41 10120 700 1900 1.5 19 5.5 16:42 10105 20 6.25 Ramp 1200 psi 16:42 10075 1286 2252 1.4 21 6.75 16:43 1057 1254 2690 1.4 22 7.5 Little gas~a 16:44 10016 1263 2763 1.5 23 8.25 PLF Endicott 2-28 WSO, 06/24/97 16:44 9954 1255 2833 1.5 24 9 16:45 9860 1250 2841 1.5 25 9.75 16:46 9824 1245 2846 1.5 26 10.5 Park coil 16:47 27 16:47 9824 1250 28 12.25 16:48 9824 1242 2854 29 13.25 16:48 9824 1248 2860 30 14.25 16:49 9824 1250 31 15.25 Ramp to 2000 psi 16:50 1900 3300 32 15.75 16:50 9824 2077 3486 33 16.25 16:51 9824 2067 3660 1.5 34 17.25 16:52 9824 2056 3668 1.5 35 18 16:52 9824 2052 3668 1.5/1.0 36 19 Slow rate 16:54 9824 2043 2811 1.0 37 20 16:54 9824 2096 2808 1.0 38 21 Ramp to 2500 psi 16:55 9824 2500 3265 1 39 21.5 16:57 9824 2542 3283 1 40 22.5 16:57 9824 2564 3273 1 41 23.5 Ramp to 3000 psi. 16:58 3074 3759 1 42 24 16:59 3075 3833 1 43 24.75 17:00 3050 3850 1 44 25.75 17:01 3047 3847 45 26.5 17:02 3050 3865 1/.5 46 27.5 Reduce rate. 17:03 3036 3257 .5 47 28.5 17:05 3036 3250 .5 48 29.5 ramp to 3500 17:07 3500 3748 .5 17:07 3552 3743 .5 49/0 30 17:09 3536 3735 1 .75 swap tanks in squeeze unit 17:11 3536 3527 .5/0 2 2.0 trap 3500 psi. 17:22 9824 3429 3407 0 17:32 3375 3350 0 125 psi loss in 25 minutes. 17:43 3355 3335 0 0 0 20 psi in 10 minutes, drop pressure to 2000,., reverse out. 17:47 9824 1800 60 1.7 0 0 Start LRO. 18:17 10060 2170 65 1.4 44 18:33 10115 2030 80 1.4 65 At perfs. 19:33 10300 1820 70 1.5 146 19:56 10265 1875 1875 0 175/0 Clean rtns, 10 bbls cement back, pressure tes~ in 5 minutes. Prepare to make,jet pass. 20:10 10080 1500 3840 1.6 8 20:31 10260 1490 3700 1.5 44/0 Start second reverse out. 21:08 10000 1860 0 1.5 54/0 Clean rtns, 10 bbls total to MI. Press test.20 psi in 10 minutes. 200 psi in 25 minutes 21:36 10000 1800 1800 0 0 Start backin~ in lift ~as. 22:19 8800 1975 1050 0 0 27 27 bbls rtn, continue POOH. 22:52 3500 1976 700 0 0 Fluid level indicated, come on line and pump minimum. 23:13 0 1940 1930 .25 4 OOH, F/P CT, RD and MOL. Endicott 2-28 WSO, 06/24/97 2 FLUID SMUMMARY 600 bbls. FSW RIH and sump cleanout, and cool down. 10 bbls. FSW 13 bbls Cement 10 bbls EW 49 bbls SW 175 bbls. SW reverse 44 bbls SW jetting 54 bbls. SW second reverse pass CEMENT D020 1.0 BWOC D047 antifoam .20gal/sk D065 dispersant .50 % BWOC D800 .9 GPS M117 1.0% BWOC D135 .1 GPS D134 .9 GPS API fluid loss was 78 cc with .90" filter cake thickness (field) SUMMARY RIH and circulated to kill well. Well would not flow. It was probably loaded up and was killed by running in the hole and header pressure of 280 psi (Hydrostatic of water + 280 =4680, SIBHP estimated at 4600). Circulated FSW until all water returns holding 250 psi WHP. Did not pump acid into perfs. Felt that existing squeeze perfs, production logs of 5-1-97 indicated holding, would possibly be damaged and that given the high PI of the well and the low drawdown of the well that acid would be of nominal value. Laid in 13 bbls of latex cement from 10275. Cement had AP1 f/i of 78 with a filter cake of .9". Performed a relatively aggressive ramp with 1250 psi 3 minutes after perfs covered and 3000 psi after 20 minutes. Ramped up to final squeeze pressure of 3500. Held squeeze pressure for a total of 1 hour. Reversed out with 175 bbls SW, pressure tested and WHP fell 300 psi in 5 minutes. Made jet pass and second reverse out. Recovered 10 bbls. of cement, estimate 1-2 bbls of cement behind pipe. Reversed in liftgas from 9000' making final fluid level approximately 3100'. Endicott 2-28 WSO, 06/24/97 3 "--" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging__ Perforate__ Pull tubing Alter casing __ Repair well ... Other x 2. Name of Operator 5. Type of Well: 6. BP Exploration (Alaska) Inc. Development X Exploratory ~ 3. Address Stratigraphic 7. P. O. Box 196612, Anchorage, Alaska 99519-6612 Service 4. Location of well at surface 8. 1944' SNL, 2240' WEL, Sec. 36, T12N, R16E At top of productive interval 9. Datum elevation (DF or KB) KBE = 55 feet Unit or Property name Duck Island Unit/Endicott Well number 2-28/P- 19 MPI Permit number/approval number 88-86/not required 10. APl number 50- 029-21847 2310' SNL, 1930' WEL, Sec. 36, T12N, R16E At effective depth 2370' SNL, 1897' WEL, Sec. 36, T12N, R16E At total depth 2375' SNL, 1895' WEL, Sec. 36, T12N, R16E 11. Field/Pool Endico~.P~o~ ! ~[ I I' !~ 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 10530 feet Plugs (measured) 10479 BKB feet 10448 feet Junk (measured) 10397 BKB feet Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2465' 13 3/8" 3687 c.f. Permafrost 2504' 2503' 9605' 9 5/8" 575 c.f. Class G 9644' 9597' 1144' 7" 517 c.f. Class G 9383'- 10527' 9338'- 10476' measured 10114'- 10160'; 10180'- 10200', 10216'- 10226' (all squeezed) 10145'-10155', 10152'-10157', 10188'-10213', 10196'-10206', 10216'-10246'(all open) true vertical (Subsea) 10009'- 10055'; 10075'- 10095'; 10111'- 10121'(all squeezed) 10040'- 10050', 10047'- 10052', 10083'- 10108', 10091'-10101', 10111'- 10141' (all open) Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" 9.2# L-80 tailpipe to 9452' Packers and SSSV (type and measured depth) 9 5/8" SAB Packer at 9339', 4 1/2" SSSV at 1555' 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment (7/24/96) Intervals treated (measured) 10145'-10155', 10152'-10157', 10188'-10213', 10196'-10206', 10216'-10246' Treatment description including volumes used and final pressure ss bbla Seawater/Mutual Solvent Mix, 315 bbls Seawater/Scale Inhibitor Mix, 507 bbls Seawater/2% Surfactant Mix, 169 bbls Seawater Tubing Volume. FSlWHP=Shut-in 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2284 10696 9736 0 N/A N/A N/A Tubing Pressure 1105 N/A 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil x Gas Suspended Service 17., here~y~e,rtify that.the(,~, ~,go~n? is tr..ue.,and correct to the best of my knowledge. Signed ~ Title Senior Technical Assistant IV Form 10-40~:{~v 06/15/88 Date 8/8/96 SUBMIT IN DUPLICATE Endicott Production Engineering Department Additional Perforations DATE: 4 - 26 - 96 WELL N°: 2-28/P-19 BP EXPLORATION REP: VARBLE SERVICE CO: ATLAS (RICHARDS,DAHL) RECEIVED AUG 0 S 1996 Alaska 0tl & Gas Cons. Commission Anchorage DATE/TIME OPERATIONS SUM. MARY 1430 MIRU ATLAS 1 51 5 HOLD TGSM 1530 ARM GUN 1607 S.I. WELL & RIH WITH SINKER BAR/PFC/5' GUN 1700 LOG TIE IN PASS FROM 10330' - 10250'. TIE INTO DLL DATED 8/13/88 OPEN WELL TO 80 BEANS TO UNDER BALANCE. (FWHP = 385) OPTED TO SHOOT WITH WELL SHUT IN. SEE PERF SUMMARY FOR DETAILS. 1730 LOG CONFIRMATION PASS FROM 10330' TO 10250'. ON DEPTH. LOG UP & HANG CCL @ 10143' MD (9' FROM CCL TO TOP SHOT) 1745 SHOOT GUN FROM 10152' - 10157' MD GOOD CAP BREAK. NO WEIGHT CHANGE. LOG OFF. 1755 POOH .1825 OOH 1831 CONFIRM ALL SHOTS FIRED. 1930 RDMO PERFORATION SUMMARY: GUN DIL DEPTH FEET SUBZONE I 10,152-10,157' 5' 3A2 ALL INTERVALS WERE SHOT USING 2-1/8 SILVER JET GUNS AT 6 SPF, 0 DEG. PHASING AND RANDOM ORIENTATION. HIGH GAMMA RAY COUNTS IN THE TBG. ALL OPEN & SQZ. INTERVALS ARE VERY HOT. UNABLE TO CORRELATE TO THE OPEN HOLE OR THE BOND LOGS. OPTED TO TIE IN FROM 10330'-10250' & PULL UP HOLE TO SHOOT. DECIDED IT WOULD BE BEST TO LEAVE WELL SHUT IN FOR BETTER DEPTH CONROL THAN TO TRY & SHOOT UNDERBALANCED. PROBALBY A GOOD CANDIDATE FOR SCALE INHIBITOR TREATMENTS. HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date 17 May 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 2-36/O-14 (MPI) 2-28/P-19 (MPI) 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF Run # 1 Run # 1 ECC No. 4205.05 5724.06 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ ~7~° (907) 563-7803 Received by: .. Date: Gas Cons. Commission Anchoraq~e LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 7 May 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION PFC/PERF FINAL BL+RF (--Run # 1 PFC/PERF FINAL BL+RF~"~Run # 1 PFC/PERF FINAL BL+RF JRun # 1 PLS FINAL BL+RF Run # 1 ECC No. 5724.05 5725.06 5937.09 6355.07 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Service% 5600 B Street Suite 201 ~ Anchorage, AK 99518 (907) 563-7803 ~88k8 Received by: Date LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 August 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 PLS FINAL BL+RF 1 CCL FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS/STP FINAL BL+RF ECC No. Run # i - 3867.02- Run # 1 5157.08 Run # 1 6014.03 Run ~ ! 6156.01 Please sign and return to: Attn. Rodney D. Paulson Atlas WJ ,~ces B Street Suite 201 , AK 99518 Or FAX to (907) 563-7803 Received by Date: Endicott Production Engineering Department DATE: 4/27/95 WELL NS: 2-28 / P-19 BP EXPLORATION REP: CLUMP SERVICE COMPANY: ADD-PERF ATLAS (BARBA) Ii ,'DAT,E/TIME ...... , OPERATi'ONS SUMMARY. ,, .... ,,,I 1200 MIRU ATLAS. 1315 SHUT-IN WELL. RIH WITH 25'- 2"' HSC, 4 SPF, 0 DEG PHASING, 0 DEG ORIENTATION (OVERALL TS LENGTH 38.5'): ... 1350 TAG BTM @ 10358' MD BEE. LOG FROM 10366' - 10055' UP TO TIE IN TO CRT DATED 17 AUG 1988. ON DEPTH. OPEN WELL TO FLOW @ 25 BEANS. ALLOW TO STABILIZE FLOW. 1414 RIH 'TO 10310'. MAKE TIE IN PAS~3 FROM 10310'- 10255' (-2). MAKE CONFIRMATION PASS FROM 10308'- 10184.5' MD BKB. ON DEPTH. SHOOT GUN FROM 10188-10213' MD. GOOD INDICATION. .NO WT CHANGE. FWHP= 1075 PSI. LOG OFF ..... 1435 SHUT IN WELL. ALLOW FOR WELL TO STABILIZE. POOH. 1530 " CCH. ALL SH0~S FIRED .... 1500 RDMO. pOp WELL TO FOal'. , SlP=1250 PSI lAP= 0 PSI CAP= 0 PSI .... PERFORATION SUMMARY: DEPTH FEET SUB.~ONE 10188-10213 25 2B Interval was shot with 2" HC Alpha Jet, 4 spf, 0 deg phasing, 0 deg orientation. R £CF..lV F..D Oil & Gas Cons. Commission Anchora~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 2 May 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: .WELL ~?~ ~ 2-46/Q-15 DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1GR/CCL FINAL BL+RF 1 PLS FINAL BL+RF ECC No. Run # 1 3842.04 Run # 1 5724.04 Run # 1 6004.05 Run # 1 6351.06 Run :~ 1 6355.04 Run # 1 Run # · 1 6419.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 · Or FAX to (907) 563-7803 Received by: Date: Please st~n end return ~$ Petroteohnieal Data Oente~ BP Exploration (Alaska) 900 East Benson Boulevard ~,~e~~ 99508 .' BP EXPLORATION BP Exploration (Alaska) Inc. g00 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 16, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, qSCenior Technical Assistant II JLH Enclosures xc: File 06.10 SEp 2 0 1993 WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME 1-09/J-18 3-17/J-30 2-18/L-16 2-36/O-14 1-35/0-25 2-28/P-19 1-15/P-25 3-47/Q-35 1-51/V-20 8/22/93 7/27/93 9/5/93 8/20/93 8/25/93 8/28/93 9/4/93 9/6/93 8/21/93 11200'-11945' 13400'-13950' 10900'-11200' 10800'-11250' 12700'-13261' 9800'-10320' 12400'- 12860' 100'-10450' 3600'-12700' PDK- 100 LOG PRODUCTION LOGGING SERVICES PFC/GR/CCL PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE STATE OF ALASKA ., ,~,._ ..~KA OIL AND GAS CONSERVATION COMMI~,. ~)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging.. Perforate x Pull tubing ... Alter casing Repair well. Other x 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1944' SNL, 2240'WEL, Sec. 36, T12N, R16E 5. Type of Well: Development X Exploratory Stratigraphic Service .... o , o At top of productive interval 9. Datum elevation (DF or KB) KBE ~ 55 feet Unit or Property name Duck Island Unit/Endicott Well number 2-28/P- 19 MPI Permit number/approval number 2310' SNL, 1930' WEL, Sec. 36, T12N, R16E At effective depth 10. 2370' SNL, 1897' WEL, Sec. 36, T12N, R16E At total depth 11. 2375' SNL, 1895' WEL, Sec. 36, T12N, R16E 12. Present well condition summary Total depth: measured 10530 feet Plugs (measured) true vertical 10479 BKB feet JUN 2 4 1993 .0il & Bas Cons. Commission ~chQrage 88-86/not required APl number 50- 029-21847 Field/Pool Endicott Oil Pool Effective depth: measured 10448 feet true vertical 10397 BKB feet Junk (measured) 3 bowspring leafs in the bottom of the well Casing Structural Conductor Surface intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True v~Bal depth BKB 92' 30" Driven 131' 131' 2465' 13 3/8" 3687 c.f. Permafrost 2504' 2503' 9605' 9 5/8" 575 c.f. Class G 9644' 9597' 1144' 7" 517c. f. Class G 9383'- 10527' measured 10114'- 10160'; 10180'- 10200', 10216'- 10226'(allsqueezed) 10196'-10206', 10216'-10246' 9338'- 10476' true vertical (Subsea) 10009'- 10055? 10075'- 10095'; 10111'- 10121'(all squeezed) 10091'-10101', 10111'-10141' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" 9.2# L-80 tailpipe to 9452' Packers and SSSV (type and measured depth) 9 5/8" SAB Packer at 9339', 4 1/2" SSSV at 1555' 13. Stimulation or cement squeeze summary Cement squeeze for gas shut-off Intervals treated (measured) 10114'-10160'; 10180'-10200'; 10216'-10226' Treatment description including volumes used and final pressure 1075 Bbls seawater, 24 Bbls EDTA, 5 Bbls effluent water, 40 Bbls methanol FSIWHP = 1500 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1359 i 1022 21 0 2942 1586 ~"~ 7171 17 0 1663 , , , , 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations .. ;~ Oil ;~ Gas Suspended 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 1~-404 Rev 06/15/88 ' ' Service sUBMIT IN D~PLI~CA~E Endicott Production Engineering Department ,Vi Post S(]ueeze Perforations D AT E: 5/2/93 WELL N~: 2-28/P-19 BP EXPLORATION REP: Luedke-Chan SERVICE COMPANY: AWS DATE/TIME. OPERATIONS SUMMARY 1500 ' MIRU'. Post radio silence signs at the entrance to island and next to well site. 1520 Install SSV: fusible cap. SIWHP = 210 psi. lAP = 100 psi. gAP = 50 psi. 1540 ESTABLISH RADIO SILENCE AND ARM GUNS (Not~y security). 1600 Pressure test lubricator, t.o wellhead pressure. 1650 RIH with Gun #1 (20 feet). SlWHP = 210 psig. 1800 Open wincj valve and set produCtion choke to 32 beans. 1810 Tie in to CBL dated 8/17/88. All of the depths listed below are from the open hole reference log. Flag line for next run. FWHP ='210 psig ~) 32 beans, 1850 Hang gun #1 Top Shot at 10226 MDBKB. 1852 Shoot gun #1 from 10226-10246' MDBKB (blown uph01e ~100 feet-good ,,, indication that gun went off) and flow well for 15-20 minutes. FWHP = 750 psig. Tag TD ~ 10~361' MDBKB (E-Line). 2100 RIH with Gun ~ (20 feet). SIWHP = 1500 psig. 2150 Open wincj valve. FWHP = 500 psig. 2205 Tie in to CBT Ioggincj up. Shoot gun # 23 from 10216-10226' MDBKB. 2230 Shoot gun # 2b from 10196-10206' MDBKB. 2245 SI well and POH. SlWHP = 1532 pslg. 0100 OOH. Work hydrates out of lubricator. Confirm all shots fired. 0130 End radio silence. ._ 0200 RDMO. POP. PERFORATION SUMMARY: GUN INTERVAL(DLL) ~ FEET ~ 1 10226-10246 10226-10246 20 2B 2A 10216-10226 10216-10226 1 0 2B 2B 10196-10206 10196-10226 10 2B All intervals were shot using 2-1/8" Jumbo Jet III guns at 4 spf, 180 degree phasing and 0 orientation. Pre-iqueeze Well Te[t Data ( 4/28/93) OIL RATE I CHOKE GOR BS&W (BPD) I (BEANS) (SCF/STB) 972 [ , 8 4547 , (%) WHFP I WHFT (PSIG) I (DEG F) 2860 I I 16 2.2 ..... Post'Squeeze and Perforation Well Test Data ( 5 /4/ 93) __ OIL RATE I CHOKE I GOR I Bs&w I WHFP I WHFT (BPD) I (BEANS) ! (SCF/STB) I (%) I, (PSIG) I (DE,G F) 2! 1, 3o I 652 ! 1.1 I 1663,, ! 115 Note: Changed out choke from 48 bean to 104 bean. Will test at a higher choke setting when test separator schedule allows, but well seems to be the only thing between Endicott and decline. Maybe we could put in a 176 beaner and shut in the rest of the field. JUN 2 4 1993 .0J! & Gas Cons, Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 I:ast Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 19, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, ~,~ a~n-ne L. Haas- Senior Technical Assistant II JLH Enclosures RECEIVED BAY 20 XC: File 06.10 BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICOTT FIELD ONLY WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME 1-51/V-20 O~ 4/1 9/93 112o0'- 12740' {~.... ~ t 4/22/93 1 00o0'-12721' 4/22/93 10000'-12721' 5/3/93 11300'- 12691' ~.~ 5/14/93 11900'-12694' 1-55/R-25 5/8/93 12900'-13195' 2-14/O-16 2-28/P- 19 ~ 4/26/93 9200'- 10585' 5/2/93 10050'-10335' 3-29/J-32 ~'0..- I'~{.~, 5/2/93 12290'- 12416' 3-39/J-39 <~"7~lt(.,, 4/30/93 13930'-14276' 3-41/K-39~;/lO-L0 4/24/93 12640'-12648' DIL/SFL/GR CBL CNL/GR/CCL PFC/GR CBL Production Logging Services GR/CCL PFC/GR Production Logging Services PFC/GR Vertilog Schlumberger Atlas Wireline Services Atlas Wireline Services Atlas Wireline Services Atlas Wireline Services Atlas Wireline Services Atlas Wireline Services Atlas Wireline Services Atlas Wireline Services Atlas Wireline Services Atlas Wireline Services BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICOTI' FIELD ONLY WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME // 1-35/O-25~6-t~t 1 0/1 6/92 12100'-13150' 1-43/P-26 o°;~'-Io~ 9/28/92 12900'-14275' 1-47/Q-21oe~-~t) ~ 1 0/1 3/92 10750'-11200' 1,67/T-20 ~J*l!' 9/26/g2 11315'-11600' 0/1 5/92 9650'-10350' ~to '-12 9/29/92 10620'-12063' 3-07/N-28o°~"1~'' g/27/92 13050'-13300' ., 3-11/M-30g~-"J? 10/14/92 12800'-13380' 4-04/T-26 8~'-"~' 9/28/92 13000'-14030' 3,~.. V ~' 4-06/Q-32~/,~$ 10/3/92 10800'-11482' 4-44/M-44 ~?..~r~ ~[ 9/27/92 13600'-14226' 9/17/92 14000'-14225' SAG DELTA NORTH ONLY 2-32/SN-03,%,.~1~1 9/19/92 7/' 12900'-13278' PDK-100 Gamma Ray/CCL (Borax)---" Injection Profile Survey Production Logging .. PFC Gamma Ray ¢ PDK-100 Gamma Ray/CCL (Borax) Injection Profile Warm Back Injection Profile Survey ~ . Production Logging (?~J~,~' Injection Profile Survey Production Profile - Pump-In-Temperature Survey PFC//Gamma Ray Production Profile Survey ,,~ Atlas Wireline Carrx~ Atlas Wireline Atlas Wireline Atlas Wireline Camco Camco Atlas Wireline Camco Camco Camco Atlas Wireline 1 Camco OCT 0 1992 Alaska 0il & Gas Cons. Commissi0n Anchorage Bluelines to the State BLUELINE AND SEPIA INFORMATION ENDICO'Fr FIELD ONLY WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME 1-27/P-20 .'"' 5/1/92 10350'-10850' Production Profile Survey One Camco ~2--- ~g' 2-28/P-19 -/' 5/2/92 /..f,,,,'o 2-30/O-09 "' 5/20/92 J.-I?z. 2-34/P-14-,/ 5/16/92 ~-7-~ 2-46/Q-15 / 5/3/92 ~ ~'~?? 2-64/U-10 "" 5/22/92 ~'~.-I ~,~ 3-01/N-29 ,/ 5/4/92 ~..{~,o 3-33/K-37 "" 5/21/92 ~.-7.7. <j4-02/Q-28 ,," 5/11/92 t.4-02/Q-28 / 5/24/92 ~.-~¢ 4-50/K-41 ./ 6/7/92 /' 4-40/P-43 ./ 5/14/92 ') 4-40/P-43 ---' 5/14/92 ,[~,,~'~' '~ 4-40/P-43 '/ 5/1 4/92 ~ 4-40/P-43 ,-/' 5/1 4/92 ~ 4-40/P-43 '''/ 5/1 8/92 1~4-40/P-43 --' 5/1 8/92 9900'-10300' 11100'-13250' 100'-10700' 10500'-11100' 8800'-9600' 12150'-12700' 12640'-12945' 11800'-13000' 10600'-13008' 13300'-13890' 13100'-13801' 13031.6'-13624' 13100'-13806' 9650'-13806' 12580'-13688' 12580'-13652' Production Profile Survey Production Log Leak Detection Survey Production Profile Survey TDT-P/Borax Survey/Water FLow Log Production Profile Survey Production Log Flowmeter Temperature Log Injection Profile Survey Production Logging Services Dual Laterolog Micro-SFL Repeat Formation Tester Subsea TVD Log Compensated Neutron-Litho-Density Ultrasonic Imager (USI)' ~ Cement Bond Log One One One One One One One One One One One One One One One One Camco Schlumberger Camco Camco Schlumberger Camco Schlumberger Camco Camco Atlas Wireline Services Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Page 1 STATE OF ALASKA ALAoKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. OPerations performed: Operation shutdown Stimulate x Plugging Pull tubing Alter casing .. Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1944' SNL, 2240' WEL, Sec. 36, T12N, R16E At top of productive interval 2310' SNL, 1930' WEL, Sec. 36, T12N, R16E At effective depth 2370' SNL, 1897' WEL, Sec. 36, T12N, R16E At total depth 2375' SNL, 1895' WEL, Sec. 36, T12N, R16E ' 1;~. Present Wail '~:ondition summary Total depth: measured true vertical Effective depth: measured true vertical 10530feet 10479 BKBfeet 10448feet 10397 BKBfeet 5. Type of Well: Development X Exploratory Stratigraphic Service Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) KBE -- 55 feet 7. Unit or Property name ' ' Duck Island Unit/Endicott 8. Well number 2-28/P- 19 MPI 9. Permit number/approval number 88-86 / 9O-632 10. APl number 50- 029-21847 11. Field/Pool Endicott Oil Pool 3 bowspring leafs in the bottom of the well Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented 92' 30" Driven 2465' 13 3/8" 3687 c.f. Permafrost 9605' 9 5/8" 575 c.f. Class G Measured depth True vertical depth BKB BKB 131' 131' 2504' 2503' 9644' 9597' 1144' 7" 517c. f. Class G 9383'- 10527' 10114'- 10160'; 10180'- 10200', 10216'- 10226' 9338' - 104 76' true vertical (Subsea) 10009'- 10055'; 10075'- 10095'; 10111'- 10121' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" 9.2# L-80 tailpipe to 9452' Packers and SSSV (type and measured depth) 95/8" SAB Packerat 9339',4 1/2" SSSVat 1555' R E C E I V E D 13. Stimulation or cement squeeze summary 6% HCL- 1.5% HF stimulation w/CTU JAN ! ! ]991 Intervals treated (measured) 10114'-10160'; 10180'-10200'; 10216'-10226' AJaska 0ii & ~as COrls. Treatment description including volumes used and final pressure 45 bbls, 6% HCL; 65 bbls, 1.5% HF Anchorage Final coiled tubing pressure = 3700 psi 14. Prior to well operation Subsequent to operation Re0resentative Daily Average Production or In!action Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1647 2015 2 0 1776 2609 2 0 Tubing Pressure 1858 1994 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil .x Gas... Suspended Service 17. I hereby cert. ify that the foregoing i_s true and correct to the best of my knowledge. Signed .~~,~ ~ . Title Reservoir Develo~ment Coordinator Form 10-4'04 Rev 06/15/88 Date SUBMIT IN DUPLICATE ~,~ STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. O%rations Performed: Operation'shutdown ' Stimulate .X plUgging Perforate Pull tubing Alter casing "2. 'Name Of'Operator ..... BP Exploration (Alaska) Inc. 31 Address " P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1944' SNL, 2240' WEL, Sec. 36, T12N, R16E At top of productive interval 2310' SNL, 1930' WEL, Sec. 36, T12N, R16E At effective depth 2370' SNL, 1897' WEL, Sec. 36, T12N, R16E At total depth 2375' SNL, 1895' WEL, Sec. 36, T12N, RI6E ' 1"2.' Pr~s~e~t well condition summary ' Total depth: measured true vertical Repair well Type of Well: Development X Exploratory Stratigraphic Service 10530feet Plugs (measured) 10479 BKB feet Other ,, 6. Datum elevation (DF or KB) KBE = 55 feet 7. Unit o'r Property name Duck Island Unit/Endicott 8. Well number 2-28/P- 19 MPI 9. Permit number/approval number 88-86 / 90-632 10. APl number 50- 029-21847 11. Field/Pool Endicott Oil Pool Effective depth: measured true vertical 10448feet 10397 BKBfeet Junk (measured) 3 bowspring leafs in the bottom of the well Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2465' 13 3/8" 3687 c.f. Permafrost 2504' 2503' 9605' 9 5/8" 575 c.f. Class G 9644' 9597' 1144' 7" 517 c.f. Class G 9383' ~ 10527' 10114'- 10160'; 10180'- 10200', 10216'- 10226' 9338' - 104 76' true vertical (Subsea) 10009'- 10055'; 10075'- 10095'; 10111'- 10121' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 9 5/8" SAB Packer at 9339', 4 1/2" SSSV at 1555' 13. stimulation or cement squeeze sum~nary '6% HCL - 1.5% 'HF stimulation w/CTU ' Intervals treated (measured) 10114'-10160'; 10180'-10200'; 10216'-10226' Treatment description including volumes used and final pressure aska, fiil & Gas Cons. Comais ~ bbls, 6% HCL; ~ bbls, 1.5% HF Fin~ coiled tubing prossur, ~ 3700 psi 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1647 2015 2 0 1776 2609 2 .0 Tubing Pressure 1858 1994 15. Attachments Copies of Logs and Surveys run . Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 [:lev 06/15/88 Date /'-,,~- ?/ SUBMIT IN DUPLICATE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.o. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 December 27, 1990 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells' WELL 1-57/R-23 TDT-P BORAX 11500'-12000° SCHLUMBERGER WELL 2-16/M-16 INJ 11000'-11450' CAMCO WELL 2-20/L-15 PRODUCTION LOG/PBU 10660°-11150' SCHLUMBERGER WELL 2-28/P-19 PRODUC~ON LOG 9900'-10275' 12/3/90 RUN ONE 1 1/21/90 RUN ONE 1 1/1 8/90 RUN ONE 12/3/90 RUN ONE RECEIVED Alaska Oil & Cas" ~- BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 20, 1990 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells: WE, LI. 1-27/P-20 8/22/90 PERF RUN ONE 9688'-10690' SCHLUMBERGER WELL 1-27/P-20 10/20/90 PROD-F RUN ONE 10350'-10942' ,,WELL 1-63/T-22 10/19/90 PROD-F RUN ONE 12200'-13098' WELL 2-28/P-19 10/26/90 PROD-F RUN ONE 9900'-10443' WELL 2-36/O-14 TUBING CUTTER 10140'-10270' SCHLUMBERGER 1 1/1 3/90 RUFK~E RECEIVED N0V 2 8 1990 Alaska 0il & Gas Cons. Commission Anchorage 10140'-10261' ATLAS WlREUNE WELL 2-68/S-17 STATIC 10650'-11100' HRS CAPAC~E 10295'-10895' HRS WELL 3-17/J-30 PROD-R 13300'-14000' HRS WELL 3-21/L-34 DUAL STATIC 12625.5'-12632' SCHLUMBERGER WELL 3-33/K-37 DUAL STATIC 12944.5'-12957' SCHLUMBERGER WELL 3-39/J-39 PROD-R 14000'-14425' SCHLUMBERGER WELL 4-20/M-35 PROD-R 11535'- 11850' HRS Sincerely, ~:taas - JLH/Ims cc: File 06.10 11/4/90 RUN ONE 10/1/90 RUN ONE 10/1/90 RUN ONE 10/7/90 RUN ONE I 1/1 0/90 RUN ONE 1 0/21/90 RUN ONE 1 1/3/90 RUN ONE 10/3/90 RUN ONE RECEIVED NOV 2 8 1990 Alaska 0il & Gas Cons. Commission Anchorage ./ WELL 1-55/R-2,,5 RADIOACTIVE TRACER SURVEY 12950'-13550' SCHLUMBERGER 8/12/9O RUN ONE J STATIC PRESSURE SURVEY 12950'- 13550' SCHLUMBERGER 8/12/9O RUN ONE WELL 1-57/R-23 ¢'TEMPERATURE SURVEY 11486'-11972' HALLIBURTON LOGGING SERVICES 8/14/90 RUN ONE WELL 1-63/'1"-22- STATIC PRESSURE SURVEY 12436'-12436' SCHLUMBERGER 8/13/90 RUN ONE RADIOACTIVE TRACER SURVEY 12300'-13082' SCHLUMBERGER 8/13/90 RUN ONE WELL 1-67/T, -20 ,/'TEMPERATURE SURVEY 11120'-11650' HALLIBURTON LOGGING SERVICES 8/12/90 RUN ONE WELL 2-26/N-14 STATIC TEMPERATURE SURVEY 11500'-1 2000' CAMCO 8/12/90 RUN ONE WEI,,,L 2-28/P-19 ~/' PERFORATION RECORD 10070'-10436' SCHLUMBERGER 8/22/90 RUN ONE WELL 2-34/P-14 INJECTION PROFILE WARM BACK 10770'-10990' CAMCO 8/1/90 RUN ONE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate x Change approved program __ Pull tubing __ Variance__ Perforate Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1944' SNL, 2240' WEL, Sec. 36, T12N, R16E At top of productive interval 2310' SNL, 1930' WEL, Sec. 36, T12N, R16E At effective depth 2370' SNL, 1897' WEL, Sec. 36, T12N, R16E At total depth 2375' SNL, 1895' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE = 55 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-28/P- 19 MPI 9. Permit number 88-86 10. APl number 5O- 029-21847 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10530 feet 10479 BKB feet 10448 feet 10397 BKB feet Plugs (measured) Junk (measured) Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2465' 13 3/8" 3687 c.f. Permafrost 2504' 2503' 9605' 9 5/8" 575 c.f. C/ass G 9644' 9597' 1144' 7" 517c. f. ClassG 9383'- 10527' measured 10114'- 10160'; 10180'- 10200', 10216'- 10226' true vertical (Subsea) 10009'- 10055'; 10075'- 10095'; 10111'- 10121' 9338' - 10476' RECEIVED Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" 9.2# L-80 tailpipe to Packers and SSSV (type and measured depth) 9 5/8" SAB Packer at 9339', 4 1/2" SSSV at 1555' 13. Attachments Description summary of proposal ~ Detailed operations program x BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: November 1990 16. If proposal was verbally approved Oil x Gas ~ Nan~e of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed , 2 Title Reservoir Development Coordinator FOR COMMISSION USE ONLY Suspended Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- Approved by order of the Commission J Approval No. ~)_ ~l~ Commissioner Form 10-403 Rev 06/15/88 Approved Copy I~etu ned ORIGINAL SIGNED BY LONNIE 6. SMITH Date SUBMII IN TRIPLICATE 2-28/P-19 Mud Acid Stimulation 2-28/P-19 Mud Acid Special Pre-treatment Operations , · . . . · GA Obtain wellhead sample for emulsion testing. Test for emulsion/sludging tendencies using AP! RP 42 testing procedures (add 5000 ppm ferric ions to acid systems)· Tests should be carried out using spent and unspent 5% HCl (w/ additives) and 7%HCI / 1-1/2%HF (w/ additives) at 200 deg. F. Adjust additives as required by test results. See fluid summary for acid recipes. 2-28/P-19 Mud Acid Stimulation Procedure SI well just prior to starting job. Isolate SSV. MIRU stim company. Ensure acid transports are rolled continuously. Puli acid samples and visually inspect for suspended solids. Ensure Fe conc. are less than 350 ppm. Check acid to ensure acceptable conc. 5% HCi, acceptable conc. 4 - 6% 6% / 1-1/2% mud acid, acceptable conc. 5 - 7%HCI, 1- 1-1/2%HF Pump the following fluids at pressures below frac ( .54 psi/fi) and maximum rate of 1 BPM. Filter ali fluids to 3 ~ excluding diverter. Attempt to hold rate constant during treatment. a. 5 bbis OSR diverter in 3% NH4CI b. 35'bbis 5% HCI c. 70 bbls 6% / 1-1/2% mud acid d. 70 bbls 3% NH4Ci overflush RECEIVED ~i~ska.Oil & Gas Cons. Cornmissior~ ~,nCh0rag, a e. 35 bbls diesel postflush (leave tail end of diesel across perfs) f. Displace to within 500 ft of perfs with dead crude. NOTE: The Iow strength acids to be used in this program have freezing points above 0° F. Record rates & pressures during treatment and PFO after treatment. Pump 30 bbls of 2% NH4CI with 20 gals corrosion inhibitor down flowline to protect duplex pipe from potentially unspent acid. Line well up through the MPi high flow test separator and return well to production at _+ 2 MBOPD ASAP. This job is small volumes of weak acid and should be handled through the normal production train. 10/12/90 2-28/P-19 Mud Acid Stimulation 3 . . However, inform the board when the well is POP to monitor the 1st stage water out readings for indications of a possible plant upset. If the 1st stage readings drop off significantly, switch the well into the cretaceous disposal system. Pull several wellhead samples on the hour following bottoms up during 1st 24 hrs of flowback. Check the pH of each sample using pH paper capable of measuring pH values below 1.0. Visually inspect for emulsion. Retain samples for service company and Chemlink analysis. Select the lowest 3 pH sample and sent to town for analysis of corrosion inhibitor concentration. Allow well to cleanup for 3-5 days and obtain a well test at the pre- treatment wellhead pressure. Ensure a post treatment WC sample is obtained during the well test. ,Fluid 3% NH4Ci w/Diverter (5 bbis) 5% HCI (35 bbis) 6%HCI/ 1.5%HF (70 bbls) 3% NH4CI Overflush (70 bbis) Diesel Postflush (20 bbis) Additive Surfactant OSR Corr. lnhib. Surfactant Anti-sludge Non-Emuis Iron Control Mutual Solv Corr. lnhib. Surfactant Anti-sludge Non-Emuls Iron Control Mutual Solv FLUID SUMMARY Conc. D/S 0.2% F-40N 1#/gal J237 O.2% A-250 Per AP! 42 F-40N Per APl 42 W-35 Per APl 42 W-54 · 25#/Mgai L58 5%(10%D/S) U-66 0.2% A-250 Per APl 42 F-40N Per APl 42 W-35 Per APl 42 W-54 25#/Mgal L58 5%(10%D/S) U-66 Surfactant 0.2% F-40N Mutual Soiv 5%(10%D/S) U.66 BJ Titan NE-18 FLC-11 Ci-25 NE-18 Ferrotrol-210 Inflow 40 Ci-25 NE-18 Ferrotrol-210 Inflow 40 NE-18 Inflow 40 Halliburton Penn-88 Matriseal © HAl-85 Penn-88 AS-5 Fercheck A MusoI-A HAl-85 Penn-88 AS-5 Fercheck A Musoi-A Penn-88 MusoI-A GA 10/12/90 L STATE OF ALASKA ALAo,~A OIL AND GAS CONSERVATION COMMISS~JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate x Pull tubing Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1944' SNL, 2240' WEL, Sec. 36, T12N, R16E At top of productive interval 2310' SNL, 1930' WEL, Sec. 36, T12N, R16E At effective depth 2370' SNL, 1897' WEL, Sec. 36, T12N, R16E At total depth 2375'SNL, 1895'WEL, Sec. 36, T12N, R16E 5. Type of Well: Development _~_ Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-28/P- 19 MPI 9. Permit number/approval number 88-86 / 90-632 10. APl number 50- 029-21847 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10530 feet 10479 BKBfeet 10448feet 10397 BKBfeet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth BKB 92' 30" Driven 131' 2465' 13 3/8" 3687 c.f. Permafrost 2504' 9605' 9 5/8" 575 c.f. Class G 9644' 1144' 7" 517c. f. ClassG 9383'- 10527' 10114'- 10160', 10180'- 10200', 10216'- 10226' True vertical depth BKB 131' 2503' 9597' 9338' - 104 76' true vertical (Subsea) 10009'- 10055', 10075;- 10095', 10111'- 10121' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" 9.2# L-80 tailpipe to 9452' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 9 5/8" SAB Packer at 9339', 4 1/2" SSSV at 1555' Intervals treated (measured) Treatment description including volumes used and final pressure SEP 1 1 1990 Alaska 011 & Gas Cons. C0mm~ss~0~ 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1591 5425 3 0 2484 Not available due to shut-in for drilling 15. Attachments CoPies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil x Gas__ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //Y ~)-- '~~ Title Re,ervoir Development Coordl, ator Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ~~1~~ Endicott ~~)~ Production Engineering Depqr_t_ment --- -- - ...................... "', ....... 2.-2" ........', 5~'=;:.';. ~.,.': ". .... Alldl....~~l ......... P..e..rfor a tio n s DATE: 8/22190 WELL N~: 2-25/P-19 ADD PERFORATIONS R ¢EIVED BP EXPLORATION REP: LOVF_LAND~'.~-~ SEP 1 I 1990 SERVICE COMPANY: SO~ ~a$~ 0il & Gas Cons. G0mmi~ion /i~oliorage INOTE: INsURE";TH'~-~ "~h-L-£'"~i'i;J~'-a~A; "WEt& -H'-0-U-~,-'~.~§-"HhObUi~tiON" tiai~iil ARE KEPT FREE OF CJRUDE OIL, EOt, IIPMEflT LEAK8 OR TFIA~IH. CLEAN UP ANY! CRUIDEtH:Y._._D._.._.R=...A..ULla OIL LEAKIB.__~EI=._O,.R.E_ LEA¥1NG "rile ,,JO,,.B, ~.!T_E..'. ................... : ............ I 1345 RI0, Radio silence in effect. ...... 1'~-~ ....... '-' ...... i;~;t~ii--§§'V-f-~d;i~-~p.'~.~SSV i;-O-d~'~ ..... Well '~'"',hut-~ ~ruer, ' ...... 1510 ................ Pressure test iubrlcator to. ~,llhoa,d t6 l0 Make initial., t~e-m' ' at~b~_' ' . .............. ................................. ..... i62[._: ..... Opec ~i:~.~0n5. se~toductlo~ choke to 20,,, b.6.~.~l' .... 1630 Tagged bottom at I~51 MDBKB, Tie in to CBT dated 8117/88. All of tho d, pths Ii~t,d below ~e from the ope~ hole reference log, ............................ F~g=~....~;~9=[,,.p $ig ...... 1659 Ha~g gun gl~op shot at ~16 MDBKB, ,7oo s,oot g~d 0~ t,o;;~"i~'~i~' "~i022~" ~nfffi"""~a no~ ~n fob ~g ..... .... ...... -~..~!~ ............. 8I well ~)~_...p.OiL AIl shots fired. . ............... . ....... 1830 End radio sil¢nc, ........ . ~ 830, ~ 92_0 ........ ~,g:. ~O~2~.77~tW}i~'"~-g~6"~'L ~'"i~P =~>.~g, o~.~.......= o p=~g... PERFORATION SUMMARY: GUN ] N T ER YA_._L:(!)...I~.-,I~ CBL DEPTH ~ ~UBZONE Z0216-~0226 ~02.~.]0226 1 o 2Bl All intervals were shot using. 2 1/8" guns loaded at 4 spf, 0 degree phasing, oriented to low $~de with 6.5 gram charges. The de-;m log was on depth with the open hole reference log. STATE OF ALASKA AEAoKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 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 __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1944' SNL, 2240' WEL, Sec. 36, T12N, R16E At top of productive interval 2310' SNL, 1930' WEL, Sec. 36, T12N, R16E At effective depth 2370' SNL, 1897' WEL, Sec. 36, T12N, R16E At total depth 2375' SNL, 1895' WEL, Sec. 36, T12N, R16E 12. Present well condi'l~ion summary Total depth: measured true vertical 10530 feet 10479 BKB feet 5. Type of Well: Development x Exploratory __ Stratigraphic ~ Service 6. Datum elevation (DF or KB) KBE = 55 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-28/P- 19 MPI 9. Permit number 88-86 10. APl number 50- 029-21847 11. Field/Pool Endicott Oil Pool Plugs (measured) Effective depth: measured true vertical 10448 feet 10397 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured de_.p.th True vertical depth BKB 92' 30" Driven 131' 131' 2465' 13 3/8" 3687 c.f. Permafrost 2504' 2503' 9605' 9 5/8" 575 c.f. Class G 9644' 9597' 1144' 7" 517c. f. Class G measured 10114'- 10160', 10180'- 10200' 9383' - 10527' 9338' - 10476' true vertical (Subsea) 10009'- 10055', 10075;- 10095' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" 9.2# L-80 tailpipe to 9452' Packers and SSSV (type and measured depth) 9 5/8" SAB Packer at 9339', 4 1/2" SSS Vat 1555' 13. Attachments Description summary of proposal x Detailed operations program ~ BOP sketch x 14. Estimated date for commencing operation August 25, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas__ Suspended__ Service i~gne' I hereby certify that the foregoing is true and correct to the best of my knowledge. d . Title Reservoir Development Coordinator FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test__ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- Approved Copy Returi~ed Approved by order of the Commission .. Form 10-403 Rev 06/15/88 I Approval No. ~,~, ~'.~, ~ Commissioner ORIGII~II~ ,SIGNED BY SUBMIT IN TRIPLICATE BP Exploration Endicott Field Well 2-28/P-19 Additional Perforating Proposal In order to drain the oil in subzone 2B1, we propose to perforate the following additional interval. 10216' - 10226' MD (Ref. CBT 8/17/88) A lubricator will be installed and tested to 3000 psi for all well work. The SSSV will be reinstalled and tested after the pedorations are added. BASIC SYSTEM MAKEUP .-~~ BOWEN PACKOFF' ~SE SF_AL · FEOW'R~BE · FLOWLINE GREASE LINE FLOWLINE V. ALVE - . - GREASE . " L-----------~~'t GREASE PUMp' RISER : ~~___~ ~REASE RESERVO. BOP ,.t .... ~"~ ?' 'i ,i .... ~:', WELL 2-28/P-19 7/14/90 *DUAL BURST TDT LOG (TDT-P) 9650' - 10445' Run No. 1 Schlumberger WELL 2-:~4/P- 14 7/13/80 *PERFORATION RECORD 10650' - 11113' Run No. 1 Schlumberger WELL 2-58/S-09 *DGR/EWR/CNO/SFD 9928' - 10796' Sperry-Sun 5/28/90 Run No. 1 *DGR/CNO/SFD 12496' - 15350' Sperry-Sun Run No. 1 *EWR/DGR 12496' - 15350' Sperry-Sun Run No. 1 *CEMENT BOND LOG / .3o'-/¢' .-4-8640'-- 15156' Schlumberger 6/1/90 Run No. 1 · CEMENT EVALUATION LOG 10304' - 15174' Run No. 1 Schlumberger *GAMMA RAY-CCL 13874' - 14340' Schlumberger 6/4/90 Run No. 1 *COMPLETION RECORD 6/5/90 13800' - 14360' Run No. 1 Schlumberger *GR/CCL TCP CORRELATION LOG 13566' - 13950' Run No. 1 Schlumberger WELL3-05/O-29 6/18/90 *PERFORATING RECORD 12100' - 12550' Schlumberger Run No. 1 6/1/90 6/7/90 WELL 1-43/P-2§ *THERMAL DECAY-BORAX LOG (TDT-P) 13200' - 13828' Run No. 1 SCHLUMBERGER WELL 1-45/Q-26 *COLLAR LOG 13418' - 13891' Run No. 1 ATLAS WlRELINE SERVICES WELL 1-47/~-21 *HRS 10600' - 11299' HRS Run No. 1 WELL 1-49/P-21 *TEMPERATURE SURVEY 10800' - 11290' Run No. 1 CAMCO WELL 1-67/'!'-20 *COLLAR LOG 11097' - 11588' Run No. 1 ATLAS WlRELINE SERVICES *COLLAR LOG 11400' - 11710' Run No. 1 ATLAS WIRELINE SERVICES WELL 2-26/N-14 *PERFORATING RECORD 11650' - 12020' SCHLUMBERGER *TEMPERATURE LOG 11000' - 11800 CAMCO Run No. 1 Run No. 1 *CCL - GAMMA RAY LOG 10680' - 12100' SCHLUMBERGER Run No. 1 WELL 2-28/P-19 *PRODUCTION PROFILE 9900' - 10452' CAMCO Run No. 1 BP EXPLORATION March 14, 1990 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 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells Well Name Date 1-09J-18 2-12-90 1-41/O-23 2-18-90 1-49/P-21 3-1-90 1-67/T-20 2-3-90 2-26/N-14 2-7-90 2-28/P-19 2-24-90 2-52/S-14 1-2-90 3-17/J-30 2-27-90 4-04/T-26 12-30-89 4-42/P-38 2-13-90 4-46/N-39 12-29-89 5-03/SG09 2-20-90 If there are any questions regarding this data, please contact Jeanne Haas at 564-5225. Sincerely, ~:~e~nne L. Haas JLH Enclosures " RE -E ¥ MA 90 .0il.& Gas Cons. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 25, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs' Enclosed are Bottom Hole Pressure Reports for the following wells. Well Name Date 2-28/P-19 3-01/N-29 3-05/0-29 3-35/L-36 3-47/Q-35 08-16-89 08-21-89 08-19-89 08-2;1.-89 08-15-89 If there are any questions regarding this data, please contact Dave MacDonald at 564-4697. Sincerely, ,~eanne L. Haas JLH Enclosures cc' File: 76.13 v (~ 0ii & 6as C0n~ G0aai~iQD ' AnohoraOe WELL 2-46/Q-15 · '~~PCF LOG 10500'-11110' Run 1 ~ ATLAS WIRELINE SERVICES J' ~,a ~ ,r,~, ,--.. WELL 2-28/P-19 MPI *DIFFERENTIAL TEMPERATURE LOG 10000'-10440' Run 1 CAMCO WELL 3-'O 1/N-29 *STATIC TEMPERATURE SURVEY 12150,-12940' Run 1 CAMCO ~' WELl' 3-47/Q-35 · *DIFFERENTIAL TEMPERATURE LOG 9725'-11254' Run 1 CAMCO WELL 4-46/N-39 *CEMENT BOND LOG 12272'-12324' SCHLUMBERGER Run 1 '~,~.. WELL 4-46/N-39 *COMPLETION RECORD (POSITION TUBING) 11296'- 11758' Run 1 SCHLUMBERGER '~,,, WELL 4-46/N-39 · ~*CEMENT EVALUATION LOG 12272'-12345' Run 1 SCHLUMBERGER 1092/G N D ,WELL 3-49/J-40 *PRODUCTION FLUID SAMPLER 14420'- 14928' Run 1 SCHLUMBERGER ~,w *DIFFERENTAL TEMPERATURE LOG 14697'-14686' Run 1 CAMCO ~ WELL 4-18/$-30 *PRODUCTION LOG BUILD-UP 111,~ 11600' Run 1 SCHLoMBERGER WELL 5-01/SAG 7 '~ *TEMPERTURE SURVEY 11500'-12350' CAMCO Run 1 WELL 2-26/N- 14 *TEMPERATURE LOG 11000'-11812' CAMCO Run 1 WELL 2-28/P-19 *PRODUCTION PROFILE 9900'-10250' CAMCO Run 1 WELL 2-16/M-16 *INJECTION PROFILE 10305'- 11435' CAMCO Run 2 WELL 3-49 J-40 *PRODUCTION PROFILE 14600'-14920' CAMCO Run 1 1027/GD Standard Alaska Production Company ~ 900 East 8enson Boulevard,,'" P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION January 3, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the cased hole well logs run in the following Endicott well: WELL 2-08/K- 16 *PRODUCTION PROFILE 11700'-12050' Run No. 1 CAlVlCO WELL 2-28/P- 19, *PRODUCTION PROFII~E 9900'- 10250' Run'No. 1 CAMCO WELL 1-41/O-23.. *PRODUCTION PROFILE 11350'-11800' Run No. 1 CAMCO WELL 3-1 l/M-30 *PRODUCTION PROFILE 12700'-13200' Run No. 1 CAMCO Receiv~ Alaska .Oil .a Gas Cons. ': i~c/~oraqe Date Sincerely, ~llard A unit of the or,ginal Standard Oil Company Founded in Cleveland. Ohio. in 1870. Standard Alaska Production Company 900 East Benson BouleV~..~._~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 January 3, 1989 STANDARD ALASKA PRODUCTION Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs' Enclosed are Bottom Hole Pressure Reports for the following wells in the Endicott Reservoir: Well Name Date 2-08/K-16 2-28/P-19 12-10-88 12-07-88 If there are any questions regarding this data, please contact Loren Twyford at 564-4401. Sincerely, Jeanne L. Haas ILH A unit of the anginal Slandard Oil Company Founded m Cleveland. Ohto. ,n 1870 Standard Alaska Production Company qO0 East Benson ~oulevorc.~,,~-- PC). Box 196612 Anchorage, Alaska 99519-6612 907 .56!-.5111 October 20, 1988 STANDARD ALASKA PRODUCTION Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells in the Endicott Reservoir: Well Name Date 1-09/J-18 2-28/P-19 2-44/R-12 3-05/O-29 3-1 l/M-30 3-35/L-36 3-39/J-39 4-02/Q-28 4-26/0-34 10-10-88 09-27-88 08-30-88 10-10-88 09-27-88 10-09-88 09-12-88 07-26-88 09-18-88 If there are any questions regarding this data, please contact Loren Twyford at 564-4401. A unit of the original Standard Oil Company Founded ,n Cleveland. Ohio. in 1870. Sincerely, Jeanne L. Haas Standard Alaska Proauct~on Company PO ~o~ i96o'~ Anchorage, 41a s,<a 1907~ 561-5i~1 STANDARD ALASKA PRODUCTION October 7, 1988 John Boyle Alaska Oil and Gas Conservation Commission 3(3()l Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the cased hole well logs run in the following Endicott well: WELL 3-39/J-39 *Pump-In Temp. Survey Collar Log 13700'-14640' Run No. 1 Camco WELL 2-28/P- 19 *CCL LOG 9200'-10451' Run No. 1 Camco WELL 3-1 l/M-30 *CCL LOG 12300'-13403' Run No. 1 Camco Received By Sincerely, Date A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standard Alaska Production Company,~.~. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561~5111 51'ANDARD ALASKA PRODUCTION August 23,1988 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott well log information Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the cased hole well logs run in the following Endicott Well: Endicott Well 2-28/P-19 *Cement Evaluation Tool (CET) Run Date: 8-17-88 Run No. 1 9300' - 10452' Company' Schlumberger *Cement Bond Log (CBT) Run Date: 8-17-88 9300' - 10432' ~"~ Company' Schlumberger ' Sincerely, Jeanne L. Haas A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standard Alaska Production Company 900 East Bergson BouJeva~- PO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561 .5 I 11 STANDARD ALASKA PRODUCTION August 29, 1988 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott well log information Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the cased hole well logs run in the following Endicott Well: Endicott Well 2-28/P-19 '~'~ *Dual Laterolog MSFL Run Date: 8-13-88 Run No. 1 9300' - 10538' Company: Gearhart ~~*Spectral Litho-Density Compensated Neutron~r'rec~e~) Log Run Date: 8-13-88 Run No. 1 9645'- 10533' Company: Gearhai't *Formation Tester Run Date: 8-14-88 Run No. 1 Company: Gearhart A unit of the original Standard ali Company Founded ir~ Cleveland, Ohio, in 1870, Oil & Gas Cons, Commission gnch0ra~e Sincerely, Jeanne L. Haas Date ~ia~a _Oi~ 8, Gas Cons. comm~ss~o,~ STATE OF ALASKA ~" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,, 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of operator 7. Permit Number Standard Alaska. Production. COmpany 88-86 3. Address 3'. APl Number P. 0. Box 196612, Anchora~le, Alaska 99519-6612 50- 029-21847 ¢. 'Locatio'n of well at surface .... 9~ Unit or Lease Name" 1944' SNL, 2240' WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At Top Producing Interval 10. Well Number 2-28/P- 19 MPI 2310'SNL, 1930' WEL, SEC. 36, T12N, R16E ! VERIF~EDZ2.,,~.. 1:1. I~ield and Pool At Total Depth Endicott Field/Endicott Pool 2375' SNL, 1895' WEL, SEC. 36, T12N, R16E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 55.0 Feet . I ADL34633 . 12. D~.te SpUdded 13. Da{~ T'.D. Reached 14. Date comp., Susp. or Aband. 115. Water Depth,' il Offshore 116. No. of Completions 07-31-88 08-14-88 09-23-88I N/A feet MSL I One 1~'.' Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where $SSV set 1211' Thickness of Permafrost 10530'MD 10479'TVD 10448'MD 10342'TVD YES [] NO []I 1555 feet MD I. 14..66 22. Type Electric 'or Other Logs Run' DLL/MSFL, S. LD/CNL Corrected, Formation.. Teste. r, CRT, CBT 23. CASING, LINER AND C'EMENTING RECORD S~TT~NG DEPTH CASING SIZE WT. PER FT. GRADE TOP I BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED .... 30" Structural Drive Surface 131' Drive . 13-3/8" 68# NT-80 Surface 2504' 17- i/2" 3687 cuft Permafrost 9-5/8" 47# NT-80S' ' Surface 8348' 12-1/4" i 9-5/8'' , 47# NT95H 8348' 9644' 12-1/4" 575 cuft Cla.s..s G ....... 7" 29# SM-110 9382' 10527' 8-1/2" 517cu ft Class G .... !24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ...... interval, size and number) SIZE ' DEPTH SET (MDI .... PACKER SET (MD! 2-1/8" Western Atlas @ 4spf 4-1/2'' 12.6// 9451'MD 9339' 10114'- 10160' 10089'- 10052' w/3-1/2" ta/Ipi, pe 10180'- 10200' 10075'- 10095' 26. ACID, FRACTORE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13-3/8"X 9-5/8" Down Squeeze 13-3/8"x 9-5/8" annulus with 345 SX p. ermafrost followed bY. . . 115 bbls dry crude . . 27. PROD UCTION TEST Date First Productio'n IMeth0d ~f Ope'rat'ion (Flowing, gas lift, "etc,) September.23, 1988 I Flowin~t .. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHO~ESIZE IGAS-OIL RATIO TEST PERIOD I~ I 15iow"Tubing Casing Pressure cALCULATED OIL-BBL GAS-MCF WATER-BBL OiL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ ..... 28. CORE DATA Brief' description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chip~. ~iaska 0/1 & (~as Cons. C0r~missi0r~ ' ~nchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29, GEOLOGIC MARKERS/, 'r-,,,'r~MATION TESTS NAME Include interval tested, pressure data, ,~1 fluids recovered and gravity. ME. AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. HRZ 9,387' 9287' ITK 9645' 9543' ~oepk 9680' 9577' iktuk 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed.. 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". Form 10-407 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 1, 1988 at 0600 hfs Rig: Doyon #15 Well: 2-28/P- 19 (MPI) AFE # 717552 API: 50-029-21847 AFE Amount: Current Amount: 0600 Depth: 1641' Day: 1 48- Hour Ftg: 1534' Current Operation: Tripping. Accepted rig @ 2200 hours on 7/30/88; spud @ 0130 hours on 7/31/88. Drill & survey 17-1/2" hole to 1498'. Trip for Dyna-drill. Drill with motor to 1641'. Mud Type: Spud WT: 9.4 VIS: 120 PV: YP: FL: Solids: Temp: °F SURVEY MD ANGLE DIREGTIQN TVD SECTION COORDINATES DLS 2 936 .75 N81E 936 2 N1 E4 4 1562 2.75 S76E 1562 6 N9 El8 2.8 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 2, 1988 at 0600 hfs Rig: Doyon #15 Well: 2-28/P-19 (MPI) AFE # 717552 API: 50-029-21847 AFE Amount: Current Amount: 0600 Depth: 2520' Day: 2 24- Hour Ftg: 879' Current Operation: POH. Drill and survey 17-1/2" hole to 2520'. POH. Run and cement 13-3/8" casing; shoe @ 2504'. Mud Type: Spud WT: 9.8 VIS: 78 PV: YP: FL: Solids: Temp: °F SURVEY IVID /kNGLE DIRECTION TVD SECTION COORDINATES DL$ 6 2141 .75 S19E 2140 23 N3 E30 0.4 7 2491 .75 S25E 2490 27 S7 E32 0.1 STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT August 3, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-28/P-19 (MPI) AFE # 717552 API: 50-029-21847 AFE Amount: Current Amount: 0600 Depth: 3900' Day: 3 24- Hour Ftg: 1380' Current Operation: Drilling 12-1/4" hole. Install 13-3/8" x 5000 psi split speedhead. Nipple up & test BOPs - OK. Test casing to 3000 psi - OK. Drill cement & float shoe @ 2504' plus 10' of new hole. Perform fit to 11.7 ppg EMW. Drill & survey 12-1/4" hole to 3900'. Mud Type: FW/Gel SURVEY MD. 9 3027 11 3600 WT: 9.1 VIS: 37 PV: 8 YP: 20 FL: 25.4 Solids: 6.2 Temp: 60 °F /~NGLE DIRECTION TVD SECTION COORDINATES DL$ 0.1 S07E 3026 30 S10 E33 0.1 1.2 S64E 3599 37 S13 E41 0.2 ' STANDARD ALASKA PRODUCTION Rig' Doyon#15 Well: 2-28/P- 19 (MPI) Daily Drilling Report -- ENDICOTT August 4, 1988 at 0600 hrs AFE # 717552 API: 50-029-21847 AFE Amount: Current Amount: 0600 Depth: 5530' Day: 4 24- Hour Ftg: 1630' Current Operation: Drilling 12-1/4" hole. Drill 12-1/4" hole to 4207'. Trip for bit change. Drill 12-1/4" hole to 5530'. Mud Type: Ligno SURVEY MD 13 4173 15 4739 WT: 9.4 VIS:39 PV: 13 YP: 13 FL: 15.6 Solids:7 Temp: 72°F ANGLE DIRECTION TVD SECTION COORDINATES DLS 0.1 S18E 4172 46 S20 E46 0.1 0.3 S05E 4738 50 S23 E48 0.1 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 5, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-28/P-19 (MPI) AFE # 717552 API: 50-029-21847 AFE Amount: Current Amount: 0600 Depth: 7000' Day: 5 24- Hour Ftg: 1470' Current Operation: Trip for Dyna-drill. Drill & survey 12-1/4" hole to KOP @ 7000'. Mud Type: Ligno. WT: 9.6 SURVEY MD ANGLE 20 6162 1.4 23 6980 2.8 VIS: 39 PV: 14 YP: 11 FL: 7.9 Solids: 8 Temp: DIRECTION S65W N81W TVD 6161 6978 SECTION COORDINATES 47 S30 E36 17 S29 W3 88°F DLS 1.0 Daily Drilling Report -- ENDICOTT August 8, 1988 at 0600 hours STANDARD ALASKA PRODUCTION Rig' Doyon #15 k(ell' 2-28/P-19 (MPI) AFE# 717552 AFE Amount' API' 50-029-21847 Current Amount' 0600 Depth' 8400' Day' 8 72-Hour Ftg- 1400' Current Operation' Dynadrill to 7522'. Trip for BHA change. Drill & survey 12-1/4" hole to 8400'. Mud Type- Ligno )~T' 9.9 VIS' 39 PV' 17 YP' ll FL: 5.6 SOL' l0 Temp' 88 °F SURVEY MD ANGLE DIRECTION TVD SECTION 25 7260 6.4 S46E... 7258 27 28 7832 13.1 S53E 7819 136 30 8210 13.2 S46E, ' 8186 223 COORDINATES DLS S44 1~4 3.3 Sl08 E85 0.9 S165 E152 0.4 Rig' Doyon #15 klell' 2-28/P-19 (MPI) STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 9, 1988 at 0600 hours AFE# 717552 AFE Amount' API' 50-029-21847 Current Amount' 0600 Depth' 8852' Day' 9 24-Hour Ftg' 452' Current Operation' Tripping. Drill & survey 12-1/4" hole to 8852'. Mud Type' Ligno NT' 10.2 VIS' 38 PV: 18 YP' ll FL' 5.3 SOL' 14 Temp' 92 °F SURVEY MD ANGLE DIRECTION ~VD SECTION COORDINATES DLS 31 8404 12.4 S43E 8376 266 S196 E182 0.5 33 8782 11.6 S40E. 8746 344 S254 E234 0.5 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 10, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-28/P-19 (MPI) AFE # 717552 API: 50-029-21847 AFE Amount: Current Amount: 0600 Depth: 9610' Day: 10 24- Hour Ftg: 758' Current Operation: Drilling 12-1/4" hole. Drill and survey 12-1/4" hole to 9610'. Mud Type: Ligno SURVEY,. MI) 35 9150 WT: 10.2 ANGLE 9.1 VIS: 38 PV: 17 DIRECTION S38E TVD 9108 YP: 11 FL: 5.2 SECTION 408 Solids: 14 Temp: 92 °F CQQRDINATE$ DL$ S305 E274 0.6 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 11, 1988 at 0600 hfs Rig: Doyon #15 Well: 2-28/P-19 (MPI) AFE # 717552 API: 50-029-21847 AFE Amount: Current Ar~ount: 0600 Depth: 9654' Day: 11 24- Hour Ftg: 44' Current Operation: Testing BOPE. Drill 12-1/4" hole to 9654'. Run and cement 9-5/8" casing. Test BOPE. Mud Type: Ligno ~IJRVEY 36 37 38 WT: 10.2+ VIS:40 PV: 17 YP: 14 FL:5.2 Solids: 14 Temp: MD ANGLE DIRECTION ~ SECTION .COORDINATES 9340 8.1 S30E 9296 436 S329 E290 9538 7.3 S21E 9492 460 S352 E300 9654 7.1 S19E 9607 473 S365 E305 DL$ 0.8 0.7 0.2 STANDARD ALASKA PRODUCTION Dally Drilling Report .- ENDICOTT August 12, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-28/P- 19 (MPI) AFE # 717552 API: 50-029-21847 AFE Amount: Current Amount: 0600 Depth: 9722' Day: 12 24- HourFtg: 68' Current Operation: Drilling 8-1/2" hole. Test BOPE. RIH with 8-1/2" bit. Test casing to 3000 psi - OK. Drill out float shoe. Drill 8-1/2" hole to 9722'. Mud Type: Ligno WT: 9.7 VIS: 38 PV: 13 YP: 10 FL: 6.4 Solids: 10 Temp: °F ~URVEY MD /kNGLE DIRECTION .TVD SECTION COORDINATES DL$ STANDARD ALASKA PRODUCTION Dally Drilling Report -- ENDICOTT August 15, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-28/P-19 (MPI) AFE # 717552 API: 50-029-21847 AFE Amount: Current Amount: 0600 Depth: 10,530' Day: 15 72- Hour Ftg: 808' Current Operation: Circulating with 7" liner. Drill 8-1/2" hole to TD @ 10,530'. Run O.H. logs. RIH with 7" liner. Break circulation. Mud Type: Ligno SURVEY MD WT: 9.8 VIS: 38 PV: 9 YP: 8 FL: 5.6 Solids: 10 Temp' °F ANGLE. DIRECTION TVD SECTION. COORDINATES, DLS Daily Drilling Report -- ENDICOTT August 16, 1988 at 0600 hrs STANDARD ALASKA PRODUCTION Rig: Doyon #15 Well: 2-28/P-19 (MPI) AFE # 717552 API: 50-029-21847 AFE Amount: Current Amount: 0600 Depth: 10,530' Day: 16 24- Hour Ftg: Current Operation: Cleaning out 7" liner. Cement 7" liner shoe @ 10,527'. Clean out to liner top @ 9383'. Test lap to 3000 psi - OK. Clean out 7" liner to F/collar @ 10,448'. Mud Type: WT: 9.7 VIS: 39 PV: 12 YP: 10 FL: Solids: Temp: °F SURVEY MD ANQLE DIRECTION TVD, SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT August 17, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-28/P-19 (MPI) AFE # 717552 API: 50-029-21847 AFE Amount: Current Amount: 0600 Depth: 10,448' PBTD Day: 17 24- Hour Ftg: Current Operation: RU to mn tubing. Clean out 7" liner to F/collar @ 10,448'. Displace well with brine. Test 9-5/8" casing & 7" liner lap to 3000 psi - OK. Run C.H. logs. RU to run tubing. Mud Type: NaC1 ~,URVEY MD WT: 9.7 VIS: PV: YP: FL: Solids: Temp: cF ANGLE DIRECTION TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 18, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-28/P-19 (MPI) AFE # 717552 API: 50-029-21847 AFE Amount: Current Amount: 0600 Depth: 10,448' PBTD Day: 18 24- Hour Ftg: Current Operation: Moving rig to 2-68/S-17. Ran 4-1/2" tubing. N/U and test tree. Displace well with brine and diesel. Set packer and test - OK. Install BPV. Release rig at 0200 hrs on 8/18/88. Mud Type: NaC1 Brine .SURVEY MD WT: 9.7 VIS: PV: YP: FL: ANGLE DIRECTION TVD SECTION Solids: Temp: CF COORDINATES DLS GREAT I~END DIRF_~TION~ DRIr.~.ING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY m m mm m m mm mm m m mm m m mm mm m m m STANDARD ALASKA PRODUCTION COMPANY mmmm COMPANY 2-28/P-19 ~ ,mm.m. WELL NAME ENDICOTT LOCATION AL788-D23 SINGLE SHOT & MWD SURVEYS 8/22/88 JOB NUMBER,, TYPE SURVEY DATE NAME T I TLE S I GNATURE 490 FT 9654 FT m--mmmmmmmmmmmmmmmmmmmmmm mmmmmmmmmmmmmmmmmmm DEPTH INTERVAL FROM TO 7-31-88 8-10-88 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF. YOUR W~I.L WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, Ar.n COPIES OF THE SURVEY REPORT WIr.r. BE FORWARDED TO YOU ON WRITTEN REQUEST. /%r.r. SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL DRILLI~3, INC 8122/88 Client .............. : STANDARD ALASKA PRODUCTIC~'J CO. We ] 1 ................ : END I COT T 2-28/P- 1.~ Ve~tica] Section at.- S 45.88 E Mognet~c De¢l~nation- 31 deg S m~n E Datm f~]e nome ...... : B-MPI~D.DAT RECORD OF SURVEY (Welt ~ssumed vertical to MD of Computation- RADIUS OF CURVATURE Survey date- 8/8/88 Method ..... - SINGLE SHOT & ~wD . RKB Height.- 55.0 ft O.O! MEAS DR I FT TRUVERT SUBSEA SEC T I ON DEPTH DEPTH DIST DEPTH DG MN 0.00 -SS.O0 0 10 490.00 435.00 0 45 935.98 880.98 2 0 1480.82 1425.82 2 45 ].561.75 1506.75 o. DIRECTION RELATIVE COORDINATES ANGLE FROM WEL. L.-HEAD 0.00 N 0.00 E 0.3]. , N 70.00 E 2. ].7 : N 81.00 E 5.33 N 36.00 E 6.01 N 76.00 E 490 936 1481 1562 0.00 N 0.00 E 0.24 N 0.67 E 1.14 N 4.12 E .7.79 N 14.98 E 9.63 N 17.7]. E CLOSURE DISTANCE DG MN S 0.00 N 0 0 0 E 0.71 N 70 0 0 E 4.27 N 74 35 2 E 16.87 N 62 3]. 6 E 20.16 N 61 27 26 E DOG LEG deg/lO0 0.000 0.034 0.230 0.933 1763 214I. 2491 2742 3027 o 0 ].762 57 1707 57 0 45 2].40.45 2085.45 0 45 2490 42 o,.~ - ~.42 0 12 2741.42 2686.42 0 6 3026.4]. 2~71.4I 8.26 N 44.00 E 14.71 S 1.9.00 E 18.89 S 25.00 E 20.89 S 35.00 E 21.51 S 7.00 W 13.74 N '24.83. E 12.10 N 32..23 E 7.86 N 33.94 E 6.06 N 34.98 E 5.35 N 35.16 E 28.38 N 61 2 6 E 34.42 N 69 24 46 E 34.84 N 76 S7 47 E 35.50 N 80 I0 23 E 35.56 N 81 20 43 E 0.374 0.331 0.000 0.219 0.035 3307 3600 3884 ~53 4739 5023 5309 5594 5880 6162 6446 6726 6980 7152 1 0 3306.40 3251.40 I 0 3599.35 3544.35 0 54 3883.3]. 3828.31 O 42 4172.29 4117.29 0 18 4452.28 4397.28 O 18 4738.27 4683.27 0 24 S022.27 4~67.27 0 24 S308.26 5253.26 0 30 5593.25 5538.25 0 48 S879.23 S824.23 1 24 6161.18 6].06.18 3 12 6444.94 6389.94 3 0 6724.53 666~.53 2 48 6978.20 6923.20 3 24 7149.95 7094.95 23.88 N 8~.00 E 28.19 S 64.00 E 32.84 S 35.00 E 36.64 S 18.00 E 38.87 S 26.00 E 40.15 S S.O0 E 41.29 S 11.00 W 41.44 S 68.00 W 40.65 S 62.00 W 39.46 S_69.00 W 37.36 S 65.00 W 30.98 N 88.00 W 19.00 N 79.00 W 8.36 N 81.00 W 8.99 S 20.00 E 3.59 N 3¢.74 E 2.49 N 41.69 E 0.53 o~' 45.23 E 4.13 S 47.03 E 6.39 S 47.94 E 7.83 S ~.56 S 11.03 S 11.98 S 13.32 S 1S. 44 S 17.69 S 15.98 S ].3.75 S ].9.70 S 36.92 N 84 25 18 E 41.76 N 86 34 45 E 45.24 S 89 19 28 E 47.21 S 84 58 46 E 48.37 S 82 24 8 E 481~34 E '"'"';48 97 S 80 47 S7 E 48.~'.25 ;E ?."'/':,,49. ].9S 78 47 47 E 49,,.~3'~'E ....... :48.31 S 76 47 44 E 45.!90 E ~':"~.;';~46.57 S 75 S 35 E 4~.'~05 E ~ ...... .144.11 S 72 25 7 E 37.07 E- ::_~;',¢~0 16 S 67 23 18 E 26.00 E ....... 31.45 S SS 44 22 E 10.~8 E 1~.38 S 34 2~ ~ E 1.68 W 13.85 S 6 57 S1 W 6.5~ W 20.77 S 18 2~ 21 W 0.322 0.003 0.035 0.069 0_143 0.000 0.035 0.001 0.035 O.10S 0.213 O. 634 O. 072 O. 07_-o- 0 or- ENDICOTT 2-28/P- 19 8/22/88 RECORD OF SURVEY MEAS DRIFT' TRUVERT SUBSEA SECTION DEPTH DG MN DEPZH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 7260 6 24 7257.54 7202.54 7435 10 24 7430.63 7375.63 7642 ~2 48 7633.39 7578.39 ~832 13 6 7818.56 7?63.56 8020 13 42 8001.44 7946.44 C 8210 13 12 8].86.22 81.31..22 8404 ].2 24 8375.40 8320.40 8S92 12 0 8SS9.1~ 8S04.16 8782 II 12 8745.27 8~90.27 8962 I0 42 8922.00 88~7.00 9].50 9340 9S38 9654 P ? 9].07.18 90S2.18 8 36 9294.90 9239.90 7 42 9490..~0 ~43S.~0 7 12 9~0S.~2 9SS0.92 17.90 S 46.00 E 43.24 S S9.00 E 84.19 S S3.00 E 12~.44 S S3.OO E 169.83 S 49.00 E 214.00 : S 46.00 E 2S6.96 S 43.00 E 296.62 S 42.00 E 334.68 S 40.00 E 368.S9 S 37.00 E 400.~4 S 38.00 E 429.30 S 30.00 E 4S5.S9 S 21.00 E 469.12 S 19.00 E 27.37 S 1.61: W 42.90 S 18.~53 E 6~S.1~ S S3.12 E 91.7¢ S 87.12 E 119.20 S 120.97 E 149.0S S I53.5S E 179.70 S 183.67 E 208.99 S 210.S1 E 237.83 S 23S.S8 E 264.S8 S 25~.86 E 290.29 S 276.58 E 3~4.S7 S 292.9~5 E 339.88 S 305.03 E 35.-4. o1 s 31o. 18 E CLOSURE DISTANCE DG MN S 27.42 S 3 21. 39 W 46.77 S 23 28 15 E 84.84 S 38 45 30 E 12~.55 S 43 30 23 E ].69.83 S 45 25 24 E 2].4.00 S 45 S1 7 E 25~.~4 S 45 37 33 E 296.64 S 45 ].2 27 E 334.7S S 44 43 40 E 3~8.?S S 44 9 S E 400.~6 S 43 36 54 E 429.8~ S 42 S7 47 E 456.69 S 41 S4 2~ E 470.c47 S 41 13 27 E DOG LEE deg/106 2.79~ 2. 298 1.1~8 O. 158 0.341 O. 27,~ 0.418 0.214 O. 423 O. 284 0.825 0.304 0.462 0.432 ENDICOI'T 2-28/P- 19 DATA INTERPOLATED FOR EVEN 100 FEE1 OF:' SUBSEA DEPTH 8/22/88 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL. DEPTH DEPTH ~ DEPTH D]FF. CORRECT SS SS 0 0 0 1SS J. SS 100 0 0 255 255 200 0 0 355 355 300 0 0 455 455 400 0 0 SSS SSS SOO O~ 0 6SS 65S 600 0 0 7SS 7SS 700 0 0 855 855 800 0 0 955 955 900 0 0 10SS llSS 1255 1355 1455 1SSS ~1655 ~i?SS 1855 1955 2OS& 2156 225~ 2356 245~ 2556 2756 2856 10SS 1000 llSS llO0 1255 1200 13SS I300 ].455 1400 ISSS 1SO0 0 0 1655 1600 0 0 1755 1700 0 0 1855 1800 0 0 1955 1900 0 0 2055 2000 1 1 °lSS 2100 1 0 2255 2200 1 0 2355 2300 1 0 2455 2400 1 0 2SSS 2500 I 0 2655 2600 1 0 2755 2700 1 0 2855 2800 ! 0 2955 2900 1 0 RELATIVE COORDINATES FROM WELL-HEAD 0.01 N " 0.00 0.07 N 0.03 0.16 N 0.11 0.24 N 0.29 0.26 N 0.56 0.33 N 0.89 E 0.54 N 1.40 E 0.86 N 2.11 E 1.31 N 3.02 E 1.18 N 4.37 E 1.58 N 5.90 E 2.32 N 7_74 E -3.46 N 9.82 E 5.06 N 12.07 E 7.17 N 14.39 E ].0.64 N 15.89 E 11.16 N 21.60 E 13.54 N 24.65 E 16.3]. N 26.29 E 18.98 N 26.16 E 20.70 N 24.68 E 11.92 N 32.29 E 10.70 N 32.74 E 9.48 N 33.22 E 8.28 N 33.75 E 7.17 N 34.28 E G.42 N 34.72 E 6.02 N 35.01 E S.80 N 35.22 E S.~8 N 35.44 E ENDICOTT 2-28/P- 19 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTtt MEAS. DEPTH 3056 3156 3256 ~3356 ~3456 3556 3756 3~56 4056 4256 4456 4556 ,4656 4856 S056 5156 5256 S356 S456 SSS6 S656 S?56 S856 5~56 TRU VERT SUB SEA MD-TVD DEPTH ~ DEPTH DIFF. 305S 3000 3155 3100 1 3255 3200 1 3355 3300 1 3455 3400 3SSS 3500 3655 3600 1 3755 3700 1 3855 3800 1 3~SS 3~00 1 4055 4000 I 4155 4100 1 4255 4200 1 4355 4300 1 4455 4400 1 4SSS 4500 I 4655 4600 1 4755 4700 1 4855 4800 1 4~SS 4~00 1 SOSS SO00 1 SISS S100 1 S2SS S200 1 S3SS S300 S4SS S400 I SSSS SSO0 S6SS S600 STSS S700 SSSS 5800 S~55 S~O0 VERTICAL. CORRECT RELATIVE COORDINATES FROM WELL-HEAD S.28 N 3S.IS E 4.71 N 35.34 E 3.91 N 36.09 E 3.64 N 37.59 E 3.?4 N 39.31 E 4.52 N 40.~S E 2.11 N 42.57 E 1_68 N 44.1.~ E 1.SS N 45.81 E 1.4]~' S 45.85~ E 2.45 S 46.85 E 3_32 S 47.83 E S.O1 S 47.33 E S.83 S 47.67 E 6.41 S 47.95 E 6.86 S 48.21 E 7.28 S 48.52 E 7.92 S 48.35 E 8.48 S 48.43 E 9.08 S 48.S~ E 9.78 S 48.22 E 10.47 S 48.28 E 3.1.10 S 48.58 E 11.16 S 46.72 E 3.1.47 S 46.03 E 3.1.83 S 45.30 E 12.26 S 44. SO E 12.81 S 43.57 E 13.49 S 42.51 E ].3.75 S 40.~? E 8/22/88 ENDICOTT 2-28/P-19 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 8/22/88 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL. DEPTH DEPTH.~. DEPTH DIFF. CORRECT 6056 6iS6 6256 ' o4S6 6556 6656 6757 6857 6957 7057 7157 7257 7359 7460 7562 7664 ~767 7869 7972 8075 8178 8281 8383 8485 8588 8690 8792 8894 8996 6055 6000 6155 6].00 6255 6200 6355 6300 6455 6400 6555 6500 ].~ 0 6655 6600 1 0 6755 6700 2 1 6855 6800 ~_o 0 6955 6900 2 0 7055 7000 2 0 7155 7100 2 0 7,_5~ 7200 2 0 7355 7300 4 7455 7400 S 1 7SSS 7500 7 2 7655 7600 ? 2 7755 7700 12 3 7855 7800 ].4 2 7955 7900 17 3 8055 8000 20 3 8155 8100 23 3 8255 8200 26 3 8355 8300 28 2 845Ei 8400 30 o 8555 8500 33 3 8655 8600 35 2 8755 8700 37 8855 8800 39 2 8955 8900 41 2 RELATIVE COORDINATES FROM WELL-HEAD 14.47 S " 39.25 E 15.38 S 37.21E 16.81 S 34.65 E 19.26 S 31.46 E 17.67 S 2S.44 E ].7.67 S ].9.93 E 17.97 S 14. SS E ].5.68 S 9.41 E ].4.76 S 4.37 E 13.93 S 0.55 W :!.4.90 S 5.30 W 19.99 S 6.48 W 27.17 S 1.80 W 35.72 S 8.22 E 45.22 S 22.54 E S4.84 S 40.04 E 69.12 S 57.04 E 82.92 S 75.36 E 96.87 S 93.97 E 110.56 S 113.43 E 127.64 S 130.83 E 142.75 S :1.49.29 E 160.01 S 165.12 E 175.12 S 181.84 E 192.36 S 195.57 E 207.89 S 223.74 S 239.30 S 254. O0 o'~ 269 48 ~ 210.4:1. E 224.03 E 236.81 E 249.60 E 260. S~ E ENDICOTT 2-28/P-17 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 8/22/88 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH :. DEPTH DIFF. CORRECT ~0~7 ~1~8 9300 O1 9603 90SS 9000 42 1 91SS ?100 43 1 92SS 9200 4S 2 ~35S ~300 4G 1 94SS 9400 47 1 9SSS ~SO0 48 " 1 RELATIVE COORDINATES FROM WELL-HEAD 283.48 S 296.22 S 307.77 S 322.20 S 333.83 S " 271.29 E 281.39 E 29 ~.. 86 E 297.61 E 30S. 79 E 347.79 S 308.].6 E ENDICOTT 2-28/P- 19 DA1A INI'ERPOLATED FOR EVEN 3.000 FEET OF MEASURED DEPTH MEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH I000 3.000 94S 2000 3.999 1.944 3000 2999 2944 4000 3999 3944 SO00 4999 4944 ~000 5999 S944 7000 6998 ~943 8000 798~ 7927 9000 8959 8904 RELATIVE COORDINATES FROM WELL-HEAD 1.32 N S.02 E 3.9.~0 N 2S.62 E S.86 N 3S.$3 E 1.90 S 46.31 E 9.37 S 48.68 E 14.0S S 40.2S E 13.71 S 2.67 W 11.4.18 S 1;1.8.8S E 270.3.3 S 263.. OS E 8/22/88 5O 5O tO0 t50 :~00 ~0 3OO 35O 4OO ,150 §00 5,5O 600 65O Hanker' Identification ~ ~D D~RT ~J K~ 0 0 0 Eli TD 96,54 9606 469 HORIZONTAL VIEW STANDARD ALASKA PRODUCTION CO. ENDICOTT 2-28/P-t9 CLOSURE: 47t ft S 4t.2 E DECLINATION: 3t.08 deg E SCALE: t inch = I00 feet DRAWN: 8/22/88 §0 0 §0 ~00 t50 300 250 300 350 400 4§0 §00 550 600 ~00 i800 2400 3000 3600 4200 4800 54OO 6000 6600 720O 7800 8400 go00 9600 ~0200 i0800 -600 VERTICAL SECTION STANDARD ALASKA PRODUCTION CO. ........ ENDICOTT 2-2B/P-19 SECTION AT S 45.88 E ............. TVD SCALE' 1 inch = i200 feet OEP SCALE ' t inch = i200 feet .......................... DRAWN ' 8/22/88 ~arker Identification ~ TVD DEPRT ~ KOP 0 0 0 ......... BJ TD 9~4 9606 469 _. . ...... r. , 0 600 t200 tOO0 2400 3000 3600 4200 4800 5400 6000 6600 DepaPtuPe $UB.$URFACE DIRECTIONAL ~URVEY ~-~ UIDANCE F~ONTINUOUS FflOOL Company STANDARD ALASKA PRODUCTION COMPANY W~)! N~&11~ 2-28/P-19MPI (1944' SNL~2240' WEL~SEC36~T12N,R16E) F)~)d~Loc~t~o¢l ENDICOTT, NORTH SLOPE. ALASKA Job Reference No. 72897 SALAZAR SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR STANDARD ALASKA PRODUC'TION CO. 2-28/P-19 MPI ENDICOTT ,NORTH SLOPE,ALASKA SURVEY DATE: 17-AUG-88 ENGINEER: S. SALAZAR METHODS OF COMPUTATION TOOL LOCATION: TANGENTI.~L- AVERAGED DEVIATION AND AZIMUTH INT~RPOL. aT!ON: LiN~&R VERTICAL SECT:ON: HOoIZ. OIST. PROJECTED ONT:O.A TARGET AZIMUTH OD SOUTH ~8 D~G DO NJN E~ST , ' ,' CSMPUT~TIgN D~TE: 21-AUg-88 STANDARD ALASKA PROOUCTZON CO. 2-28/P-19 MPI ENDICOTT NORTH SLOPE,AL~SK~ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASUR DEPT TqU? SU~-SEA CgURS: ED VERTICAL VERTICAL DEVIATION ~ZIMUTH H DEPTH gEPTH DEG MIN DEG MIN 0.00 I00.00 200.00 300.90 400.00 500.00 600.00 '?00.00 BO0.O0 909.00 0 .00 -55.00 0 0 N 0 0 100.00 45.00 0 7 W 36 9 200.00 14q. O0 0 5 S v5 3~ 300.00 ~5.00 0 9 S 77 17 400.00 345.00 0 13 S 5r)0.o~ ~4~.00 0 15 S 600.03 54S.00 0 19 S ~2 17 699.9~ 5~',.99 0 24 S 83 53 799.9'~ 74~. ~9 0 25 S ~99.~ ~44.~q 0 29 N 34 KELLY 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 .00 .DO .00 .00 .00 .00 .00 .00 .00 .00 ME.~SUPED DEPTH 2000.00 2100.00 2200.00 2300.00 2~00.00 2500.00 2600.00 2700.00 2800.00 2900.00 VERTICAL DOGLEG RECTANGULAR SECTION SEVERITY NORTH/SOUTH FEET OEG/IO0 FEET 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 0.00 0.00 0.03 0.30 -0.02 0.17 0.20 0.07 O.:~F 0.03 0.78 O. 10 .ls o.o? 1.50 0.17 2.11 0.10 2.59 0.10 999.99 944.99 0 29 N 69 51 E 1099.g~ 1044.98 0 30 N 73 46 E 1199.98 1144.98 0 42 N 70 18 E 1299.95 1244.96 1 33 N 56 49 E 13~9.91 1344.91 1 48 N 50 2'3 F 1499.85 1~44.36 1 55 N 68 39 E 1599.75 1~44.75 3 3 S 62 32 E 1699.64 1644.6~ 2 21 5 49 31 E 1799.57 1744.57 1 53 S 45 47 ~ 1899.53 1'34&. 53 I 22 S 43 ! E 0.00 'i 0.04 N 0.17 N 0.07 N 0.03 ~4 0.05 S 0.12 S 0.20 S 0.25 S 0.24 S 2.94 0.06 0.03 S 3.25 0.06 0..2~ 3.61 0.39 0.56 N 3.96 1.11 1.38 N 4.05 0.2! 3.2,4 N 4.09 3.19 5.18 N ]'.61 1.30 4.19 N 12.17 0.77 1.44 N 15.85 0.60 1.09 S 18.63 0.24 3.08 S 20.~0 0.32 4.69 22.38 0.15 5.85 23.75 0.10 6.78 25.13 0.09 7.7B 26.53 0.02 8.94 27.88 0.35 10.10 28.65 0.37 10.75 2~.96 0.31 ;11.10 29.15 0.12 11.47 29.36 0.09 11.84 19)9.51 116~+.51 1 4 S 42 26 2099.49 2044.49 0 47 S 45 29 E 2199.4i~ 2144./~ 0 47 S 48 24 F 2299.4~, ~4~_ .47. 0 2399.45 2344.46 0 249q.,.4~,., 244&. 4~, 0 4~ S 2599.45 2=q44.%5 O 2699.4,5 2{44.,;5 0 12 S 21 4 W 2799.45 2744. ~c 0 I 4 S 23 17 W 2899.45 2~44.~5 0 13 S 3 5~ W DATE BUSHING OF SURVEY: ELEVATION: PAG;E 1 17-AUG-68 55.00 FT ENGINEER: S. SALAZAR 2999.~,5 2~44.45 0 6 S 8 43 E 3099.45 3044.~5 0 7 S 41 25 E 31')9.45 3144.45 0 !7 S 56 19 ~ 3299.44 3:~44.44 0 43 S T3 0 5 3399.43 334&.43 0 52 S 84 5 5 3499.42 3444.42 0 56 S 74 39 E 3599.40 3544.40 1 ! S 69 5~ E 3699.39 364~.39 0 57 S 64 1T E 3799.38 3'/44.~8 0 55 S 54 36 E 3899.36 3344.36 0 56 S 50 42 ~ COORDINATES HORIZ, PARTURE FAST/WEST DIST. MUTH FEET FEET: G MIN 29.60 0.06 29.75 0.16 30.11 0.27 30.89 0.61 31.95 0.29 3.3.18 0.32 34.65 0.06 36.22 0.18 37.72 ,0'07 39.30 0'16 , , 0.00 0.1l 0.18 o.41 0.75 1.18 1.69 2 3.05 3.84 4.66 E 5.48 E 6.44 E 8.04 E 10.48 E 12.94 5 17.33 E 21.19 E 23.92 E 25.87 E 0.1 0 E 0 3 E 0-25 :,47 32 E 0.42 t,.~80 11 E 0.76: 8 5 E 1.18 , 7 40 E 2 3.0'6 :.'::S 85 5 E 3.85 S 85 28 E 4.66 S 89 38 E 5.49 N 87 31 E 6.47 N 85 4 E 8.16 N 80 13 E 0.97 N 72 48 E 3,9~ N 6~J 12 E 7,83 N 76 24 E 1.24 N 86 7 E 3.95 S 87 23 E 6.06 $ 83 12 E S 27.34 E S 28.4 3 E S 29.46 E S 30.40 E S 31.20 E S 31.92 E S 32.33 E S ' 32.39 E S 32.23 E S 32.10 E 12.16 S 32.09 E 12.31 S 32.16 E 12.54 S 32.43 E 12.91 S 33.23 E 13.11 S 34.66 E 13-43 S 36.23 : 13.97 S 37.90 E 14.68 S 39.53 E 15.49 S 40.92 E 16.47 S 42.21 E 27.73 S 80 15 29.02 S 78 22 30.23 S 77 2 31.38 S 75 38 32.46 S 74 1 33.48 S 72 26 34.07 S 71 36 34.24 S 71 5 34.22 S 70 24 34.22 S 69 44 34.3,;? S 69 15 E 34.43 S 69 3 E 34.77 S 68 51 E 35.64 S 68 46 E 37.06 S 69 16 E 38.64 S 69 39 E 40.39 S 69 45 E 42.17 S 69 37 E 43.75 S 69 16 E 45.31 S 68 40 E E E E E E E STANDARD ~L~SKA PROOU£TION CO. 2-28/P-19 ENDICOTT NORTH SLOPE,ALASK~ COMPUTATION D~TE: 21-AUG-S8 INTERPOLATEO VALUES FOR TRU: SU~-SEA MEASURED V2RTICAL VERTICAL DEPTH D=PTH DEPTH 4000.00 3999.35 4100.00 4099.33 4200.00 4199.32 4300.00 4299.31 4400.00 4399.31 4500.00 4499.31 4600.00 ~599.30 4700.00 4699.39 4800.00 47')9.3n 4900.00 ~899.39 5000.00 4999.30 5100.00 5099.29 5200.00 5199.29 5300.00 5299.29 5400.00 5399.29 5500.00 5499.23 5600.00 5599.2~ 5700. O0 $6 99.2 !3 5800.00 5799.2? 5900.00 5899.26 6000.00 5999.24 6100.00 6099.22 6200.00 6199.19 6300.00 6299.16 6400.00 5399.07 6~00.00 ~499.93 6600.00 6598.76 6700.00 6698.5<) 6800.00 6798.44 6900.00 ,5898.29 7000.D0 6998.1T 7100.00 1098.11 7200.00 1197.96 7300.00 7297.45 7400.00 7396.4B 7500.00 7494. 75 7600.00 7592.33 7700.00 7639.92 7800.00 7787.45 7900.00 78B4.8'7 EVEN 100 3944.35 4944.33 4144.32 4244.31 4344.31 4444.~1 4544.30 4644.30 4744.30 4a44.30 COURSE VFRTICAL DEVIATION AZIMUTH SECTION DIG MIN DiG M!N FFET 4~44.30 5044.29 514.4.29 5.244.29 5~44.29 5444.28 5344.~ 5544.2~ 5'744.27 5~44.26 0 58 S 41 17 E 0 57 S 37 44 0 46 S 26 32 0 36 S 24 12 F 024 S 17 1~ E 0 24 S !8 22 F. 0 23 S 022 S 020 S 4 57c 5944.24 6944.22 6t44.19 6344.16 6344.07 6443.93 g ,5l, .'3. '?~ 6643.59 6B43.~9 0 25 S 2 54 W 0 18 S 36 48 W 0 25 S 71 55 W 0 25 S 72 34 W 0 25 S 65 17 W 0 27 S 72 31 W 0 26 S 70 49 W 0 36 S 74 53 W 0 41 S 75 10 W 0 53 S 75 44 W 6943.17 7043.11 7142.96 7242.46 7341.49 7439.75 7~37.~8 7634.92 7732.45 7S29.!~7 2 2'9 N 85 38 W 1 48 S 29 26 W 4 ~3., S 24 57 E 6 43 S 48 33 E 9 19 S ,61 22 E 11 5~ S 55 25 F: 12 42 S 53 4'3 E 12 44 S 53 6 E 12 51 S 52 3B E 1~ 15 S S1 13 E 40.97 42.70 44.11 45.37 46.21 46.92 47.54 4~. 13 48.68 49.23 49.~4 50.26 50.20 49.93 49.67 49.48 49.29 4~.92 48.50 47.90 47.30 46.93 46.42 45.38 42.97 39.53 35.80 31.99 28.12 24.29 29.90 19.72 24.16 33.94 47.11 64.54 85.40 106.73 128.18 150.13 FEET OOGLE SEVER OEG/I PAGE 2 D~TE OF SURVEY: 17-~UG-88 KELLY BUSHING ELEVATION: 55.00 FT OF ME~SURFD DEPTH G RECTAN ITY NOPTH/ O0 0.29 0.36 0.11 0.32 0 0.08 0.06 O .0~. 0.15 0.22 0.13 0.49 0.32 0.14 0.43 0.11 0.37 0.33 0.23 0.17 0.51 0.33 0.31 1.21 0.96 0.37 0.38 0.30 0.56 0.41 ENGINEER: S. SALAZ~R 1.26 3.30 3.3'9 3.77 2.71 1.75 0.30 0 0.30 0'62 GULAR COORDINATES SOUTH FAST/WEST T FeET 17.6~ S 43.42 E 19.00 S 44.48 E 20.20 S 45.23 E 21.~7 S 45.79 E 22.19 S 46.11 E 22.8B $ 46.39 E 23.43 S 46.64 E 24.1~ $ 46.7~ E 24.80 S 46.82 E 25.48 S 46.86 E 26.25 S 46.87 E 26.88 S ~6.75 : 27.25 S 46.21 ~ 27.45 S 45.52 E 27.65 S 44.87 E 27.97 S 44.16 E 28.33 S 43.41 E 28.59 S 42.50 E 28.94 S 41.39 E 29.27 S ~0.04 E 29.87 S 38.32 E 30.91 S 36.45 E 31.93 S 34.36 E 32.65 S 31.79 E 32.79 S 27.79 E 32.77 S 22.34 E 32.65 S 16.53 E 32.32 S 10.8~ E 31.7'7 S 5.38 E 31.33 $ 0.17 W 30.91 S 5.07 W 31.86 S 8.12 W '36.92 S 7.33 W 44.72 S 1.42 W 52.20 S 10.28 E 62.06 S 25.83 E 74.66 S 43.4,6 E 87.82 S 61.11 E 101.15 S 78.75 E 115.00 S 96.55 E 53.72. S 60 44 E 53.93 S 60 6 E 53.64 S 59 28 E 53.15 S 58 54 E 52.70 S 58 21 E 52.28 S 57 38 E 51.83 S 56 52 E 51.22 S 56 4 E 50.50 S 55 2 E 49.59 S 53 49 E 48.59 S 52 47.79 S 49 46.91 S 47 45.58 S 44 42.96 $ 40 39.65 S 34 36.60 S 26 34.10 S 18 32.22 S 9 31.33 S 0 31.33 S 9 32.88 S 14 37.64 S 11 44.74 S 1 48 W 53.21 S 11 B E 67.22 S 22 36 E 86.38 S 30 11 E 106.99 S 34 50 E 128.19 S 37 54 E 150.16 S 40 0 E 4 E 41 E 5 E 16 E 16 E 36 36 E 18 ~ 18 W 13 ~ Cg~PtJT AT I .'IN STANDARD ALASKA P?ODUCTION 2-28/P-19 ENDICDTT NORTH SLOPE,ALASKa CO. INTERPOLATE9 VALUES MEASUR DEPT T VER D RUF TIC~L =PTH D~TE: 21-AUG-88 8000.00 8100.90 8200.00 8300.00 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 7932.13 8079.36 9176.67 B274.09 B371.62 3459.23 8567.05 9664.95 ~752.9~ ~861.14 PAGE 3 DATE 3F SURVEY: 17-AUG-88- KELLY ~USHING ELEVATION: 55.00 FT 9000.00 8959.49 9100.00 9058.09 9200.00 9155.B¢ 9300.00 9255.69 9400.00 9354.~6 9500.00 9453.76 9600.00 '9552.95 9700.00 9652.24 9800.00 9751.57 9900.00 9851.0~ FOR EVEN 100 FEET OF MEASURED DEPTH SU~-SE~ COURSE VERTICAL VFRTTC~L DEVIATION ~'ZIMUTH SECTION OEPTH DEG MIN DEG MIN FEET 10000. [0100. 10200. 10300. 1O400. 10500. 10530. O0 9950.52 O0 19050.15 O0 101~9.85 O0 102~9.55 O0 103~9.2a O0 104~9.03 DO 10478.95 7~27.13 8024.36 8121.67 8219.08 9316.62 ~41~.28 8512.96 860q.~5 8707.99 8~06.14 13 33 S 49 29 _F 13 24 S /,7 57 E 13 12 S 46 38 E 12 53 S 45 6 E 12 34 S 43 5¢ E 12 16 S 42 40 E 11 57 S 41 29 E 11 34 S 40 19 ~ 11 9 S 3g 17 ~ I0 48 S 38 23 E 8904.49 9003.09 9101.84 9200.69 9299.66 9398.76 949,7.95 9597.24 9696.57 9796.90 95-8 S 38 1] E 9 20 S 38 Z/, E 8 51 S 36 33 E 8 2~J S 33 5 E 8 5 S 29 50 E 7 27 S 24 47 E 7 5 S 20 51 E 6 39 S 21 30 E 6 28 S 23 2~ E : 54 S 25 46 ~ ENGINEER: S. SAL~ZAR 9895.52 5 11 S ?.6 13 E 9995.15 4 39 S 32 14 E 10094.85 4 27 S 37 1~ : 10194.55 4 18 S ]6 22 ~ !_.0Z94.28 4 3 S 36 50 E '!03g4.03 4 3 S 36 50 E 10~27.~5 4 3 S 36 50 5 OOGLEG R=CTANGULAR SEVERITY NORTH/SOUTH DEG/IO0 :EST C30RDINATES HORIZ. DEPARTURE E~ST/WEST DIST. ~'" ~ZIMUTH FEET FEET DEG 172.93 195. '97 218.76 241.17 263.14 28~.56 305.50 345.58 364.73 0.44 1 29.89 0.37 145.)4 0.44 160.96 0.38 176.69 0.49 192.43 0.42 208.0'7 0.38 223.64 0.47 239.07 0.37 254.19 0.68 269.11 S 114.42 S 131.97 S 1~,8.91 S 165.11 S 180.58 S 195.)2 S 209.37 S 222.74 S 235.34 S 2~7.34 173 10 196:]2 : .~ 1422 EE 219.2~::~ 46 E 241.83.1 3 E 263.89 10 E 285.~8.. 11 E 306.3S.,::!'i: ~ 6 Ef 326 . 346.4! i2 47 E 365.5I S 42 35 E 382.~2 399.50 415.33 430.33 444.~9 ~57.60 469.T7 481.06 492.21 502.56 0.88 283.33 0.45 296.41 0.75 308.90 1.76 3Z1.22 0.87 333.40 0.80 3~5.30 0.59 357.01 0.42 368.15 0.97 378.87 0.41 388.55 S 258.53 S 268.88 S 278.60 S 287.23 S 294.68 S 300.81 S 305.67 S 309.$2 S 314.29 S 318.76 E 383.55 S 4Z 22 E E 400.20 S 42 12 E E 415.98 S 42 2 E E 430.91 S 41 48 E E 444.96 S 41 28 E E 457.95 S 41 3 E E 469.99 S 40 34 E E 481.17 S 40 4 E E 492.26 S 39 40 E E 502.58 S 39 21 E 512.11 520.40 528.29 536.01 543.24 550.32 552.44 0.97 397.37 0.75 404.80 0.25 411.21 0.39 417.37 0.00 423.19 0.00 428.86 0.00 430.56 S 323.05 E S 327.05 E S 331.66 E S 336.32 E S 3t, O. 62 E S 3~4.86 E S 346.14 E 512.12 S 39 6 E 520.40 S 38 56 E 528.29 S 38 53 E 536.01 S 38 51 E 543.24 S 38 49 E 550.32 S 38 48 E 552.44 S 38 47 Ei.~, STANDARD ~L~SKA P~O3UCTION 2-28/P-19 ENDICOTT NORTH SLDPE,ALASK,~ CC. COMPUTATION INTEPPCLATED VALUES FOR EVEN TRU= SUb-SE MEASURED VERTTC~L VERT[C DEPTH DEPTH OEPT 0.00 0.00 -ES. 1000.00 9)9.99 ~44. 2000.00 1999.51 1)44. 3000.00 2999.45 2~, 4. 4000.00 3999.35 ~g44. 5000.00 49q9.30 4944° 6000.00 59)9.2¢. 5~44. 7000.00 6998.17 69~3. 8000.00 79~2.1~ 7~27. 9000.00 '~959.4~ ~04. 10000 O0 q950 5" . - o ~. , . 10530.00 10478.95 1042~. ~ COURSe VERTIC &t DEVIATION ~ZI'~UTH SECTI 'H DEG MIN DEG M[N FEE O0 0 0 N 0 0 E O. 99 0 29 N 69 5! F 2. 51 ! 4 S 42 25 = 20. 45 0 6 S 8 4 ~ E 29 ~5 0 58 S 41 17 ~- 40. ~0 0 25 ~ 2 5~ W 49. ~.4 1 12 S ~5 3:J W 4?. 17 2 29 N ,~5 38 W 20. lB 13 3~ S ~9 20 ~ 171. 49 9 58 S 3~ 13 E 382. 52 5 11 S 26 13 E 512. 95 4 3 S 36 50 E 552. 21-aUg-88 KELLY DaTE OF SURVEY: BUSHING ELEVATION: ENGINEER: PAGE ~ 17-A UG- 88 ' :~::'~ 55°00 FT $. SALAZAR 1000 FEET OF MEASuRFo OEPTH ~t DOGLEG RECTaNGULaR DN SEVERITY N3RTH/S3UrH T OEG/IO0 FE~T O0 0.00 0.00 N )4 0.06 0.03 S 80 0.32 4.69 S 60 0.05 12.16 S 97 0.29 17.64 S 84 0.13 26.25 S 30 0.51 29.8~ S 90 1.2~ 30.91 S 93 0.44 1 ~-9.99 S 82 0.8'~ 2~3.33 S 11 0.97 44 0.00 COORD~rN &TES H E~ST/WEST DI FEET FE 0.00 E 0 4.66 E 27.3~+ E 27 32.09 E 34 ~3.42 E 46 ~6.8T ~ 53 38.32 E 48 5.07 W 1 14.42 E 173 258.53 E 383 391.31 S 3?3.05 E 512 430.56 S 3e, 6.14 E 552 .1Z S 39 6 E .44 S 38 47 E STANDARD .~,L~SKA PoOOUCTTON 2-28/P-19 MPI ENDICOTT NORTH SLOPE,ALASK~ CO. COMPUTATION TRU= MEASURED VERTICAL DEPTH DEPTH INTERPOLATFD VALUES FOR SU~-SE VERTIC gEPT 0.00 0.00 -55. 55.00 55.00 O. 155.00 155.00 100. 255.00 255.00 200. 355.00 355.00 300. 455.00 455.00 400. 555.00 555.00 '~00. 655.00 655.00 500. 755.01 755.00 700. 855.01 855.00 ~00. ~ COURSE ~L DEVIATION AZIMUTH H DEG MIN DEG O0 O~ 0 N 0 g O0 0 10 N BO 37 O0 0 5 N 24 57 O0 0 9 S 6'~ 18 90 0 12 S 93 5 O0 0 14 S 79 36 O0 0 17 S 83 O0 0 21 S 81 77 O0 0 25 S ~35 2~ 'JO 0 27 N 97 53 955.01 955.0'9 900. 1055.02 1055.00 1000. 1155.02 1155.00 1!00. 1255.03 1255.00 l!O0. 1355.07 1355.00 1300. 1455.12 1.455.00 1400. 1555.18 1555.00 1500. 1655.32 1655.00 1609. 1755.40 1755.00 1700. 1855.~6 1855.00 1~00. 1955.49 1955.00 1900. 2055.50 20,55.00 2900. 2155.51 2155.09 2100. 2255.52 2255.00 2ZOO. 2356.53 2355.00 2300. 2455.54 2455.09 2~00. 2555.55 2555.00 2~Og. 2655.55 Z655.09 2600. 2?55.55 2755.00 2?00. 2855.55 28:55.00 2800. 2955.55 2955.09 2't09. 3055.55 3035.00 3000. 3155.55 3135.00 3100. 3255.56 3255.00 3200. 3355.57 3355.00 3300. 3455.58 3455.00 3400. 3555.59 3555.00 3500. 3655.61 3655.00 ~500. 3755.62 3755.00 3700. 3855.63 3855.0,9 3BOO. O0 0 29 N 74 12 O0 0 2'9 N 72 32 O0 0 34 N 71 16 O0 I I N 61 5 7 gO 1 46 N 52 19 O0 1 46 N 49 57 O0 2 /+9 S 74 46 gO 2 40 S 52 22 O0 2 7 S 46 4 ~ O0 1 33 S 44 15 00 ! l 4 S ,42 0 30 0 52 S 43 0 90 0 47 S 4R 35 O0 0 47 S 41 44 O0 0 49 S 34 40 90 0 46 S 32 O OO 0 21 S ~1 3.6 OC 0 11 $ 6 33 O0 0 13 S ~0 54 O0 0 I~ S 9_2 lO 30 C 10 S 1 5~ O0 0 5 S 23 25 O0 0 13 S 48 56 O0 0 3! S 64 27 O0 0 50 S 33 37 90 O 55 S 77 35 gO 1 O S 71 15 O0 1 ! S 66 O0 0 54 S 59 5& O0 0 55 $ $1 48 DATE: 21-aUG-88 P~GE 5 DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: 17-AUG-88. 55. O0 FT S. $,%LAZAR EVEN 100 VERTICA[ SECTION FEET 0.00 0.01 -0.03 0.09 0.33 0.62 0.97 1.39 1.88 2.37 2.91 3.10 3.44 3.83 4.04 3.99 5.53 10.25 14.29 17.51 19.90 21.75 23.14 24.51 25.90 27.30 2~.37 28.87 29.06 29.E5 29.51 29.68 29.92 30.47 31.49 32.61 33.98 35.53 37.05 38.60 FEET OF DOGLEG SEVERITY DEG/IO0 0.0O 0.06 0.27 0.10 0 .OB 0.06 0.18 0.02 0.05 O.lt 0.09 0.12 0.23 0.94 0.18 0.37 2.38 0.79 0 0.73 0.36 0.42 0.02 0.28 0.08 0.20 0.24 0.27 0.14 0.40 0.18 0.08 0.20 0.52 0 0.24 0.19 0.27 0.14 0.22 , . SUB-SEA DEPTH RECTANGUL&R'CgORDIN~TES HORIZ~ NORTH/SOUTH EAST/WEST DIST. :"' FEET FEET FEET 0.00 N 0.00 E 0.09 N 0.01 E 0.15 N 0.13 E 0.11N 0.29 E 0.04 N 0.58 E O.Ol S O.9B E 0.09 S 1.44 E 0.16 $ 2.01 E 0.24 S 2.70 E 0.26 S 3.46 E ,DEPARTURE . o.ZO o. o .98 1.4.4 2. 2.71 3.47 0 E 1 E 31 E i, 8 40 E 36 E 34 E 29 19 56 E 85 44 E 0.15 S 4.29 E 0.13 N 5.10 E 0.39 N 5.97 E 0.87 N 7.18 E 2.36 N 9.37 E 4.36 N 11.79 E 5.09 N 15.13 E 2.67 N 19.66 E 0.01 S 22.78 E 2.2'7 S 25.10 E 4.29 S 87 58 E 5.10 N 88 33 E 5.98 N 86 15 E 7.24 N 83 5 E 9.67 N 75 50 E 12.57 N 69 41 E 15.96 N 71 24 E 19.84 N 82 16 E 22.78 S 89 59 E 25.20 S 84 49 E 4 0~ S ?6 73 = m ~. ~ . ~,= 5.39 S 27.99 E 6.37 S 28.99 E 7.30 S 30.01 E 8.41 S 30.85 c 10.52 S 32.19 E 10.97 S 32'41 E 11.30 S 32.30 E 11.68 S 32.13 f Z7.03 28.50 29.68 30.88 31.98 33.05 33.86 34.21 34.2Z 34.19 S 81 26 E S 79 5 E S 77 37 E S 76 19 E S 74 44 E S 73 8 E S 71 54 E, S 71 17 S 70 42 E S 70 1 E 12,05 S 32.09 E 12.24 S 32.12 f 12.42 S 32.28 E 12.73 S 32.77 E 13.05 S 34.00 ~ 13.25 S 35.53 E 1'3.71 S 37.16 E 14.35 S 38.83 E 15.10 S 40.32 E 16.03 S 41.65 5 34.28 S 69 25 E 34.3'? S 69 7 E 34.58 S 68 57 E 35.16 S 68 46 E 36.42 S 68 59 E 37.92 S 69 32 E 39.61 S 69 44 E 41.40 S 69 43 E 43.06 S 69 28 E 44.63 S 68 57 E COMPlJTATION DATE: 21-AUG-88 STANDARD ALASKA P~OOtJCT[OH CD. 2-28/P-19 MPI ENDICOTT NORTH SLOPE,ALASK~ KELLY DATE OF SURVEY: BUSHING ELEVATION: ENGINEER: INTERPOLATEg VALUES FOR EVEN 100 FEET O= SUB-SEA DEPTH MEASUR DEPT TRU ED VERT[ H D~P CAL TH SUni-SE4 VEPTIC~L ~,_ TH COURS~ VERTICAL OOGL~-G RECTANGULAR DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH DEG MIN DEG H[N FE~T DEG/IO0 FEET COORDINATES HDRIZ. E~ST/WEST DIST. FEET ~EET' 3955. 4055. 4155. 4255. 4355. 4455. 4555. 4655. 4755. 4855. 65 66 67 68 69 69 69 70 70 70 39 40 41 ~3 45 46 47 ~8 55 55 55 55 55 55 55 ~5 .00 .0O .00 .00 .0O . .90 .07 .0O 3~00.00 4000.00 4109.00 4ZO0.O0 4300.00 4409.00 4500.~0 4500. O0 ~00.90 4:~OO.OO 0 57 S 44 53 ~ 40.22 0.27 17.08 S 0 59 S 36 5;~ ~ 41.)2 0.11 18.38 S 0 46 S 29 45 ~ 43.52 0.1~ 19.68 S 0 45 S ~_5 2.~ ~ 4~.~4 0.22 20.8~ S 0 29 S 21 2! E 45.99 0.30 21.87 S 0 26 S ~2 57 ¢ 46 ~0 0 25 P2 ~9 S 0 21 S 23 52 E 47.29 0.44 23.21 S 0 23 S q 6 ~ 47.~8 0.15 !3.87 S 0 22 S 6 3 ~ 43.~4 0.07 24.52 'S 0 24 S 3 53 E 43.97 O.l~ 25.~5 S 42.91 E 44.02 E 44.96 E 45.56 E 46. O0 ,.c ~6.25 E ~6 58 c 46.70 E 46.7'~ E 46.85 E 46.1~9 47.70 49 07 50ill 50 94 51.47 52.04 52.44 52.82 53.17 4955. 5055. 5155. 5255. 5355. 5455. 5555. 5655. 5755. 5855. 7O 71 71 71 71 72 72 73 73 49 53 54 55 56 57 58 55 55 55 55 55 55 55 55 55 55 .0O .00 .00 .00 .09 .0O .00 .00 .00 5900.00 5109.00 5200.00 5309.30 5400.00 5500.00 5509.00 5700.00 5800.fi0 0 27 S ]I 3q E 49.58 0.17 25.91 S 0 22 S 10 45 W 50.15 0.64 26.6? S 0 22 S 54 46 W 50.27 0.17 27.12 S 0 22 S 75 lO W 50.04 0.33 27.36 S 0 21 S 74 51 W 49.77 0.23 27.55 S 0 26 S 64 1 W 49.59 0.28 27.86 S 0 30 S 59 31 W 49.36 0.33 28.18 S 0 33 S 73 9 W 49.11 0.15 28.48 S 0 40 S 71 21 W 48.70 0.28 28.79 S 0 50 S 76 51 W 48.19 0.50 29.10 S 46.88 46.84 46.48 ~5.82 45.13 44.48 43.72 42.93 ~1.91 40.70 P.%GE 55.00 FI :~: , S. SAL~,ZAR ,; ~ 5955. 6055. 6155. 6255. 6355. 6456. 6556. 6656. 6756. 6856. 75 77 80 83 88 O0 17 34 49 65 59 60 61 62 63 64 65 66 67 68 55.00 55.00 55.09 55.00 55.00 55.00 55.09 55.00 55.00 55.00 fO00.30 6tO0.O0 6200.00 6300.00 64O0.0O 6500.30 6500.90 6700.00 6909.00 1 2 S 69 33 W 47.55 0.54 29.53 S 1 14 S 60 24 W 47.09 0.11 30.44 S I 21 S 62 42 W 46.68 0.41 31.49 S ! 3! S 73 14 W 45.97 0.69 32.4Z S 2 20 S qB 45 W 44.18 1.01 32.76 S 3 19 N 99 40 W 41.14 0.33 32.81 S ~ 16 N 89 6 W 37.45 0.15 32.73 S 3 11 N ~6 29 W 33.64 0.49 32.50 S 3 3 N 84 30 W 29.75 0.76 31.95 S 3 10 N 85 19 W 25.89 0.47 '31.50 S 39.15 37.28 35.32 33.03 29.75 24.85 19.07 13.27 7.76 2.17 DEPARTURE 6956. 7056. 7156. 7257. 7358. 7459. 7561. 7664. 7766. 7869. 78 87 94 28 03 43 69 ZO 73 32 6955 7055 7155 7255 7355 7455 7555 7655 7755 7855 .00 .00 .OD .00 .00 .00 .00 .00 6909.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7600.00 7700.00 7900.90 2 1 5 8 10 12 12 12 13 &7 N 85 12 W 22.29 0.68 31.08 S 50 S 58 25 W 19.69 2.51 31.05 S 12 S 10 36 E 21.42 4.01 34.17 S 46 S 37 33 E 29.30 3.34 41.33 S 8 S 58 33 E 41.20 3.16 49.10 S 50 $ 56 4'2 E 56.79 3.62 57.51 S 35 S 54 14 E 77.27 0.65 69.69 S 43 S 53 15 E 99.09 .0-09 83.09 S 47 S 52 51 E 121.02 .0"I0 ' 96.69 S 7 S 51 48 E 143.29 0.60 110.64 S 3.06 7.17 8.28 4.61 4.71 19.13 36.65 54.81 72.88 91.07 AZIMUTH DEG MIN : S 68 17 E s 67 19 E S&6 21 E $ &5 22 E :$ 64 34 E ':S 63 57 E " 6~ 55 ~ S'62 20 E S 61 46 E 53.56 S 61 4 E 53.90 S 60 20 E 53.81 S 59 44 E 53.36 S 59 9 E 52.88 S 58 35 E 52.48 S 57 56 E 52.01 S 57 11 E 51.51 S 5~ 26 E 50.84 $ 55 30 E 50.04 S 54 25 E 49.04 S 52 58 E 48.13 S 50 46 E 47.32 S 48 16 E : 46.28 S 45 31 E 44.26 S 4Z 14 E 41.16 S 37 8 35.11 S 2Z 12E 32.88 S 13 38 E 31.57 S 3 56 E 31.23 S 5 37 W 31.87 S 1Z 59 W 35.16 S 13 37 W 41.59 S 6 22 W 49.33 S 5 28 E 60.61 S 18 23 E 78.74 S 27 44 E 99.54 S 33 24 E 121.08 S 37 0 E 143.30 S 39 27 E C']MPUTATIDN PATE: 21-~UG-88 STANOARO ALASKA PoOOUCT[ON CO. 2-28/P-19 MPI ENDICOTT NORTH SLOPE,ALASKa KELLY INTERPOL~TEO VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASURED DEPTH T VER D RU TI EP c TH SUq-SE VERTIC !]EPT A COURSE VERTICRL ~L DEVIATION AZIMUTH SECTION H DEG MIN DEC M[N FEET DOGLEG RECTANGULAR SEVERITY NgRTH/SOUTH DES/lO0 FEET 7972.09 8074.96 8177.74 8280.43 8982.98 84,85.38 8587.67 8689.85 8791.86 8893.74 79 80 81 82 ~4 ~5 ~6 87 55 55 55 55 55 55 55 '35 55 .00 .00 .00 .00 .00 .0O .09 .00 .00 .00 7900. 8000. 8100. 8200. 8300. ~¢00. ~500. ~500. ~700. ~ ?00. O0 13 31 S 49 47 r: 166.49 '30' 13 27 S 4,8 17 ~ 190.;~3 O0 13 16 S 46 59 E 213.72 O0 12 56 S ~5 19 ~ 236.84 O0 12 38 S 44 6 E 259.45 90 12 18 S ~2 5! E 281.46 O0 11 59 S 41 3~ : 302.95 90 ll 36 S 40 25 E 323.87 O0 11 11 S 39 22 ~ 344.02 30 1~ 51 S 3~ 25 i ~63.55 0.52 125.63 S 0.41 141.45 S 0.33 157.47 S 0.44 173.61 S 0.54 1~9,76 S 0.37 205.73 S 0.34 221.72 S 0.48 237.52 S 0.44 252.9~ S 0.63 268.19 S 8'~95.44 9096.~7 9198.14 9299.31 9400.35 9501.Z5 9602.07 9702.78 9803.46 9904.02 89 90 91 92 93 94 95 96 97 98 55 55 55 55 55 55 55 55 55 55 .00 .00 .00 .00 .00 .00 .00 8=~00. 9000. 9100. 9 ~-00. 9300. 9400. 9500. 95O 0. 9700. 9~00. O0 10 1 S 38 13 E 382.03 O0 9 21 S 38 24 E 398.99 O0 8 51 S 36 37 E 415.04 O0 8 27 S 33 6 E 430.23 O0 E 5 S 29 49 E 444.54 O0 7 27 S 24 44 E 4,57.76 O0 7 5 S 20 50 = 470.01 O0 6 39 S 21 34 ~ 481.37 O0 6 27 S 23 31 E 492.59 · .10 5 53 S 25 50 E 50~.97 0.89 2~2.79 S 0.46 296.01 S 0.75 308.67 S 1,93 321,13 S 0.83 333.45 S 0.80 34~5.44 S 0.59 357.26 S 0.41 368.45 S 1.03 379.24 S 0.41 338.94 S 0004.50 0104.86 0205.17 0305.47 0530.00 99 100 101 102 104 55.03 55.00 55.00 55.00 78.95 9909. lO00O. !OlOO. 10200. 10~23. 0.97 397.76 S 0.75 405.13 S 0.23 411.52 S 0.39 417.71 S 0.00 430.55 S DATE OF SURVEY: SUSHING ELEVATION: ENGINEER: CgORDINATES HORIZ ~AST/WE ST DI ST - F E ,: T 109.44, E 166. 127.65 E 190. 145.20 E 214.110 162.03 E 237.48 178.03 E 260.Z0, 193.21 E 282.2'7 207.68 E 303.8~ 221.42 E 324.~ 234.35 E 344.84',:i 246.60 E 364.33 258.04 E 382.76 268.56 E 399.69 278.43 E 415.70 287.17 E 430.80 294.70 E 445.01 300.88 E 458.10 305.76 E 470.22 309.94 E 481.48 314.45 E 492.65 318.9~ E 502.99 323.23 E 512.52 327.26 E 520.80 331.91 E 528.69 336.56 E 536.43 346.14 E 552.44 PAGE 7 17-AUG-88. 55.00 FT S. SALAZAR S 39 5 E S 38 55 E S 38 53 E S 3~ 51 E S 38 47 E STANDARD AL&SKA P~OOUETION 2-28/P-19 M~I ENDICOTT NORTH SLO~E,~LASK~ M~RK~R D q I LL..9. R S -.gE PT H CO. CgMPUT~TI']N D~XT~: INTERPOLATEO VALUES NEASURED OEOTH 21-~UG-~8 FOR CHOSEN FROM KB 10~78.95 HORIZONS ORIGIN= 194¢ TVO SU~-SEA KELLY 10423.95 SNL, PAGE OAT= OF SURVEY: 1_.7-AUG-lBS. '3USHING ELFV6TION: 55.00 FT ENGINEER: S. SALAZAR SURFACE LOCATION AT 22~0 WEL, SEC 36 T12N, RI6E RSCTANGULAR C~OEOINATES NORTH/SOUTH EASy, WEST STAND&RO ~L~SKA PgOgUCTTON CC. Z-28/P-19 MPI ENDICOTT NORTH SLOPE,ALASK~ COMPUTATION DATE: Zl-&UG-'S8 KELLY MARKER ORIGIN: 19~4 MEASUREO ]EPTH TVO BELOW K~ FgOM KB SU$-SE~ DRILLERS O~PTH 105~0.09 10478.95 1047__3.95 ~-INAL ~ELL LSCIT!ON AT TO: T~LI= SUO-SEA M;flSU;:E3 V=PTI'-AL VERTICAL OE mT q 9 :,c, TH 0~ PTH HORiZONTaL G~P ~R'TUP, E OI S T ~NC ~ ~ Z IMUTH nE ET DEG MZN 10530.00 lO~Tq.a. 5 10423.95 SNL, O~TE BUSHING OF SURVEY: ELEVATION: ENGINEER: PAGE 9 ~7-AUG-88 55.00 FT S. SAL A. ZAR SURFaC: 2240 WCL, SEC PECTANGULAR NORTH/SOUTH 430.56 S LOCATION AT ! 36 ~2N, R16E c6°I TEs DINA EAST/WEST 3'~:~',14 E SCHLUMBERGER D ]' RECT I ON~L SURVEY COMPANY STANDARD ALASKA PRODUCT!ON WELL 2-28 P-J9 MPI FIELD ENDICOTT COUNTRY USA RUN i DATE LOOOEO t? - AUO - 88 REFERENCE 72897 WELL:" 2-28/P-19 MPI (1944' SNL, 2240' WEL, ~-cC 36, TI'2N, R16E) HORIZONTAL PROJECTION NO, IH ~ REF ?289? 1130 -100 -200 -BO0 -400 -BO0 [ N/FT i ' SOUTH -600 -2O0 - 1 O0 0 1 O0 200 300 400 SOO ~00 EAST WELL'. 2-28/P-19 MPI (1.944' SNL, 2240' WEL, ,~...C 36, T12N, R16E) V£R?!)CAL PROJECTION 141, T"T'T"r'T'T'T'T'T" PI~O,.JECTION ON VERTIC¢4. PLI:INE 141. - ~21. 8CALEB IN VERTICI:IL. DEPTH8 HORIZ SCALE : 1/100 IN/FT Standard Alaska Production Company 900 East Benson Boulev~-~ PO, Box 196612 Anchora.qe, Atasko 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION September 30, 1988 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the cased hole well logs mn in the following Endicott well: WELL 2-28/P- 19 *Collar Log 9877'- 10300' Run No. 1 Atlas Wire Services Received By~~ Ir~f3--i- v ~ ~":!¢~ Sincerely, A unit o{ the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. July 28, 1988 J G Vidrine Endicott Drlg Eng Supervisor Standard Alaska Production Company P 0 Box 196612 Anchorage, AK 99519-6612 Telecopy No. (907) 276-7542 Re: Duck Island Unit/Endicott 2-28/P-19 Standard Alaska Production .Company Permit # 88-86 Surf Loc 1944'SNL, 2240'WEL, Sec 36, T12N, R16E, UM Btmhole Loc 2434'SNL, 1738'WEL, Sec 36, T12N, R16E, Dear Mr Vidrine: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required bY law from other govern- mental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Co~ission may be present to witness testing of the equipment before'the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. vey. y. truly _ryours, .? ........ :,: ;,/. ,, ~/.___.- Chairman Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION ~n°closure C; Department of Fimh & Game, Habitat Section - wlo encl Department of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill r-Illb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company BKB--56 fee t Endicott Field/Endicott Pool 3. Address 6. Property Designation P. 0. Box 196612, Anchorage, Alaska 99519-6612 ADL 34633 4. Location of well at surface 7. Unit or property Name 11. Type Bond(s~, 2o ^^c 25.o25) 1944' SNL, 2240' WEL, Sec. 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 2375' SNL, 1795' WEL, Sec. 36, T12N, R16E 2-28/P-19 MP! KOO683449-G-14 At total depth 9. Approximate spud date Amount 2434' SNL, 1738' WEL, Sec. 36, T12N, R16E August 2, 1988 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL312828 1795 feet 2-26/N-14 10 feet 2560 10530' MD;10456' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (soo 20 AAC 25.035 (e)(2)) Kickott depth 7000 feet Maximum hole angle 12.4 o Maximum surfaco 3800 psig At total depth (TVD) 9855'/4740 pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe 75 Surface 131' 131' Drive 17-1/2" 13-3/8" 68# NT-80 Butt 2444 Surface 2500' 2500' !2700 cu fl Permafrost 12-1/4" 9-5/8" 47# NT80S NSCC 8472 Surface 8528' 8500' 320 cu fl Permafrost 12-1/4" 9-5/8" 47# NT95H NSCC 1163 8528' 8500' 9691' 9636' 575 cu fl Class G 8-1/2" 7" 29# L-80 SM-110 1090 9440' 9391' 10530' 10456' 370 cu ft 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 Measured depth Structural R EC EITF ,oa, depth Conductor Surface Intermediate J U L. ~'~ ~'; Production ,-, ~.,. Liner Ataska 0il & Gas C0~s. Perforation depth: measured '.:;. Anchorage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid pro~tram [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby ce ti?r,~tl~..t/t.h~, foregoing is true and correct to the best of my knowledge Signed~/¢'~ ;~ ~/~~0 Title Endicott Drilling Engineering Supervisor Date/~- Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ~'~'"~¢e [50- O?_~-- 2, t~(7 [ 07/28/88 [for other requirements Conditions of approval Samples required [] Yes I~No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey requ~re~ [] Yes~ [] No Required work~d~'~s~fo~'5M; []10M; I-'I~I5M; Other: by order of Approved by (, ~., j~', Ik, ~~ Commissioner me comm,ssion Bat Form 10-401 R'e-'~'. 12-1-85 Subm 'iplicate PROPOSED DRILLING AND COMPLETION PROGRAM' WELL 2-28/P-19 (MPI) Objective Well 2-28/P-19 will be drilled as an oil production well from zone 3A. The completion will be run at the time of drilling and will consist of a simple assembly. Ooeration Execute a rig move to slot 2-28 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. and c. ement 13-3/8" 68#/ft., NT-80CYHE Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4740 psi at 9855 ft. TVDss. Maximum possible surface pressure is 3800 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 7000 ft., then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe and 5 ft. new hole and conduct a formation leak-off test. Drill 8-1/2" hole to TD. Run logs. Run and cement 7" 29#/ft, SM-110 buttress liner to TD with approximately 250 ft. of lap in the 9-5/8" casing. Clean out to float collar. Test casing and lap to 3000 psi. Run CET/CBT/VDL/GR/CCL in 7" liner and gyroscopic survey from PBTD to surface. Change over to NaCI packer fluid. Perforate well under balance utilizing drill-pipe conveyed guns. Run a simple completion assembly and install and test tree. Release rig. Downsqueeze the 13-3/8" x 9-5/8" annulus with Permafrost cement followed by a non-freezing fluid once rig is off location. ENDICOTT PROPOSED DIAGRAM WELL 2-28/P-19 (MPI) NON-FREEZING FLUID TVD (BKB) MD {BKB} 30" DRIVE PIPE 131 FT 131 FT BASE PERMAFROST 1466 FT 1466 FT SSSV 1550 FT 1550 FT TOP OF DOWN SQUEFTF: CEMENT (ESTIMATED) 2000 FT 13-3/8" 68#/FT NT-80CYHE BUTT 25OO FT 25OO FT BOTTOM OF DOWN SCUE~ CEMENT (ESTIMATED) 3000 FT 4-1/2", 12.6#/FT L-80 TUBING W/ 3-1/2" TAILPIPE KOP ( DIR: S 46° E; ANGLE: 12.4 DEG ) 7000 FT TOP OF 9-5/8" CEMENT 9-5/8" 47#/FT NTSOS NSCC (ESTIMATED) 7891 FT 8500 FT 8528 FT 4-1/2" SLIDING SLEEVE 9-5/8" PACKER 9342 FT 9390 FT 7" LINER TOP 9391 FT 9440 FT . 9-5/8" 47#/FT NT95HS NSCC 9636 FT 9691 FT PLUG BACK TD 10450 FT 7" 29#/FT SM-110 BUTT LINER 10456 FT 10530 FT KRL/7-19-88 B.O.P. STACK CONFIGURATION I ~3-5/8 IN. TRIPLE RAH STACK 5000 PSi WP DRILLING ANNULAR PREVENTER I I I l PIPE RAMS , I ! I I BL IND.-.RAMS I I 2 IN. KILL LINE GATE GATE DRILLING SPOOL I I PIPE RAMS I 4 IN. CHOKE LINE GATE GATE DRW NO. 116- 85 SHEET I ef I0 ,, REV. 0 PLAT OF PROPOSED WELL LOCATIONS IdPI Welll Lecete4 I, Se¢.&&,T. IZN-~R.I&E.,Umi4I Id. SDI leal, LecMed la S~c. I~T.II#.,R.l?E.,Um'~rt Id. , PREPARED FOR SOHIO ALASKA PETROLEUM CO. PRE:PAR EO BY F.R. BELL & ASSOC. PRUOHOE 8AY OFFICE PRUDHOE BAY, ALASKA ~T£: NOV. I~, tlt5 ICAL[: I"'1 NILE CX[CK[O BY' i.E. · ~4 0 I ~0 ® 42400 0 44 0 5 5~0 0 I ?0 . ~)0 ~ 0 f? f~ 0 ~ 0 ~1 0 o ° CERTIFICATE OF SURVEYOR I hearby certify that I em properly registered and licented to practice land surve,~ing in the State a~ Alaska end that this plat represents an proposed la<ation for the Well numbers shown above. All surveying was done by me or under my supervision, end that ell dimensions end data,Is ere correct. 36 DRW. 116-85 SHEET Z af I0 REV. 0 No rES' 0 Indicates ,~ell Indicates Celcbleted Sectlaa Career FesJtmn Indicates Perl~.e~diceler Offset Distance Indicetee Pereeediculer Off,et Dieteece · tperf~endicwlar d, stgnc? v~ries to, r ~a,,c~ will ) PLAT OF hlPI PROPOSEO WELL LOCATIONS LOCATED IN IEC. It, T..I~:#.,R. lB E. UNIAT M. II~EPARE 0 FOR SOHIO ALASKA PETROLEUM CO. F.R. BELL & ASSOC. ' PRUDHOE BAY OFFICE PRUDflOE BAY, ALASKA _ DAT[ ' leOV. 13, leis SCA L(, I'" DRAWN iY: RiX. CHECKEOBY: I.E. iii i _ _ i ii I i~__ I I I II I ....... . I Y, 1912412.37 N- 710~324.~1 7~2'1'10.0670' 14~17'Zi.i~' 1921.4i ~6.64 2 Y- ~982~79.88 N- 780~3~3.~2 70°21'20.9814' 147°57'24.&2~7' Zl3~.43 X- 2~904~.49 E- 464094.4~ 3 Y- 5982474 18~N· 71305321 98 70'21 '09 9846' 247' 57'20 6258' 1936 77~ 2032 11 · ~ · i I e · ~ ~ 5~82571.~ ~ 7805350.~ 70~21'10.8~1' ' 117:57'2~.~8~6' ~ 1813.80 X- 2~9035.76 E- 464092.74 ~ ~Y- ~98246~.99 ~ N- 78053~9.46 70~21'09.902~" ~7'20.78~7" X- 2~9169.27 E- 46413~.9~ & Y- ~982~63.~0 N- 7G0~348.47 70~21'10.816B" 147e~7'24,94~4' 18~2'i7 i X- 2~9030.02 E- 464091.04 7 Y- ~9824~7,80 N- 780~316.94 70c21'09.8200" 1470~7'20.945~" 1953.~2 2043.06 2~9163.~4 E- 464132.24 X- 8 Y" ~982~5~,30 N' 780~34~,94 70021'10,7344" 147°~7'2~.1~3'" IB60,~4 21B5,3~ ~' 2~9024,29 E- 464089,33 9 Y- 5982449.&1 N- 780~314,41 70021'09.7376, 147°57'21,10~4" 11&l.lt 204B.53 X" 2~9~7,10 E- 464130,53 10 Y- 5982547,1~ N- 780~343,42 70o21'10,6~21" 1470~7'2~,2&~1' IB&8,91 21~0,B3 X- 2~90~8.~5 E- 464.087,62 11 Y- ~982441,42 N- 780~311,89 70°21'09,6~3" 147°57'21,2653" 1970.26[ 2054,00 X- 259152,07 E- 464128,83 12 Y- 5982538,92 N- 7805340,90 70~ 21'10, 5697' 147°57'25,4250' 1877,21i 2196,30 X- 259012,82 E- 464085,92 ~3 Y- ~982433,23 N- 780~309,36 70°21 *09,5730' 147°57'21,4251' 1978,63": 2059,47 I ~ X' 259~46,33 E~ 464127,~2 14 Y' 5982530,73 N' 7805338,37 70c21'10.4874' 147°57'2~,5849' 1885,&6' 2201,77 X' 2~9007,08 E- 464084,2~ ~ Y- 598242~,03 N- 780~306,84 7002~'09,4906' ~47057'21,~850' 1987,00 2064,94 X- 259[40.60 E- 464~25,42 ~6 Y~ 5982522,54 N- 7805335,85 70o21'~0,4051' 147°57'25,7447' 1194,03 2207,24 X- 259001,35 E- 464082,50 , 17 Y' ~982416,84 N' 7805304,3~ 70°2~*09,4083' ~47~57'21,7449' 1995,38 2070,41 X' 259~34.16 E' 464123,71 lB Y' 59825~4,35 N' 7805333.32 70°21'10,3227, 147°57'25,~04&' ~902,40 22~2,71 X' 25899~,61 E' 464080,80 19 Y' 5982408,6~ N' 7805301,79 70c21'09.3260' ~' 147°57'21.9047' 2'003.75~ 207~,89 X' 2~9129,13 E' 464122,00 ' 11 ~, $~2~00.~ ~, ~052~.~7 ~0e21'0~.2~36' ~ llTe~'22.0$~h· ~012.12 X- 259123.39: E- 464120.30 :. MPl PRO SED ELL L ATION LIST ~ ~ 4~~, LOCATED IN SEC. 5',T. IZ N.,".I'E. UMIAT .- -- . SOHIO ALASKA PETROLEUM CO. ~.~ t ~194_ ~~ ORW. NO. 116-85 PREPARED IY DATE'NOV. 13. qh a~-~,~:~ F.R. BELL B ASSOC ~k~C~SS~kC~ SHEET ~ of iD ' _ SC*L[' ~~~ - - PRUDHOE BAYOFFICE DRAWN aY' ~Ev. O PRUOHOE BAY, ALASKA CHECKED BY~ I.E. ii i i ii i i II(I,.L~ ZIII I IIi~-''~ 04~ 6 LITITIII4 LG~../TUK ll..w lilT 2Z'" Y-~912497.97 N;"710~'321.27 7FZi'lO.i~l' "14'~17'26.224l' 1919.1S Z223.6~ X~ 2~1914.14 E. 464077.31 23 Y- 5982392.27 N- 7B05296.74 70°21'09,i6i3' ~47057'22.2244' 2020.49 20B6,13 X- 2~9~7.6~ E- 464tZ8.59 24 .Y- ~982489.77 N- 780~2~.7~ .70c21'10.07~7' '1'47~7'26,~842' 1927.~3 2229 2~ Y- ~982~84.08 N- 7'80~294.22 70~21'09.0790' ~ 147:57'22.~84~' 2028.8~ 2092,~0 26 Y- 5982481.58 N= 7805323,23 70~21'09.99~4* 147:57'26.5440' ~ 1935.90 2234.60 .X= 258972.67 ~ E= 464073,97 27 Y= 5982375.89 ' N= 7805291.69 70c21'08.9966' 147c'57'22.5442' ~ 2037.24 2097.77 X= 259tO6. t8 E= 464115.1B 28 y= 5982473,3:~ N= 7805320.70 ;~rT'O°21'Og.tlll' tiTc57'21.703f* 1~t~.27 2240,07 x- 2~8966,93 E. 464072'27 ~ i ' 2~ ~- ~82~6~,~0 ~- ~80~28~.1~ ~0c21'08.~1~$' 1~7c~'22,~0~0 ~0 Y- ~98246~,20 N- 710~18.1B i 700 21' 0'.1287' 147°~7'2&.l~7' 1~2,&4 t224~.~4 X- 2~e96Z.20 E' 464070,~6~ St Y ~9823~9 ~0 N- 710~286 ~ [70~2~ 08 1320 147~57 22 1~3~ - , ' . ' ' · ' 2~01.72 X- 2~9094.7~ E' 464~7' ,' ~2 Y- ~9824~7.0, N' 780~'~.&~ ~70c2~'09.74&4' ~47~7'27.02~6 X- 2~89~.46 E- 464068.8~ ~ 33 Y' ~9823~.3~ N' 780~284.~2 ~70~2~'08.7496' ~47~7'23.0237'~ 2062.3~ ~2~4.~9 X' 2'9088'98 E' 464ll0'06i ~4 Y' ~982448.82 N' 780~3.~3 70~22'09 &642' ~47~7'27.~134' ~9&9.~8 22~6.49 X' 2'8949'7' E' 464067''' ~ X- 258926.78 E- 464060.32 37 Y' ~982310.36 N' 780~271 ~0 ~70°21'08.3379" 147057'23.B230" 2104.21 2141.~ X' 2~9060.30 E' 464101:~3 l' 38 Y' ~982407.86 N" 780~300.~1 70°21'09.2~24" 147~7'27.9127" 20~1.24 2283.B4 ~' 2~8921.05 E' 4640~8.&1 39 Y" ~9~2302.17 N' 7B0~268.98 7~21'0B.2~6" 147C~7'23.9129" 2112.SI 2147.02 X" 2~90~4.~6 E' 464099.82 ~ 40 Y' ~982399.&7 g' 780~297.98 {70°21'09.1700" ~47°~7'28.1426" 2019.&2' 2289.31 X' 2~89[~.3~ E' 4640~6.9~i 41 Y' 5982293.97 N' 780~266.4~ ~70°21'08.~733' 147c~7'24.1427" 2~20'9~ 2~2.49 X" 2~904B,83 ~ E' 4~4098.~[ ~ 42 Y" ~982391.48 N- 7~0~295.46 ~70°21'09.0877"~ 147°57'28'3024" 2027.99 2294.79 X' 2~8909.~8: E" 4640~.20~ * . ,, i ~.~_ MPI PR~SED WELL L~ATION LIST ~ ~ LOC&TED IN SEC. S6 T. IZN., R. 16 [. UMI&T M. so.,o A CO. ~A.~ ~ F.R BELL & ASSOC. _ S~ SHEET 4 of I0 · SCALE: N/A -'. REv 0 PRUOHOE BAY, ' ' CHECKED IT: I.[, ii i ~{LL AlP IO~ I UTh ..ON~ & LATITUde LO~' . lilt Jilt 43 Y- S9122fl.7i N, 71052&3,93 70¢21'01,090t'& 14~i7'Z4,S~i' ~IP, II X- 2~9043.09 E- 46409&.41 44 Y- ~982383.29 N; 780~292,93 7'0~'21 09.00~4" '~47°~7"28.4&~3" 203&. 3& ~ 2300. 26 X- 2~903.84 E. 4640~.~0 . .... ~ .... Y. ~7~.~-~"-7e0'~-2.40 .... ~:-~T~ooe6· ~47~'24.~6~"'-' 2i'~.~0' {X- 2~037.36 E- 4640~4.70 ' ~ 44' -'Y- 5V82375.10~ N- 78052V0.41 70-21'08.9230" ~ 147~57'28.622%" T' X- 258898.11~. E- 464051.79 ' ' X, 25903t.62 E- 464092.99} ; 48 Y- 5982366,91 N- 7B05287.89 ~70°21'08.8407' 147~57'28.7B20~' ~ 2053'.10} 2311.20 X- 258892.37 E- 464050.08 49 Y- 5982261.21 N- 7805256.35 7'0o2t"07.8439' t47°57'2'4.7B22' 2tS4.44, 2174.38 X- 259025.89 E- 464091.29 ~0 Y- ~9823S8.7i W- 7i0~28~.34 ~0o2i"'08.7~B4· i47~7'2i,'94[i· 204{.47 X- 2~8886.43 E- 464048.38 ~[ Y- ~9822~3.02 N- 780~2~3.83 70c2i"07.7624· 147~7'24.~420" 2t42.1i{ 2i79.,6 X- 2n9020. IS E- 464089.~8 i ~2 Y- n9~23~0.~2 W- 780~282.84 70c2i'08.~760"' i47°~7'29, i0i7" 2069.l~{ 2322.[4 X- 2~8880.~0 [- 464046.67 ~3 Y- ~982244.83 N- 780~2~2.3i 70~22'07.6793'"" i47o~7'2~.i0i9" 2[7i"19 2{8~.33 X- 2~90[4.4[ E- 464087.88 $4 Y- ~982~42.33 N- 780~280.3i 70o22'0'8.~937· 1470~7'29.2&{~" 2078.22{ 2327.&2 . X- 2~887~. {6 E- 464044.96 . ~S Y- ~982236.64 N- 780~248.78 70c2{'07.~96~· i47o~7'2~.2427· 2{79.~6 2190.N0 ; X. 2~9008.68 E- 464086,[7 ' '~6 Y- ~982334.~4 ~- 780~277.79 70~2~'08.~X{3" ~470~7"29.42{4· "2086.~9~ 233'3.09 X- 2~8869.43 E- 464043.26 ~7 Y'. '~ge222e.44,'. 780~246.26 70~2s'07.~4~'" {47o~7'2~.42~· 2~87.93j 2~96.27 X- 2~9002.94 E- e64oe~.e6 ~e Y-~9~232~.9~ w-7eo~'27~.27 7oo2t'oe.4~9o- ~47~7'29'.~2· 2o94.~ ~9 Y- ~982220.~ g, 780~243.73 70c2~'07.4323" {47~7'2~.~1{4" 2tg&.30 220{.74 [- 238997.2{ E- 4~4082.76 , 60 Y" 59823{7.76 ~- '780~272.74 70o2~'0B.3467' {47~'7'29.74l{· 2~03.33 2344.03 X- 2~88~7.96 E- 464039.8~ ~' Y- ~9822%2.06 ~- 780~24~.2% 70d2{'07.3499· %470~7'2~"74~3" 2204.~7 2207.2~ x. 2~e99{.47 E- 4640et.0~ 62 Y- ~982309.~7 ~- 780~270.22 '70c2"{'08.264'3" ~47'~7'29'~9009· 2tZ~.Tt x- 2~88~2.22 E- e64o~e, te , 63 Y- ~982203.87 N- 780~238.69 70o2t'07.2676' t47o~7'2~.t0tt' 2213.0~ 2212.&9 X- 258985.74 . E- ~6~079.34 ......... · ~ , m m ii i iii illl il MPI PRO~SED WELL L~TION LIST ~_~ ~~ ~1 LOCATED IN ~C. 3& T.I~N. R. I~E. UMIAT M. ~[~O~[zS~~ SHEET 5of tO F.R. BELL & ASSOC. SCALE' -~%~~- ... ~ - PRUOHOE BAY OFFICE DRAWN e[v. o PRUOHOE ~Y, ALAS~ CHECKEOBY: ~.[. ~ i iii i i i1~ i i ii ii ii i i ,' l- 2SII4&, 4l E- 4&403&. 4~ A~ Y- ~98219~.&8 N- 7105236.16 70°21'07.1852' 147°~7'26.0&10' 2221.4~ X' 2~8980.00 E' 464077.&4 66 Y- 5982293,18 N- 7805265.17 70'21'08.0997' 147'~7'30.2206' 2128.45 2360'4~ .... X- 2~8840.7~ E- 464034.73 67 Y- 5982~87.49 N- 7805233.64 70:2T;-07'1029' 247- 57'26.2208' ~ 2229.80 ' 222~'.~3 X- 258974.26 E- 46407~.93 x. 2s~e3s.o~ [. 4640ss.0~ x. 2~e~6e.~sI,. E. 464074.2S 70 Y- 59~227&.10 N- 7~0~260.12 70o21'07.9350' : 147~57'30.5403' 214~.19 2371.39 . _ X' 2~8B29.28 E- 464031.3l ~ i i ii ii MPI P~O~SED WE~ L~ATION LEST ~'~--'~-'1 SOHIO ALASKA PETROLEUM CO. ~?ss~~ PR U OHO/ BAY OFFICE ~%~~ O R A W N B Y · R,G .T. ~. 0 PRUOHOE BAY~ALASKA CHECKE0 IY~ ENDICOTT,. DEVELOPMENT WELL 2-28/P-19 (MPI) TRUE NORTH GRID SLOT 2-28 SURFACE LOCATION X = 258,967 FT ; Y = 5,982,473 FT 1944 FT SNL; 2240 FT WEL SEC 36, T12N, R16E S 46° E DEPARTURE TO TARGET: 620 FT 1O146 FT MD 10081 FT TVD BKB DEPARTURE TO BHL: 702 FT 10530 FT MD 10456 FT TVD BKB NOTE: THE NEAREST WELL TO 2-28/P-19 IS 2-26/N-14 LOCATED 10 FT NORTHEAST AT SLOT 2-26. KRL/7-19-88 --- Closest Approach Analysis --- Date: 19-JUL-88 Time: 10:38:56 Search Radius= 200 COURSE LINE -' For proposed well: 2-28/P-19 [32-36-12-16] Location = W-E S-N TVD(SBS) Top 258967.00 5982473.00 -56.00 Bottom 259455.05 5981967.97 10400.00 Note: All depths in feet Below Kelly Bushing (BKB) Closest Approach WELL IDENT /PROPOSED% /NEARBY~ CLOSEST TVD DEPART TVD DEPART DISTANCE A000-0000051 MI-1 A000-0000083 MI-33 A000-0000086 MI-36 A000-0000119 MI-69 A000-0000120 MI-70 A029-2064000 HIED10 A029-2156800 MI-P18 A029-2158500 MI-M19 A029-2160500 MI-O20 A029-2162500 MI-Q21 A029-2163900 MI-O16 A029-2164800 MI-Q17 A029-2166200 MI-P14 A029-2166900 MI-M25 A029-2167200 MI-O25 A029-2169300 MI-P20 A029-2169800 MI-J22 A029-2171300 MI-O23 A029-2172200 MI-N22 A029--2174300 MI-3X8 A029-2174800 MI-P24 A029-2175000 MI-S14 A029-2176700 MI-R12 A029-2177100 MI-K16 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 1100 8 2601 1 3373 7 0 9 1800 9 4100 8 3429 4 0 9 1 0 6000 3 0 8 0 8 1000 7 900 6 1999 8 4600 7 400 9 100 9 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 0 0 0 0 0 0 0 1100.0 2600 0 3373 0 00 1800 0 4099 9 3429 4 00 00 5999 8 00 0 0 1000 0 899 6 1999 3 4599 7 400 0 100 0 2.0 7 4 14 0 0 0 6 3 10 4 28 7 0 0 0 0 16 0 0 0 0 0 i 8 18.9 34.4 34 .5 0.7 0.2 129.6 120.7 190.7 214.1 65.3 197.3 11.1 170.1 183.9 158.3 109.9 197.4 168.6 189.7 157.0 116.5 109.5 99.8 Vertical Intersection /PROPOSED% /NEARBY% TVD DEPART TVD DEPART 7222.1 11.2 3458.8 30.3 VERTICAL DISTANCE -3763.3 8760.1 331.0 3584.2 155.1 -5174.8 9058.0 396.3 5674.3 220.9 -3382.8 8813.5 342.7 4808.9 167.5 -4004.1 A029-2178800 MI-R25 1.0 0.0 0.0 A029-2180100 MI-J19 579.4 0.0 600.0 A029-2181500 MI-N14 2700.9 0.0 2700.0 SUMMARY The well which comes closest to the proposed well is: A029-2181500 MI-N14 Closest approach distance = KICK OFF for this run = 9.2 feet 7000.0 feet 0.0 2.0 2.0 239.7 213.6 9.2 --- Closest Approach Analysis --- Date: 19-JUL-88 Time: 10:42:55 Search Radius= 200 7 DEGREE LEAD LINE -' For proposed well: 2-28/P-19 [32-36-12-16] Location = W-E S-N TVD(SBS) Top 258967.00 5982473.00 -56.00 Bottom 259512.96 5982031.21 10400.00 Note: Ail depths in feet Below Kelly Bushing (BKB) Closest Approach WELL IDENT /PROPOSED\ /NEARBY% CLOSEST TVD DEPART TVD DEPART DISTANCE A000-0000051 MI-1 A000-0000083 MI-33 A000-0000086 MI-36 A000-0000119 MI-69 A000-0000120 MI-70 A029-2064000 MISD10 A029-2156800 MI-P18 A029-2158500 MI-M19 A029-2160500 MI-O20 A029-2162500 MI-Q21 A029-2163900 MI-O16 A029-2164800 MI-Q17 A029-2166200 MI-P14 A029-2166900 MI-M25. A029-2167200 MI-O25 A029-2169300 MI-P20 A029-2169800 MI-322 A029-2171300 MI-O23 A029-2172200 MI-N22 A029-2174300 MI-J18 A029-2174800 MI-P24 A029-2175000 MI-S14 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 1100.8 2601 1 3373 7 0 9 1800 9 4100 8 3429 4 0 9 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1100 0 2600 0 3373 0 00 1800 0 4099 9 3429 4 0.0 2 0 7 4 14 0 0 0 6 3 10 4 28 7 0 0 129 6 120 7 190 7 214 1 65 3 197 3 11.1 170.1 1.0 6000.3 0.0 0.0 0.0 5999.8 0.0 16.0 183.9 158.3 0 8 0 8 1000 7 900 6 1999 8 4600 7 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1000 0 899 6 1999 3 4599 7 0 0 0 0 1 8 18 9 34 4 34 5 109.9 197.4 168.6 189.7 157.0 126.5 Vertical Intersection /PROPOSED% /NEARBY% TVD DEPART TVD DEPART 7224.6 11.4 3485.3 31.7 8046.5 174.8 1833.2 8217.7 212.3 3028.8 4.9 42.2 VERTICAL DI STANCE -3739.4 -6212.4 -5187.9 9219.0 431.5 3S25.2 263.6 -5392.8 7976.4 159.5 5758.7 15.2 -2217.2 7971.2 158.3 6003.4 16.0 -1967.2 8016.4 168.2 953.3 11.4 -7062.6 8031.0 171.4 6223.3 11.4 -1807.2 10236.7 654.3 5316.6 484.3 -4919.6 A029-2176700 MI-R12 400.9 0.0 400.0 A029-2177100 MI-K16 100.9 0.0 100.0 A029-2178800 MI-R25 1.0 0.0 0.0 A029-2180100 MI-J19 579.4 0.0 600.0 A029-2181500 MI-N14 2700.9 0.0 2700.0 SUMMARY 0.7 0.2 0.0 2.0 2.0 109.5 99 .8 239 .7 213 .6 9.2 The well which comes closest to the proposed well is: A029-2181500 MI-N14 Closest approach distance = KICK OFF for this run = 9.2 feet 7000.0 feet Interval ENDICOTT'MUD PROGRAM MAIN PRODUCTION ISLAND WELL 2-28/P-19 Mud Weight Viscosity (ppg) (sec/qt) Fluid Loss (ml/30min) oH 0-2500 8.8-9.8 100-200 20- 15 9.0-9.5 2,500- 9,691 9,691- 10,530 Set 13-3/8" casing 9.2-10.2 40-45 15-16 9.0-10.5 Set 9-5/8" casing 9.6-10.2 40-45 6-8 9.0-11.-0 Hang 7" Liner Mud Type/ Components Generic Mud /15 Seawater Fresh water Gel Soda Ash Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill DOYON DR!LL!NG, !NC. RIG NO. 15 MUD AND SOLIDS CONTROL EQUIPMENT Equipment Manufacturer Nominal Model Capacity Shaker Desander Mudcleaners Cen tr i fuge Brandt Dual Double 1000 9pm Demco 2-12" cones 700 9pm (each) Tri Flow Double 400 9pm 8 each - 4" (each) cones Pioneer Mark II, 150 9Pm Decant i n 9 Degasser Dr i lco Agi t'ator s 8randt Hoppers Geosource Vacuum 1000 9pm 8 each - 25 h.p. Dual Sidewinders 1000 9Pm The trip tank and mud tank sections have one vertical pit level float indicator which are connected to the drillin9 recorder system that contains visual and audio warning devices located in the driller's console. If' ILS,' DOUBT.- - ASKll I _ JddJ III 16:c' /.,/Trz 1."1" ¢ 6~'£1D,.~1; lglll. O~ i i i i ~ . I..o I ! ' 1 : ! ! :~T . · - ASK!! 6;.o ' e · ' ''· "T',: '"°1 I" ! ~z.-' o D ~9 ~4.0oo (~Ac. ,cuE../.. Il 0 j VIE. ~ - Z. E YE L__~__ ..F/v/ C TESTING TIlE B.O.P. STACK WITH THE 13-1/8" x 4½" IF BOX X BOX, (TIIRU-BORE), TEST PLUG (FIG. 7) 1.) Make up the 13-1/8" x 4½" IF test plug to a stand of drill pipe. (Illustration 9) NOTE: Sometimes it is helpful to make a stand of heavy wall up to the bottom of the test plug in order to help energize the compression packing. 2.} Lower the lest plug through the B.O.P. stack until it lands on the lowe~r load shoulder of the split unihead unit. 3.) Run in at least two of the lower set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if need to energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/8" X 4-1/2" IF BOX X BOX (THRU-BORE) TEST PLUG THIS EAID UP I- FMC P.N. 48-261-082 REQ'D 'PART NO. _ 1 48-261-268 Test Plug 1 48-261-083 Body 1 48-261-673 Compression Ring 4 79-040-074 Set Screws 1 48-081-529 Packing 1 51-092-001 2" Ball Check Figure #7 (Part number 48-261-082 continued on next page) FMC P.N. 48-261-082 continued PART 'NO. D~sCRi'PTION 19-505-663 Coil Spring 25-411-356 Retaining Plate 25-411-357 Circ.-O-Lox Ring 48-180-027 Pipe Plug 52-304-013 Drlg. Pipe Sub. ILLUSTRATION 9 B.O.p. STACK 3-5/8" 5000 WP 3-5/8" 3000 WP TESTING THE B.O.P. STACK WITH THE 13½" X 4½" IF BOX X BOX, (UPPER) , TEST PLUG (FIG. 19) 1.) Make up the 13½" x 4½" IF test plug (upper) to a stand of drill pipe. (Illustration 13) NOTE: Sometimes it is helpful to make a stand of heavy wall 6p to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the split unihead unit. 3.) Run in at least two of the upper set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if you need to energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/2" X 4-1/2" IF BOX X BOX (UPPER) TEST PLUG IS END UP FMC P.N. 48-261-068 REQ "D PA~ NO. DESCRIPTION 1 48-261-067 Body 1 48-261-671 Compression Ring 4 79-040-074 Set Screw 1 82-741 117 Packing 1 51-092-001 2" Ball Check 1 19-505-663 Coil Spring 1 25-411-356 Retaining Pla~e 1 25-411-357 Circ.-O-Lox Ring _ 2 48-180-027 Pipe Plug Figure #19 ILLUSTRATION # 13 B.O.P. STACK 5/8" 5000 WP , 13-5/8" 3000 WP TESTING THE B.O.P,. STACK WITH THE 10" X 4-1/2" IF BOX X BOX (COMBINATION) , TEST PLUG (FIG. 22A) 1.) Make up the 10" x 4%" IF test plu_g (combination) to a stand of drill pipe. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the tubing/casing head. 3.) Rin in at least two of the upper set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. 4.) Test the B.O.P. stack. 5.) Back out all the lockdown scres which have been run in. 6.) Remove the test plug. 10" COMBINATION TEST PLUG AND BOWL PROTECTOR RUNNING/RETRIEVING TOOL THIS END UP FMC PART NO. 48-261-503 1 48-261-504 BODY 1 48-085-833 BELT PACKING 1 48-180-025 PLUG, 1¼ L.P. 1 48-180-025 PLUG, 1¼ L.P.i 4 I 48-180-015 PLUG, ½ L.P. 1 48-010-009 WRENCH (Figure ~22A) -[] $ '~. B.O.P. 1,, STACK 5000 WP 13-5/8" 3000 W B.O.P. STACK .......... ~- ~" sooo wp ....... ~_ 11" 5000 WP I--I:W i ..... 13-5/8" 3000 WP ! CHECK LIST FOR NEW WELL PERMITS Company ~f~(~ Lease & Well No. ITEM APPROVE DATE YES NO (i) Fee _~~ Vf~6[~5 1. Is the permit fee attached .......................................... ~- ~R~S (2) Loc (2 thru 8) (8) (3) Admin ~ -ffZ~ f~ 9. (9 thru 13) 10. (i0 and 13) 12. 13. (4) Casg ~F-~.~,~, V-~V-~:~ (14 thru 22) (23 thru 28) ( 6 ) -OTHER ~ 7'f~/¢;3 (29 thru 31) rev: 07/22/88 6.011 14. 15. 2. Is well to be located in a defined pool ............................. _~ 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. Can permit be approved before fifteen-day wait ...................... ~ Does operator have a bond in force .................................. Z~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... _~_ 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 and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ...................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of .~,.~m~,~:a.n~ BOPE attached.,~/~ . .... Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (May 84) ........ f.~. ~ ..... Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? , ................ Are seismic analysis data presented on shallow gas zones ............ ""//' If an offshore loc., are survey results of seabed conditions presented// Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ?..fO[oo (3E'~- ! o;L ~9o [0145-o (Dig 0 Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well HistOry file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ .. No special'effort has been made to chronologically .. organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : 2-28/P-19 MPI FIELD NAME : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292184700 REFERENCE NO : 98080 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/04/ 9 ORIGIN : FLIC REEL NAME : 98080 CONTINUATION # : PREVIOUS REEL : COGENT : BP EXPLORATION, 2-28/P-19 MPI, ENDICOTT, API # 50-029-21847-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/04/ 9 ORIGIN : FLIC TAPE NAME : 98080 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : BP EXPLORATION, 2-28/P-19 MPI, ENDICOTT, API# 50-029-21847-00 TAPE HEADER ENDICOTT CASED HOLE WIRELINE LOGS WELL NAME: 2-28/P-19 MPI API~BER: 500292184700 OPERATOR: BP EXPLORATION (ALASKA), INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 8-APR-98 JOB NUMBER: 98080 LOGGING ENGINEER: Y MORGAN OPERATOR WITNESS: D VARBLE SURFACE LOCATION SECTION: 36 TOWNSHIP: 12N RANGE: 16E FNL: 1944 FSL: FEL: 2240 FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: 55.10 DERRICK FLOOR: GROUND LEVEL: 14.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 10448.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 10247.5 10239.0 10214.5 10211.5 10189.0 10186.0 10181 5 10178 0 10163 0 10159 5 10150 5 10148 5 10146 0 10139 0 10136.5 10134.5 10121.0 10116.5 10102.5 10089.0 10082.5 10077.5 10049.5 10047.0 10040.5 10036.5 10031.0 10026.5 10023.5 10019.5 10007.5 10002.0 9999.5 9992.5 9990.5 9982.5 9973.5 9968.5 9965.0 9957.5 9955.0 9949.5 9944.0 9938.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH 88887.5 10247.0 10239.0 10214.0 10211.5 10190.0 10185.5 10182.0 10177.0 10162.5 10159.5 10150.0 10147.0 10145.0 10140 0 10135 5 10133 0 10120 5 10116 5 10100 5 1OO88 5 10081.5 10076.0 10048.0 10046.5 10039.5 10035.5 10032.0 10026.5 10022.5 10018.0 10007.5 10001.5 9999.5 9991.5 9989.0 9982.5 9972.5 9968.0 9964.5 9957.0 9954.5 9948.0 9943.5 9937.0 RST ....... 88887.5 10247.0 10239.0 10214.0 10211.5 10190.0 10185.5 10182.0 10177.0 10162.5 10159.5 10150.0 10147.0 10145.0 10140.0 10135.5 10133.0 10120.5 10116.5 10100.5 10088.5 10081.5 10076.0 10048.0 10046.5 10039.5 10035.5 10032.0 10026.5 10022.5 10018.0 10007.5 10001.5 9999.5 9991.5 9989.0 9982.5 9972.5 9968.0 9964.5 9957.0 9954.5 9948.0 9943.5 9937.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 9931.0 9930.5 9930.5 9919.0 9918.0 9918.0 9914.5 9914.5 9914.5 9886.0 9885.0 9885.0 9884.0 9883.0 9883.0 9871.5 9870.0 9870.0 9864.5 9863.5 9863.5 9853.0 9852.5 9852.5 9851.0 9850.5 9850.5 9844.0 9843.0 9843.0 9827.5 9827.0 9827.0 9815.5 9815.0 9815.0 9803.0 9802.0 9802.0 9794.5 9794.5 9794.5 9790.0 9789.0 9789.0 9786.0 9785.5 9785.5 9784.0 9784.5 9784.5 9780.0 9780.0 9780.0 9776.0 9775.0 9775.0 9768.0 9768.0 9768.0 9760.0 9761.0 9761.0 9743.0 9744.0 9744.0 9726.0 9725.0 9725.0 9722.0 9722.5 9722.5 9716.0 9716.5 9716.5 9714.0 9713.5 9713.5 9711.0 9710.5 9710.5 9702.5 9702.5 9702.5 9698.5 9697.5 9697.5 9685.5 9685.0 9685.0 9682.0 9682.0 9682.0 9667.5 9667.5 9667.5 9657.5 9657.0 9657.0 100.0 99.5 99.5 $ REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST TDTP DATA AQUIRED ON BP EXPLORATION'S 2-28/P-19 MPI WELL. PASS #1 GRCH WAS NOT CORRELATABLE TO THE BASE GR BACAUSE BARIUM SALT IN THE CASING CAUSED ABNORMALLY HIGH READINGS (SEE FIELD COI~4ENTS) . SO, PASS #1 SIGMA WAS SHIFTED TO THE BASE GR, THEN THOSE SHIFTS WERE CARRIED AND APPLIED TO PASS #1 GRCH. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 102 63.5 9567.5 RST 10274.5 9567.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH GRCH RST .............. REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1225229 O0 000 O0 0 1 1 1 4 68 NBAC RST CPS 1225229 O0 000 O0 0 1 1 1 4 68 FBAC RST CPS 1225229 O0 000 O0 0 1 1 1 4 68 SBNA FIL CU 1225229 O0 000 O0 0 1 1 1 4 68 SFNA FIL CU 1225229 O0 000 O0 0 1 1 1 4 68 SBFA FIL CU 1225229 O0 000 O0 0 1 1 1 4 68 SFFA FIL CU 1225229 O0 000 O0 0 1 1 1 4 68 TRAT FIL 1225229 O0 000 O0 0 1 1 1 4 68 IRAT FIL 1225229 O0 000 O0 0 1 1 1 4 68 CIRNFIL 1225229 O0 000 O0 0 1 1 1 4 68 CIRF FIL 1225229 O0 000 O0 0 1 1 1 4 68 BSALRST PPK 1225229 O0 000 O0 0 1 1 1 4 68 SIBF RST CU 1225229 O0 000 O0 0 1 1 1 4 68 TPHI RST PU-S 1225229 O0 000 O0 0 1 1 1 4 68 SFFC RST CU 1225229 O0 000 O0 0 1 1 1 4 68 SFNC RST CU 1225229 O0 000 O0 0 1 1 1 4 68 SIGM RST CU 1225229 O0 000 O0 0 1 1 1 4 68 DSIG RST CU 1225229 O0 000 O0 0 1 1 1 4 68 GRCH RST GAPI 1225229 O0 000 O0 0 1 1 1 4 68 TENS RST LB 1225229 O0 000 O0 0 1 1 1 4 68 CCL RST V 1225229 O0 000 O0 0 1 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 ** DATA ** DEPT. 10274.500 NBAC.RST 2452.157 FBAC.RST 3029.524 SBNA.FIL SFNA.FIL 16.139 SBFA.FIL 41.072 SFFA.FIL 13.919 TRAT. FIL IRAT. FIL 0.507 CIRN. FIL 1.325 CIRF. FIL 3.011 BSAL.RST SIBF. RST 33.546 TPHI.RST 19.738 SFFC.RST 11.176 SFNC.RST SIGM. RST 11.188 DSIG.RST 0.251 GRCH.RST -999.250 TENS.RST CCL.RST -0.001 DEPT. 9568.000 NBAC.RST 2973.153 FBAC. RST 6465.038 SBNA.FIL SFNA.FIL 35.056 SBFA.FIL 54.402 SFFA.FIL 36.274 TRAT. FIL IRAT. FIL 0.651 CIRN. FIL 0.485 CIRF. FIL 0.670 BSAL.RST SIBF. RST 53.277 TPHI.RST 40.278 SFFC.RST 32.569 SFNC.RST SIGM. RST 32.618 DSIG.RST -3.060 GRCH. RST 2564.623 TENS.RST CCL.RST -0.011 53.735 0.861 32.681 11.104 1360.000 60.999 1.132 86.413 30.856 1544.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~fA2~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10257.0 9607.5 RST 10269.0 9607.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888 0 10261 0 10255 0 10254 0 10249 0 10248, 0 10247 0 10242, 5 10237.5 10228.0 10223.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88887.0 88888.0 10254.0 10248.0 10246.5 10242.0 10227.5 10222.0 10261.0 10252.5 10247.0 10237.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 10220.5 10220.0 10219.0 10218.0 10215.5 10214.5 10214.5 10214.0 10205.0 10205.0 10199.5 10199.5 10195.0 10196.5 10194.5 10195.5 10188.0 10187.5 10186.5 10186.0 10184.0 10183.5 10184.0 10182.0 10182.0 10177.5 10177.0 10176.0 10174.5 10172.5 10171.5 10171.0 10169.5 10168.0 10166.5 10164.5 10163.5 10161.0 10160.5 10160.0 10159.5 10156.5 10156.0 10153.0 10152.5 10151.0 10150.0 10149.0 10147.0 10146.5 10145.0 10142.0 10142.5 10140.5 10140.5 10138.0 10137.5 10136.0 10134.5 10134.5 10132.5 10129.0 10127.5 10121.5 10120.5 10119.0 10118.5 10113.5 10113.0 10111.0 10109.5 10109.0 10107.0 10102.0 10100.5 10100.0 10098.0 10093.5 10091.5 10091.5 10090.5 10089.0 10088.5 10083.5 10082.5 10083.0 10081.5 10081.0 10079.5 10079.5 10077.5 10070.0 10068.0 10064.5 10063.0 10063.0 10061.0 10059.0 10057.5 10054.0 10052.0 10050.0 10048.0 10048.5 10047.5 10046.0 10045.0 10045.5 10044.5 10041.0 10039.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 10040.5 10040.5 10037.0 10036.0 10035.5 10031.5 10032.0 10024.5 10023.0 10023.5 10022.5 10019.5 10018.0 10016.0 10014.5 10014.5 10013.5 10011.5 10011.0 10011.0 10010.5 10001.5 10001.0 10000.0 9999.5 9998.5 9998.0 9993.5 9992.5 9993.0 9992.0 9989.5 9988.0 9987.0 9986.0 9983.5 9983.5 9983.0 9978.0 9977.5 9974.0 9973.0 9973.0 9971.5 9966.0 9965.0 9963.0 9962.0 9960.0 9959.5 9958.5 9958.0 9952.5 9951.0 9950.0 9948.5 9947.5 9946.5 9945.0 9944.0 9942.5 9942.0 9942.0 9941.5 9938.5 9937.0 9937.5 9936.5 9936.0 9935.0 9931.5 9930.5 9928.5 9927.5 9921.0 9921.5 9920.0 9918.5 9918.0 9918.0 9914.0 9914.0 9912.0 9912.0 9906.0 9904.5 9905.0 9904.5 9899.5 9898.0 9896.0 9895.0 9894.0 9893.5 9887.5 9886.5 9886.0 9885.0 9881.5 9880.0 9880.5 9877.0 9875.0 9873.0 9871.5 9871.5 9870.0 9868.0 9866.5 9864.5 9863.5 9864.0 9862.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 9861 0 9855 0 9851 5 9848 5 9844 0 9843 5 9841 5 9840 0 9838 0 9833 0 9824.5 9820.0 9817.5 9790.0 9784.5 9783.5 9779.5 9779.0 9776.0 9774.5 9771.0 9759.5 9759.0 9757.0 9746.5 973 7.5 9735.0 9727.0 9723.0 9722.5 9714.5 9712.0 9707.5 9705.0 9703.0 9697.5 9693.5 9683 0 9674 5 9668 5 9665 0 9659 5 9658 0 9657 0 9652 5 9650 5 9647 5 9644 5 9639 5 9626.0 9622.5 9614.0 9609.5 100.0 9860.0 9854.0 9847.5 9843.0 9841.0 9838.0 9832.0 9823.5 9819.5 9817.0 9788.5 9784.0 9778.5 9773.5 9760.0 9747.5 9737.5 9722.5 9696.5 9668.5 9659.5 9656.5 9647.0 99.5 9850.5 9842.0 9837.0 9789.0 9784.5 9779.5 9775.0 9770.5 9760.5 9757.5 9735.0 9726.0 9723.0 9714.5 9710.5 9707.0 9704.5 9702.5 9693.0 9682.5 9674.5 9668.5 9665.5 9657.5 9652.0 9649.0 9643.5 9638.0 9624.5 9622.0 9612.0 9608.5 99.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 10 REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 BSAL RST PPK 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 11 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TPHI RST PU-S 1225229 O0 000 O0 0 2 1 1 SFFC RST CU 1225229 O0 000 O0 0 2 1 1 SFNC RST CU 1225229 O0 000 O0 0 2 1 1 SIGM RST CU 1225229 O0 000 O0 0 2 1 1 DSIG RST CU 1225229 O0 000 O0 0 2 1 1 GRCH RST GAPI 1225229 O0 000 O0 0 2 1 1 TENS RST LB 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1225229 O0 000 O0 0 2 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** DEPT. SFNA.FIL IRAT. FIL SIBF.RST SIGM. RST CCL.RST 10269.000 NBAC.RST 2505.526 FBAC.RST 3256.685 SBNA.FIL 53.079 16.621 SBFA.FIL 38.768 SFFA.FIL 14.211 TRAT. FIL 0.900 0.506 CIRN. FIL 1.343 CIRF. FIL 2.933 BSAL.RST 19.851 29.019 TPHI.RST 21.303 SFFC.RST 11.446 SFNC.RST 11.779 11.433 DSIG.RST 0.161 GRCH. RST -999.250 TENS.RST 1592.000 0.018 DEPT. SFNA. FIL IRAT. FIL SIBF. RST S IGM. RST CCL. RST 9607.000 NBAC.RST 2987.066 FBAC.RST 6132.527 SBNA.FIL 59.603 35.065 SBFA.FIL 57.468 SFFA.FIL 38.074 TRAT.FIL 1.116 0.666 CIRN. FIL 0.506 CIRF. FIL 0.675 BSAL.RST 76.127 49.403 TPHI.RST 37.453 SFFC.RST 34.778 SFNC.RST 31.036 34.763 DSIG.RST -3.958 GRCH.RST -999.250 TENS.RST 1519.000 0.036 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 12 FILE HEADER FILE AULIMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10257.0 9629.0 RST 10268.0 9628.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888 0 10265 5 10261 0 10255 0 10254 0 10253 0 10249 0 10239 5 10239 0 10230.5 10228.0 10224.5 10222.5 10215.0 10214.5 10209.0 10208.0 10202.5 10200.5 10194.5 10190.0 10188.0 10184.5 10183.5 10182.0 10181.5 10178.0 10177.5 10173.0 10171.5 10170.0 10167.5 10164.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88887.0 88887.0 10254.0 10252.0 10248.0 10238.5 10227.5 10224.0 10221.5 10214.0 10208.5 10202.5 10195.5 10188.0 10183.5 10182.5 10176.5 10171.5 10169.0 10167.0 10163.0 102 64.5 10260.5 10252.5 10239.0 10229.5 10214.0 10208.0 10201.5 10190.0 10184.0 10181.0 10177.0 10170.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 13 10161.0 10160.0 10156.5 10151.0 10148.5 10146.5 10146.0 10142.0 10139.5 10138.0 10136.0 10134.5 10129.0 10121.5 10119.0 10116.5 10113.5 10108.5 10108.0 10102.0 10100.0 10096.5 10096.0 10094.5 10093.5 10091.5 10089.0 10086.0 10083.0 10081.0 10079.5 10078 0 10073 0 10064 5 10062 5 10059 5 10055 5 10050 0 10049 0 10046 5 10046 0 10043 0 10041 0 10037 0 10036 5 10031 5 10023.0 10020.5 10019.5 10011.5 10010.5 10OO2.5 10001.5 9998.5 9997.0 10160.5 10156.0 10144.5 10142.5 10137.5 10134.5 10127.5 10118.5 10107.0 10098.0 10094.5 10093.0 10090.5 10085.0 10079.5 10077.5 10071.0 10062.5 10058.0 10053.5 10047.5 10046.0 10041.0 10036.0 10019.5 10011.0 10001.0 9998.5 9996.5 10159.5 10150.0 10146.5 10145.0 10139.5 10133.0 10120.5 10116.5 10113.0 10107.0 10100.5 10095.0 10091.5 10088.5 10081.5 10076.0 10061.0 10048.0 10045.0 10042.0 10039.5 10035.5 10032.0 10022.0 10018.0 10010.0 10002.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 14 9995.0 9993.5 9989.5 9987.0 9983.5 9983.0 9978.0 9974.5 9973.5 9973.0 9970.5 9966.0 9963.0 9960.0 9958.0 9955.0 9953.0 9949.5 9945.5 9944.5 9942.0 9938.5 9937.5 9936.0 9931.5 9928 5 9920 5 9918 5 9918 0 9914 0 9912 0 9906 0 9905 0 9901 5 9896.5 9894.0 9887.5 9886.0 9884.0 9881.5 9877.0 9873.5 9871.5 9868.0 9864.5 9863.0 9861.0 9857.5 9855.0 9851.5 9848.5 9844.0 9842.0 9840.0 9837.5 9992.5 9988.0 9986.0 9983.5 9977.5 9973.0 9972.0 9969.5 9965.0 9962.5 9959.0 9951.0 9944.0 9941.5 9936.0 9927.5 9917.0 9912.5 9904.5 9893.5 9887.0 9880.5 9875.0 9871.5 9866.5 9861.5 9860.0 9857.0 9854.0 9847.5 9841.0 9839.0 9994.0 9982.5 9972.5 9962.0 9957.5 9954.0 9948.0 9944.0 9937.0 9935.0 9930.5 9922.0 9918.5 9914.0 9904.5 9901.0 9895.0 9885.0 9883.0 9880.5 9870.0 9863.5 9850.5 9842.5 9836.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 15 9833.0 9832.0 9826.5 9826.0 9824.0 9823.0 9820.0 9819.0 9817.0 9816.5 9798.5 9797.5 9791.5 9790.5 9790.0 9788.5 9789.0 9779.5 9779.0 9780.0 9776.5 9775.5 9774.5 9773.5 9760.0 9761.0 9748.0 9748.5 9746.5 9747.5 9743.5 9745.0 9737.0 9737.5 9734.0 9734.0 9733.5 9733.0 9722.5 9722.5 9722.5 9716.0 9716.5 9714.0 9713.5 9712.5 9711.0 9709.0 9709.0 9708.0 9707.0 9703.5 9703.0 9698.0 9697.0 9697.5 9696.5 9690.5 9690.0 9683.5 9683.5 9682.5 9682.0 9678.5 9678.5 9677.0 9676.5 9671.5 9671.5 9669.0 9668.5 9668.0 9667.5 9665.5 9666.5 9659.5 9659.5 9658.0 9657.5 9657.5 9657.0 9650.5 9649.5 9644.5 9643.5 9639.5 9637.5 9633.0 9632.0 100.0 99.0 98.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 16 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF FIL 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 BSAL RST PPK 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 1225229 O0 000 O0 0 3 1 I 4 68 0000000000 TPHI RST PU-S 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST CU 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V 1225229 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 17 ** DATA ** DEPT. 10268.000 NBAC.RST SFNA.FIL 16.621 SBFA.FIL IRAT. FIL 0.506 CIRN. FIL SIBF. RST 29.019 TPHI.RST SIGM. RST 11.433 DSIG.RST CCL.RST 0.018 DEPT. 9628.000 NBAC.RST SFNA.FIL 35.176 SBFA.FIL IRAT. FIL 0.664 CIRN. FIL SIBF. RST 45.870 TPHI.RST SIGM. RST 33.375 DSIG.RST CCL.RST 0.002 2505.526 FBAC.RST 38.768 SFFA.FIL 1.343 CIRF. FIL 21.303 SFFC.RST 0.161 GRCH.RST 2671.686 FBAC.RST 48.896 SFFA.FIL 0.518 CIRF.FIL 34.711 SFFC.RST -2.093 GRCH. RST 3256.685 SBNA.FIL 14.211 TRAT. FIL 2.933 BSAL.RST 11.446 SFNC. RST -999.250 TENS.RST 4264.706 SBNA.FIL 36.526 TRAT. FIL 0.727 BSAL.RST 33.449 SFNC.RST -999.250 TENS.RST 53.079 0.900 19.851 11.779 1592.000 59.324 1.086 66.635 31.074 1537.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: O. 5000 FILE SU~!ARY LDWG TOOL CODE START DEPTH GRCH 10249.5 TDTP 102 60.0 STOP DEPTH 9870.5 9870.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 18 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10253.5 10248.0 10247.0 10240.0 10239.0 10235.5 10231.5 10230.5 10228.0 10226.5 10223.0 10218.5 10218.0 10215.0 10211.0 10208.5 10208.0 10205 0 10203 0 10199 0 10194 5 10191 0 10188 0 10186.0 10184 5 10184 0 10182 0 10181 0 10178 0 10177 5 10174 5 10172 5 10169 5 10168 5 10167 5 10165 0 10164 5 10160 0 10156.0 10153.0 10151.0 10148.0 10145.5 10141.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88887.5 88887.0 10246.5 10238.5 10235.5 10231.0 10227.5 10222.0 10218.0 10208.5 10205.0 10202.5 10199.0 10195.5 10188.0 10183.5 10182.0 10176.5 10171.5 10169.0 10166.5 10163.5 10160.0 10155.5 10145.0 10142.0 10252.5 10247.0 10239.0 10231.0 10226.0 10217.0 10214.5 10211.0 10208.0 10192.5 10185.5 10184.0 10180.5 10177.0 10174.5 10168.0 10164.0 10159.5 10152.5 10150.0 10146.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 19 10139.5 10137.5 10136.0 10134.0 10128.5 10126.0 10123.5 10123.0 10121.0 10118.0 10114.5 10113.0 10108.0 10107.0 10101.5 10100.0 10099.5 10095.5 10093.0 10091.5 10091.0 10088.5 10086.0 10085.5 10082.5 10081.0 10079.0 10077.5 10075.5 10073.0 10071.0 10069.5 10065.0 10064.0 10063.0 10059.0 10056.0 10054 0 10052 5 10050 5 10049 0 10048 5 10045 5 10044 0 10043 0 10040 0 10036 5 10036 0 10033 0 10031 5 10028 0 10026 5 10024 0 10023.5 10020.0 10137.5 10134.5 10127.5 1 O122.5 10114.5 10107.0 10098.0 10094.5 10090.5 10085.0 10079.5 10077.0 10074.5 10071.0 10069.5 10068.0 10063.0 10058.0 10052.0 10049.5 10047.5 10045.0 10043.0 10039.0 10035.0 10033.0 10028.0 10023.0 10019.0 10140.0 10137.0 10135.0 10132.5 10125.0 10122.5 10120.5 10118.0 10113.0 10106.5 10101.0 10098.5 10091.5 10090.0 10088.5 10085.0 10081.5 10076.0 10063.5 10061.0 10055.5 10051.0 10048.0 10042.0 10035.5 10032.0 10026.5 10022.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE 2O 10019.0 10017.5 10014.0 10014.0 10011.0 10011.0 10010.5 10010.0 10007.0 10007.0 10006.5 10006.5 10002.5 10002.0 10001.5 10001.0 10000.0 9999.5 9998.5 9998.5 9996.5 9996.0 9993.0 9992.0 9992.0 9991.0 9990.5 9989.0 9989.5 9988.0 9986.5 9986.0 9984.0 9983.5 9983.0 9983.0 9978.0 9977.5 9977.0 9976.5 9972.5 9971.5 9971.0 9970.0 9969.0 9968.0 9965.5 9965.5 9965.0 9964.5 9962.5 9962.0 9960.0 9959.5 9958.0 9957.5 9953.0 9952.0 9951.0 9949.5 9949.5 9948.0 9945.5 9944.5 9944.5 9943.5 9942.0 9941.0 9938.5 9937.5 9936.0 9935.0 9933.5 9932.5 9931.5 9931.0 9931.0 9930.5 9928.5 9928.0 9928.0 9927.5 9927.5 9927.0 9926.0 9925.0 9920.0 9921.5 9919.5 9918.5 9918.5 9918.0 9917.5 9917.0 9915.0 9914.5 9913.0 9912.5 9905.0 9904.5 9902.5 9900.5 9901.5 9901.0 9894.0 9893.0 9887.5 9887.0 9885.5 9885.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 21 9884.0 9882.0 9880.5 9879.5 9877.5 9876.5 9875.0 9875.0 100.0 98.5 9883.0 9880.5 9873.5 98.5 REMARKS: THIS FILE CONTAINS CASED HOLE RST FLOWING PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH FLOWING PASS Hi AND GRCH BASE PASS HI, ALSO SIGMA FLOWING PASS Hi AND SIGMA BASE PASS Hi, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 22 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM. CODE (HEX) SFFA FIL CU 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 CIRN FIL 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL RST PPK 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RST CU 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RST PU-S 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RST CU 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RST CU 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RST CU 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RST CU 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 TENS RST LB 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 CCL RST V 1225229 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10260 SFNA. FIL 15 IRAT. FIL 0 SIBF. RST 0 SIGM. RST 10 CCL. RST 0 000 NBAC.RST 2506.952 FBAC. RST 3259.608 SBNA.FIL 454 SBFA.FIL 41.140 SFFA.FIL 13.028 TRAT. FIL 509 CIRN. FIL 1.361 CIRF. FIL 3.146 BSAL.RST 921 TPHI.RST 18.122 SFFC.RST 10.163 SFNC.RST 183 DSIG.RST 0.176 GRCH. RST -999.250 TENS.RST 000 DEPT. 9870.500 SFNA.FIL 25.613 IRAT. FIL 0.551 SIBF. RST 0.959 SIGM. RST 20.871 CCL.RST -0.012 NBAC.RST 2676.054 FBAC.RST 4259.443 SBNA.FIL SBFA.FIL 44.776 SFFA.FIL 22.691 TRAT. FIL CIRN. FIL 0.920 CIRF. FIL 1.887 BSAL.RST TPHI.RST 19.668 SFFC. RST 20.269 SFNC. RST DSIG.RST -0.400 GRCH. RST 884.339 TENS.RST 48. 839 O. 848 21. 721 10.161 1009. 000 50. 966 O. 915 16.407 21.168 1090. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 23 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NTJMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10253.5 9874.0 RST 10264.5 9875.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10253.0 10251.5 10249.0 10247.5 10247.0 10242.5 10239.5 10238.5 10235.5 10231.0 10227.5 10223.0 10218.5 10215 0 10210 5 10208 5 10208 0 10202 5 10199 0 10194 5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88887.5 88887.5 10252.5 10252.5 10250.5 10248.0 10246.5 10242.0 10238.5 10235.5 10230.5 10227.5 10222.0 10218.0 10208.5 10203.0 10199.5 10195.0 10247.5 10239.0 10214.5 10211.0 10208.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 24 10189.5 10190.5 10187.5 10188.0 10184.0 10184.0 10183.5 10183.0 10182.0 10182.5 10181.0 10181.0 10177.5 10176.5 10174.0 10174.5 10172.0 10171.5 10167.5 10167.5 10167.0 10166.5 10164.0 10163.5 10163.0 10162.5 10160.5 10160.5 10159.5 10159.5 10155.5 10155.5 10152.5 10152.0 10152.5 10150.0 10150.0 10148.0 10146.5 10147.5 10146.0 10146.0 10145.0 10145.5 10145.0 10141.5 10142.0 10139.5 10140.5 10137.5 10137.5 10135.5 10134.5 10133.5 10132.0 10128.5 10127.5 10128.0 10127.0 10123.0 10122.5 10118.5 10118.5 10118.0 10118.0 10107.5 10107.0 10107.0 10099.5 10098.0 10093.0 10091.5 10091.0 10090.5 10088.5 10088.5 10087.5 10087.5 10085.5 10085.0 10085.0 10085.0 10083.0 10082.5 10082.0 10081.5 10080.0 10079.5 10079.5 10078.5 10078.5 10077.5 10077.0 10076.0 10072.5 10071.5 10069.0 10068.0 10067.5 10066.0 10064.0 10063.0 10062.0 10061.0 10058.5 10057.5 10050.0 10049.0 10048.0 10047.5 10047.0 10046.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 25 10045.0 10043.5 10040.0 10036.0 10035.5 10031.0 10029.0 10027.5 10026.0 10023 5 10022 5 10019 0 10014 0 10010 5 10007 0 10004 0 10000 0 9999 5 9998.0 9996.0 9993.0 9992.5 9990.0 9989.0 9986.5 9983.0 9982. $ 9980.0 9979.5 9978.0 9974.0 9973.0 9972.5 9970.5 9965.0 9963.0 9962.0 9959.5 9957.5 9952.0 9949 0 9947 5 9944 0 9943 5 9941 0 9937 5 9936 0 9933 0 9931 0 9930.5 9928.5 9928.0 9926.0 9921.5 9918.5 10045.0 10043.0 10035.5 10030.0 10028.0 10022.0 10013.5 10011.0 10007.5 10004.0 10001.5 9998.0 9996.0 9992.5 9988.0 9986.0 9983.5 9980.5 9977.5 9973.5 9971.5 9963.0 9959.5 9951.0 9946.5 9944.0 9941.5 9936.0 9934.0 9932.5 9930.5 9927.5 9925.0 9918.5 10039.5 10035.5 10032.0 10026.5 10022.0 10018.0 10007.0 9999.5 9992.0 9989.0 9983.0 9979.5 9972.5 9970.0 9964.5 9962.0 9957.5 9948.0 9943.5 9937.0 9931.0 9928.0 9921.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 26 9914.0 9911.5 9904 5 9903 5 9902 0 9901 0 9895 0 9893 0 9891 5 9885 5 9881 5 9881 0 9879 5 100.0 $ 9912.0 9904.0 9901.0 9892.5 9880.5 9877.5 98.0 9914.5 9904.0 9901.0 9894.5 9890.5 9885.0 9880.5 99.0 REMARKS: THIS FILE CONTAINS CASED HOLE RST FLOWING PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH FLOWING PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA FLOWING PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 27 * * SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC RST CPS 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC RST CPS 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1225229 O0 000 O0 0 5 i 1 4 68 0000000000 CIRNFIL 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL RST PPK 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF RST CU 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI RST PU-S 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC RST CU 1225229 O0 000 O0 0 5 1 1 ~ 68 0000000000 SFNC RST CU 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM RST CU 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG RST CU 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH RST GAPI 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 TENS RST LB 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 CCL RST V 1225229 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10264.500 NBAC.RST 2523.232 FBAC.RST 3280.783 SBNA.FIL SFNA.FIL 17.203 SBFA.FIL 42.406 SFFA.FIL 14.216 TRAT. FIL IRAT. FIL 0.489 CIRN. FIL 1.246 CIRF. FIL 2.939 BSAL.RST SIBF.RST 0.889 TPHI.RST 20.405 SFFC.RST 11.433 SFNC.RST SIGM. RST 11.431 DSIG.RST 0.409 GRCH.RST -999.250 TENS.RST CCL.RST 0.000 DEPT. 9874.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF.FIL -999.250 BSAL.RST SIBF.RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 GRCH.RST 739.022 TENS.RST CCL.RST -999.250 51.867 0.886 20.710 12.226 1091.000 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 28 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SOlv~vL~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10255.5 9873.5 RST 10266.5 9873.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888 0 10261 0 10252 5 10251 5 10249 0 10248 0 10247 0 10242 5 10239 5 10239.0 10237.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88887.5 88887.5 10260.5 10252.0 10250.5 10248.0 10246.0 10242.0 10238.5 10236.5 10247.0 10239.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 29 10235 5 10234 5 10232 5 10223 0 10219 5 10218 5 10215 0 10214 5 10211 0 10209 0 10205 0 10203 0 10202 0 10199 0 10196.0 10190.0 10188.0 10184.0 10182.0 10181.0 10177.5 10175.5 10173.0 10170.5 10167.5 10164.0 10161.0 10159.5 10155.5 10153.0 10152.5 10150.5 10148.5 10146.0 10141.5 10140.0 10137.5 10136.0 10134.0 10132.5 10128.5 10128.0 10126.0 10123.5 10121.0 10118.5 10116.5 10114.0 10112.5 10108.0 10106.5 10102.0 10099.5 10097.5 10097.0 10235.5 10234.0 10222.5 10218.0 10213.0 10208.5 10205.0 10203.0 10199.5 10196.5 10191.0 10188.0 10182.0 10176.5 10175.0 10171.5 10167. 0 10163.5 10160.0 10155.5 10152.0 10144.5 10142. 0 10137.5 10134.5 10127.5 1 O122.5 10118.5 10114.5 10107.0 10098.0 10096.5 10233.0 10218.0 10214.5 10210.5 10203.0 10184.0 10180.5 10170.0 10163.0 10159.5 10152.5 10150.0 10147.0 10145.0 10140.5 10137.0 10135.0 10132.5 10131.0 10126.5 10125.0 10120.5 10116.5 10112.0 10105.5 10101.0 10096.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 30 10095.5 10094.0 10093.0 10091.5 10089.0 10085.5 10083.0 10082.5 10080.5 10077.5 10072.5 10064.0 10062.5 10059.5 10057.5 10052.5 10050.5 10049.5 10048.5 10047.5 10045.5 10045.0 10044.0 10040.5 10037.0 10036.5 10033.5 10031.0 10028.0 10023.0 10019.5 10014.5 10010.5 10010 0 10007 0 10005 0 10004 5 10002 5 10000 0 9998 5 9996 5 9994 0 9992 5 9986 5 9983 5 9983 0 9978 0 9977.5 9974.5 9974.0 9971.0 9970.5 9969.0 9965.0 9964.5 10094.5 10093.0 10091.0 10085.0 10082.0 10079.5 10071.0 10063.0 10058.0 10049.0 10047.5 10045.0 10043.0 10036.0 10033.0 10028.0 10022.5 10014.0 10010.5 10004.5 9998.5 9996.0 9986.0 9983.5 9977.5 9973.0 9969.5 9965.0 10091.5 10088.5 10081.5 10076.0 10061.0 10055.5 10051.0 10048.0 10046.5 10044.5 10039.5 10035.5 10032.0 10022.5 10018.0 10010.0 10007.0 10004.0 10001.5 10000.0 9994.0 9991.5 9983.0 9976.5 9974.5 9970.0 9968.0 9964.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 31 9959.5 9959.0 9958.0 9957.5 9955.0 9954.5 9953.0 9952.0 9952.0 9950.5 9951.5 9950.5 9949.5 9948.0 9944.5 9944.0 9944.0 9943.5 9942.0 9941.5 9938.0 9937.0 9935.5 9935.0 9933.5 9933.0 9931.0 9930.5 9928.0 9927.5 9927.0 9926.5 9926.0 9925.0 9923.0 9922.0 9918.0 9919.0 9914.5 9914.5 9912.0 9912.5 9907.5 9908.5 9904.5 9904.0 9904.5 9902.5 9901.0 9901.0 9900.5 9895.5 9895.0 9894.0 9893.5 9892.0 9890.5 9887.5 9887.0 9886.0 9885.0 9881.5 9880.5 9880.5 9880.5 9878.5 9878.0 9877.5 9876.5 9876.0 9875.5 100.0 99.5 99.0 REMARKS: THIS FILE CONTAINS CASED HOLE RST FLOWING PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH FLOWING PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA FLOWING PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 32 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 t 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC RST CPS 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC RST CPS 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 CIRN FIL 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL RST PPK 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF RST CU 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI RST PU-S 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC RST CU 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC RST CU 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM RST CU 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG RST CU 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH RST GAPI 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 TENS RST LB 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 CCL RST V 1225229 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 33 DEPT. 10266.500 NBAC.RST SFNA.FIL 16.590 SBFA.FIL IRAT. FIL 0.495 CIRN. FIL SIBF. RST 0.951 TPHI.RST SIGM. RST 11.507 DSIG.RST CCL.RST 0.000 DEPT. 9873.000 NBAC.RST SFNA.FIL 33.619 SBFA.FIL IRAT. FIL 0.549 CIRN. FIL SIBF.RST 0.964 TPHI.RST SIGM. RST 32.019 DSIG.RST CCL.RST -0.041 2557.329 FBAC.RST 38.641 SFFA.FIL 1.336 CIRF. FIL 21.318 SFFC.RST 0.250 GRCH. RST 2775.117 FBAC.RST 45.245 SFFA.FIL 0.770 CIRF. FIL 33.811 SFFC.RST 0.331 GRCH.RST 3129.441 SBNA.FIL 14.279 TRAT. FIL 2.974 BSAL.RST 11.516 SFNC.RST -999.250 TENS.RST 4364.698 SBNA.FIL 33.138 TRAT.FIL 1.229 BSAL.RST 32.334 SFNC.RST -999.250 TENS.RST 49.144 0.899 20.316 11.741 1002.000 43.169 1.149 14.774 33.512 980.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 7 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS RST 1, 2, 3, $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 34 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC RST CPS 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC RST CPS 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA RSAV CU 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA RSAV CU 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA RSAV CU 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA RSAV CU 1225229 O0 000 O0 0 7 1 I 4 68 0000000000 TRAT RSAV 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT RSAV 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNRSAV 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF RSAV 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL RSAV PPK 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF RSAV CU 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI RSAV PU-S 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC RSAV CU 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC RSAV CU 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM RSAV CU 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 35 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DSIG RSAV CU 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH RST GAPI 1225229 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10274.500 NBAC.RST 2452.157 FBAC.RST 3029.524 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV -999.250 IRAT.RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBF. RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 GRCH.RST -999.250 DEPT. 9568. 000 NBAC. RST 2973. 153 FBAC. RST 6465. 038 SBNA. RSAV SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV IRAT.RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV -999.250 BSAL.RSAV SIBF. RSAV -999. 250 TPHI. RSAV - 999. 250 SFFC. RSAV -999. 250 SFNC. RSAV SIGM.RSAV -999.250 DSIG.RSAV -999.250 GRCH.RST 2564. 623 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 3 6 DEPTH INCREMENT: 0. 5000 FILE SUN~VlARY VENDOR TOOL CODE START DEPTH 10337.5 RST $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAlVk4A RAY RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9517.0 04-FEB-98 8C0-069 1700 04-FEB-98 10448.0 10298.0 9568.0 10275.0 1800.0 TOOL NUMBER ........... CGRS-A RST-A 8.500 10448.0 Produced Fluids THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORIVZALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT R~TE LOW SCALE (CPS) '. 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 37 FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger Depth correlated to SWS CBT (17 Aug 1988) Three pases made with well shut-in (9650-10298) Three passes made with well flowing (9900-10298) Ail passes made @ 1800 ft/hr GR SCALE = 1 TO 1000 DUE TO BARIUM SALT IN CASING chk = 80 during flowing & wfl passes due to floating tool WFL stationary measurements made above & below (5) IC mode Open perforation intervals: 10140-10160' & 10186 - 10212" Well test summary (1-9-98): chk=104, gfr=12555, or=1632, wc=87, gor=4178 tglr=543, whp=712, wht=196, water rate=lO923, gas rate=6819, gl rate=O THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 38 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 CS PS1 F/HR 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS1 LB 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 NPHV PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 NPDE PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 NSCE PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 CRRA PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 NSCR PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 AQTMPS1 S 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 CHV PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 CPSV PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 CP2V PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 CM2V PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 RCFR PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 RCLC PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 RCRC PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 RCAK PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 RTDF PSl 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 FPHV PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 FPDE PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 FSCE PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 FSCR PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 AQTF PS1 S 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 SF6P PS1 PSIG 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 HVPV PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 BMCU PSI UA 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 GDCU PS1 MA 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 EXCU PS1 UA 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 NBEF PS1 UA 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 FBEF PS1 UA 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 NPGF PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 FPGF PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 BSTR PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 BSPR PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 MARC PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 XHV PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 XPSV PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 XP2V PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 XM2V PS1 V 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 RXFR PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 RXLC PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 RXRC PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 RXAK PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 SHCU PS1 MA 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL PS1 PPK 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL SIG PPK 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 CIRN PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF PS1 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 CIRN FIL 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF FIL 1225229 O0 000 O0 0 8 1 1 4 68 0000000000 [,IS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 39 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DSIG PS1 CU 1225229 O0 000 O0 0 8 1 1 4 68 FBAC PS1 CPS 1225229 O0 000 O0 0 8 1 1 4 68 IRAT PS1 1225229 O0 000 O0 0 8 1 1 4 68 IRAT FIL 1225229 O0 000 O0 0 8 1 1 4 68 NBAC PS1 CPS 1225229 O0 000 O0 0 8 1 1 4 68 SFNA PS1 CU 1225229 O0 000 O0 0 8 1 1 4 68 SFFA PS1 CU 1225229 O0 000 O0 0 8 1 1 4 68 SBNA PS1 CU 1225229 O0 000 O0 0 8 1 1 4 68 SBFA PS1 CU 1225229 O0 000 O0 0 8 1 1 4 68 SFNA SIG CU 1225229 O0 000 O0 0 8 1 1 4 68 SFFA SIG CU 1225229 O0 000 O0 0 8 1 1 4 68 SBNA SIG CU 1225229 O0 000 O0 0 8 1 1 4 68 SBFA SIG CU 1225229 O0 000 O0 0 8 1 1 4 68 SFNA FIL CU 1225229 O0 000 O0 0 8 1 1 4 68 SFFA FIL CU 1225229 O0 000 O0 0 8 1 1 4 68 SBNA FIL CU 1225229 O0 000 O0 0 8 1 1 4 68 SBFA FIL CU 1225229 O0 000 O0 0 8 1 1 4 68 SIBF PS1 CU 1225229 O0 000 O0 0 8 1 1 4 68 SFNC PS1 CU 1225229 O0 000 O0 0 8 1 1 4 68 SFFC PS1 CU 1225229 O0 000 O0 0 8 1 1 4 68 SIGM PS1 CU 1225229 O0 000 O0 0 8 1 1 4 68 SIBF SIG CU 1225229 O0 000 O0 0 8 1 1 4 68 SIGM SIG CU 1225229 O0 000 O0 0 8 1 1 4 68 TRAT PS1 1225229 O0 000 O0 0 8 1 1 4 68 TRAT SIG 1225229 O0 000 O0 0 8 1 1 4 68 TRAT FIL 1225229 O0 000 O0 0 8 1 1 4 68 GR PS1 GAPI 1225229 O0 000 O0 0 8 1 1 4 68 RDIX PS1 1225229 O0 000 O0 0 8 1 1 4 68 CRNI PS1 KHZ 1225229 O0 000 O0 0 8 1 1 4 68 CRFI PS1 K2tZ 1225229 O0 000 O0 0 8 1 1 4 68 RSCS PS1 1225229 O0 000 O0 0 8 1 1 4 68 CTM PS1 DEGC 1225229 O0 000 O0 0 8 1 1 4 68 XTM PS1 DEGC 1225229 O0 000 O0 0 8 1 1 4 68 TAV PS1 KV 1225229 O0 000 O0 0 8 1 1 4 68 FICU PSI AMP 1225229 O0 000 O0 0 8 1 1 4 68 CACU PS1 AMP 1225229 O0 000 O0 0 8 1 1 4 68 BUST PS1 1225229 O0 000 O0 0 8 1 1 4 68 BUSP PS1 1225229 O0 000 O0 0 8 1 1 4 68 RSXS PS1 1225229 O0 000 O0 0 8 1 1 4 68 TPHI PS1 PU 1225229 O0 000 O0 0 8 1 1 4 68 TPHI SIG PU 1225229 O0 000 O0 0 8 1 1 4 68 CCLC PS1 V 1225229 O0 000 O0 0 8 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 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 10290.000 CS.PSl 1809.625 TENS.PSi 1374.000 NPHV. PS1 NPDE. PS1 1561.776 NSCE. PS1 2.419 CRRA.PS1 2.079 NSCR.PS1 AQTM. PS1 1.322 CHV. PS1 201.944 CPSV. PS1 5.069 CP2V. PS1 CM2V. PS1 -12.191 RCFR.PS1 0.000 RCLC. PS1 0.000 RCRC. PS1 1572.267 0.054 12.224 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 40 RCAK. PS1 2.000 RTDF. PS1 FSCE. PS1 1.963 FSCR.PS1 HVPV. PS1 161.231 BMCU. PS1 NBEF. PS1 29.591 FBEF. PS1 BSTR.PS1 12.380 BSPR.PS1 XP5V. PS1 5.041 XP2V. PS1 RXLC. PS1 0.000 RXRC. PS1 BSAL.PS1 52.750 BSAL.SIG CIRN. FIL 0.719 CIRF. FIL IRAT. PS1 0.486 IRAT. FIL SFFA.PS1 30.438 SBNA.PS1 SFFA.SIG 0.658 SBNA.SIG SFFA.FIL 29.904 SBNA.FIL SFNC. PS1 27.629 SFFC. PS1 SIGM. SIG 0.503 TRAT. PS1 GR.PS1 45.935 RDIX. PS1 RSCS. PS1 8463.000 CTM. PS1 FICU. PS1 2.318 CACU. PS1 RSXS.PS1 8878.000 TPHI.PS1 0.000 FPHV. PS1 0.019 AQTF. PS1 33.828 GDCU. PS1 61.522 NPGF. PS1 1.157 MARC. PSi 12.025 J~I2V. PS1 0.000 RXAK. PS1 2.814 CIRN. PS1 1.348 DSIG.PS1 0.485 NBAC. PS1 56.116 SBFA.PS1 2.882 SBFA.SIG 54.551 SBFA.FIL 26.702 SIGM. PS1 1.103 TRAT. SIG 100598.000 CRNI.PS1 100.586 XTM. PS1 2.584 BUST. PSi 36.282 TPHI.SIG 1523.439 FPDE. PS1 1.102 SF6P.PS1 59.793 EXCU. PS1 1.003 FPGF. PS1 0.000 XHV. PS1 -12.206 RXFR.PS1 1.000 SHCU. PS1 0.732 CIRF. PS1 1.106 FBAC. PS1 4191.282 SFNA.PS1 45.556 SFNA.SIG 3.965 SFNA.FIL 48.375 SIBF. PS1 26.730 SIBF. SIG 0.022 TRAT. FIL 451.921 CRFI.PS1 99.772 TAV. PS1 0.000 BUSP.PS1 1.047 CCLC. PS1 1508.790 124.112 3.840 0.999 200.903 0.000 35.577 1.341 4338.180 30.942 0.607 31.445 40. 771 1. 025 1.103 217.366 94.984 0.000 O.OO4 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION - O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 41 VENDOR TOOL CODE START DEPTH RST 10308.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9555.5 04 -FEB-98 8C0-069 1700 04-FEB-98 10448.0 10298.0 9568.0 10275.0 1800.0 TOOL NUMBER ........... CGRS-A RST-A 8.500 10448.0 Produced Fluids THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 42 TOOL STANDOFF (IN) '. REMARKS: Thank you for using Schlumberger Depth correlated to SWS CBT (17 Aug 1988) Three pases made with well shut-in (9650-10298) Three passes made with well flowing (9900-10298) Ail passes made @ 1800 ft/hr GR SCALE = 1 TO 1000 DUE TO BARIUM SALT IN CASING chk = 80 during flowing & wfl passes due to floating tool WFL stationary measurements made above & below (5) IC mode Open perforation intervals: 10140-10160' & 10186 - 10212" Well test summary (1-9-98): chk=104, gfr=12555, or=1632, wc=87, gor=4178 tglr=543, whp=712, wht=196, water rate=lO923, gas rate=6819, gl rate=O THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CS PS2 F/HR 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 43 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS PS2 LB 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 NPHV PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 NPDE PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 NSCE PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CRRA PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 NSCR PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 AQTMPS2 S 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CHV PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CPSV PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CP2V PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CM2V PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 RCFR PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 RCLC PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 RCRC PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 RCAK PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 RTDF PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 FPHV PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 FPDE PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 FSCE PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 FSCR PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 AQTF PS2 S 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SF6P PS2 PSIG 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 HVPV PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 BMCU PS2 UA 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 GDCU PS2 MA 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 EXCU PS2 UA 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 NBEF PS2 UA 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 FBEF PS2 UA 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 NPGF PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 FPGF PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 BSTR PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 BSPR PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 MARC PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 XHV PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 XPSV PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 XP2V PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 X~2V PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 RXFR PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 RXLC PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 RXRC PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 RXAK PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SHCU PS2 MA 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL PS2 PPK 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL SIG PPK 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNPS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNFIL 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF FIL 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 DSIG PS2 CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS2 CPS 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 44 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) IRAT FIL 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 NBAC PS2 CPS 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA PS2 CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA PS2 CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA PS2 CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA PS2 CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA SIG CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA SIG CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA SIG CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA SIG CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA FIL CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA FIL CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA FIL CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA FIL CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF PS2 CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SFNC PS2 CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SFFC PS2 CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS2 CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF SIG CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM SIG CU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT SIG 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT FIL 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS2 GAPI 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 RDIX PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CRNI PS2 KHZ 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CRFI PS2 KHZ 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 RSCS PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CTM PS2 DEGC 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 XTM PS2 DEGC 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 TAV PS2 KV 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 FICU PS2 AMP 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CACU PS2 AMP 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 BUST PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 BUSP PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 RSXS PS2 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS2 PU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI SIG PU 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 CCLC PS2 V 1225229 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 10290.000 CS.PS2 1801.279 TENS.PS2 1583.000 NPHV. PS2 NPDE. PS2 1565.171 NSCE. PS2 2.506 CRRA.PS2 2.068 NSCR.PS2 AQTM. PS2 1.102 CHV. PS2 201.944 CPSV. PS2 5.055 CP2V. PS2 CM2V. PS2 -12.211 RCFR.PS2 0.000 RCLC. PS2 0.000 RCRC. PS2 RCAK. PS2 2.000 RTDF. PS2 0.000 FPHV. PS2 1527.101 FPDE. PS2 FSCE. PS2 1.915 FSCR.PS2 -0.006 AQTF. PS2 1.322 SF6P.PS2 HVPV. PS2 161.149 BMCU. PS2 34.238 GDCU. PS2 60.143 EXCU. PS2 1578.370 0.014 12.180 0.000 1509.400 126.364 3.577 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 45 NBEF. PS2 BSTR. PS2 XP5 V. PS2 RXLC. PS2 BSAL.PS2 CIRN. FIL IRAT. PS2 SFFA.PS2 SFFA.SIG SFFA.FIL SFNC. PS2 SIGM. SIG GR.PS2 RSCS. PS2 FICU. PS2 RSXS.PS2 30 175 13 177 5 039 0 000 58 462 0 722 O. 471 29. 816 O. 607 30.260 27.259 O. 559 54.242 8463. 000 2.335 8878. 000 FBEF. PS2 BSPR.PS2 XP2V. PS2 RXRC.PS2 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS2 SBNA.SIG SBNA.FIL SFFC. PS2 TRAT. PS2 RDIX. PS2 CTM. PS2 CACU. PS2 TPHI.PS2 62.409 NPGF. PS2 1.097 MARC. PS2 12.041 XM2V. PS2 0.000 RXAK. PS2 4.191 CIRN. PS2 1.390 DSIG.PS2 0.473 NBAC. PS2 52.463 SBFA.PS2 3.099 SBFA.SIG 54.511 SBFA.FIL 26.945 SIGM. PS2 1.104 TRAT. SIG 152445.000 CRNI.PS2 100.342 XTM. PS2 2.583 BUST. PS2 36.963 TPHI.SIG 0.996 FPGF. PS2 0.000 XHV. PS2 -12.211 RXFR.PS2 1.000 SHCU. PS2 0.724 CIRF. PS2 1.603 FBAC. PS2 3714.186 SFNA.PS2 49.956 SFNA.SIG 3.607 SFNA.FIL 47.813 SIBF. PS2 26.969 SIBF. SIG 0.023 TRAT. FIL 453. 725 CRFI. PS2 99. 154 TAV. PS2 O. 000 BUSP. PS2 1 . 080 CCLC. PS2 1.003 200.789 0.000 28. 617 1.387 4742.228 31.316 O. 646 31.196 42. 859 1. 537 1.105 219.380 94.974 0.000 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~ff4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH RST 10308.0 9575.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 46 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 04 -FEB-98 8C0 - 069 1700 04 -FEB-98 10448.0 10298.0 9568.0 10275.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESEVOIR SATURATION $ TOOL NUMBER ........... CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 10448.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Produced Fluids NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) .. BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 47 Depth correlated to SWS CBT (17 Aug 1988) Three pases made with well shut-in (9650-10298) Three passes made with well flowing (9900-10298) All passes made @ 1800 ft/hr GR SCALE = 1 TO 1000 DUE TO BARIUM SALT IN CASING chk = 80 during flowing & wfl passes due to floating tool WFL stationary measurements made above & below (5) IC mode Open perforation intervals: 10140-10160' & 10186 - 10212" Well test summary (1-9-98): chk=104, gfr=12555, or=1632, wc=87, got=4178 tglr=543, whp=712, wht=196, water rate=lO923, gas rate=6819, gl rate=O THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CS PS3 F/HR 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS3 LB 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 NPHV PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 NPDE PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 48 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) NSCE PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CRRA PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 NSCR PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 AQTMPS3 S 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CHV PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CPSV PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CP2V PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CM2V PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 RCFR PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 RCLC PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 RCRC PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 RCAK PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 RTDF PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 FPHV PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 FPDE PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 FSCE PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 FSCR PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 AQTF PS3 S 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SF6P PS3 PSIG 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 HVPV PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 BMCU PS3 UA 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 GDCU PS3 MA 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 EXCU PS3 UA 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 NBEF PS3 UA 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 FBEF PS3 UA 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 NPGF PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 FPGF PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 BSTR PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 BSPR PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 MARC PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 XHV PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 XPSV PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 XP2V PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 X~2V PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 RXFR PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 RXLC PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 RXRC PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 RXAK PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SHCU PS3 MA 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 BSAL PS3 PPK 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 BSAL SIG PPK 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CIRNPS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CIRF PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CIRNFIL 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CIRF FIL 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 DSIG PS3 CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS3 CPS 1225229 O0 000 O0 0 10 i 1 4 68 0000000000 IRAT PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 IRAT FIL 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 NBAC PS3 CPS 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SFNA PS3 CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 49 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SFFA PS3 CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA PS3 CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA PS3 CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SFNA SIG CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA SIG CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA SIG CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA SIG CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SFNA FIL CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SFFA FIL CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SBNA FIL CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SBFA FIL CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SIBF PS3 CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SFNC PS3 CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SFFC PS3 CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS3 CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SIBF SIG CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM SIG CU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT SIG 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT FIL 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS3 GAPI 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 RDIX PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CRNI PS3 KHZ 1225229 O0 000 O0 0 i0 1 1 4 68 0000000000 CRFI PS3 KHZ 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 RSCS PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CTM PS3 DEGC 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 XTM PS3 DEGC 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 TAV PS3 KV 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 FICU PS3 AMP 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CACU PS3 AMP 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 BUST PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 BUSP PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 RSXS PS3 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS3 PU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI SIG PU 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 CCLC PS3 V 1225229 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 10290.000 CS. PS3 1801.279 TENS.PS3 NPDE. PS3 1565.171 NSCE. PS3 2.506 CRRA.PS3 AQTM. PS3 1.102 CHV. PS3 201.944 CPSV. PS3 5 CM2V. PS3 -12.211 RCFR.PS3 0.000 RCLC. PS3 0 RCAK. PS3 2.000 RTDF. PS3 0.000 FPHV. PS3 1527 FSCE. PS3 1.915 FSCR.PS3 -0.006 AQTF. PS3 1 HVPV. PS3 161.149 BMCU. PS3 34.238 GDCU. PS3 60 NBEF. PS3 30.175 FBEF. PS3 62.409 NPGF. PS3 0 BSTR.PS3 13.177 BSPR.PS3 1.097 MARC. PS3 0 XPSV. PS3 5.039 XP2V. PS3 12.041 XM2V. PS3 -12 1583.000 NPHV. PS3 2 068 NSCR.PS3 055 CP2V. PS3 000 RCRC.PS3 101 FPDE. PS3 322 SF6P. PS3 143 EXCU. PS3 996 FPGF. PS3 000 XHV. PS3 211 RXFR.PS3 1578.370 0.014 12.180 0.000 1509.400 126.364 3.577 1.003 200.789 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 50 RXLC. PS3 BSAL. PS3 CIRN. FIL IRAT. PS3 SFFA. PS3 SFFA. SIG SFFA. FIL SFNC. PS3 SIGM. SIG GR. PS3 RSCS. PS3 FI CU. PS3 RSXS. PS3 DEPT. NPDE. PS3 AQTM. PS3 CM2 V. PS3 RCAK. PS3 FSCE. PS3 HVPV. PS3 NBEF. PS3 BSTR. PS3 XP5 V. PS3 RXLC. PS3 BSAL. PS3 CIRN. FIL IRAT. PS3 SFFA. PS3 SFFA. SIG SFFA. FIL SFNC. PS3 SIGM. SIG GR. PS3 RSCS. PS3 FICU. PS3 RSXS. PS3 0 000 58 462 0 722 0 471 29 816 0 607 30 260 27 2~59 O. 559 54.242 8463. 000 2. 335 8878. 000 9575. 500 1564. 523 O. 441 -12.231 O. 000 1. 898 160. 836 22. 701 14. 093 5. 042 O. 000 70. 516 0.537 0 653 37 533 0 933 37 078 30 551 0 768 1301 055 8459. 000 2. 265 8878. 000 RXRC. PS3 0.000 RXAK. PS3 BSAL.SIG 4.191 CIRN. PS3 CIRF. FIL 1.390 DSIG.PS3 IRAT. FIL 0.473 NBAC. PS3 SBNA.PS3 52.463 SBFA.PS3 SBNA.SIG 3.099 SBFA.SIG SBNA.FIL 54.511 SBFA.FIL SFFC. PS3 26.945 SIGM. PS3 TRAT. PS3 1.104 TRAT. SIG RDIX. PS3 152445.000 CRNI.PS3 CTM. PS3 100.342 XTM. PS3 CACU. PS3 2.583 BUST. PS3 TPHI.PS3 36.963 TPHI.SIG CS. PS3 NSCE. PS3 CHV. PS3 RCFR.PS3 RTDF. PS3 FSCR.PS3 BMCU. PS3 FBEF. PS3 BSPR.PS3 XP2V. PS3 RXRC. PS3 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS3 SBNA.SIG SBNA.FIL SFFC.PS3 TRAT. PS3 RDIX. PS3 CTM. PS3 CACU. PS3 TPHI.PS3 1879 652 2 497 202 308 0 000 0 000 - 0 022 28 418 35.188 1. 182 12. 039 O. 000 3. 009 O. 725 O. 655 62. 715 4.306 57. 630 33. 799 1.146 172339. 000 99. 609 2.576 38. 974 TENS.PS3 CRRA.PS3 CPSV. PS3 RCLC. PS3 FPHV. PS3 AQTF. PS3 GDCU. PS3 NPGF. PS3 MARC. PS3 XM2V. PS3 RXAK. PS3 CIRN. PS3 DSIG. PS3 NBAC. PS3 SBFA.PS3 SBFA.SIG SBFA.FIL SIGM. PS3 TRAT. SIG CRNI.PS3 XTM. PS3 BUST. PS3 TPHI.SIG 1.000 O. 724 1. 603 3714. 186 49. 956 3.607 47.813 26.969 0.023 453.725 99.154 0.000 1.080 1519.000 1.550 5.040 0.000 1530.763 0.441 59.988 1.000 0.000 -12.207 1.000 0.521 -2. 647 2647. 697 49 528 3 791 53 247 33 833 0 030 465 130 99.051 0.000 1.279 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 SFNA.SIG SFNA.FIL SIBF. PS3 SIBF. SIG TRAT. FIL CRFI.PS3 TAV. PS3 BUSP. PS3 CCLC. PS3 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC. PS3 FPDE. PS3 SF6P.PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 SFNA.SIG SFNA.FIL SIBF. PS3 SIBF.SIG TRAT. FIL CRFI.PS3 TAV. PS3 BUSP. PS3 CCLC. PS3 28.617 1.387 4742.228 31.316 0.646 31.196 42.859 1.537 1.105 219.380 94.974 0.000 0.000 1574. 708 O. 012 12.158 O. 000 1510.163 126. 790 6.284 1. 004 200. 837 O. 000 36. 515 O. 707 4403. 617 33. 618 1. 015 34. 414 47.310 1.119 1.140 300. 080 95. 011 O. 000 -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center i3-APR-1998 07:30 PAGE: 51 **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUN~!ARY VENDOR TOOL CODE START DEPTH RST 10286.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) '. TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 9822.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAN~A RAY RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) '. BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 04 -FEB-98 8C0-069 1700 04-FEB-98 10448.0 10298.0 9568.0 10275.0 1800.0 TOOL NUMBER CGRS-A RST-A 8.500 10448.0 Produced Fluids LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 52 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger Depth correlated to SWS CBT (17 Aug 1988) Three pases made with well shut-in (9650-10298) Three passes made with well flowing (9900-10298) All passes made @ 1800 ft/hr GR SCALE = 1 TO 1000 DUE TO BARIUM SALT IN CASING chk = 80 during flowing & wfl passes due to floating tool WFL stationary measurements made above & below (5) IC mode Open perforation intervals: 10140-10160' & 10186 - 10212" Well test summary (1-9-98): chk=104, gfr=12555, or=1632, wc=87, gor=4178 tglr=543, whp=712, wht=196, water rate=lO923, gas rate=6819, gl rate=O THIS FILE CONTAINS THE RAW DATA FOR FLOWING PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 53 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CS FP1 F/HR 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 TENS FP1 LB 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 NPHV FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 NPDE FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 NSCE FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CRRA FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 NSCR FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 AQTMFP1 S 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CHV FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CP5V FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CP2V FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CM2V FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 RCFR FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 RCLC FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 RCRC FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 RCAK FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 RTDF FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 FPHV FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 FPDE FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 FSCE FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 FSCR FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 AQTF FP1 S 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SF6P FP1 PSIG 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 HVPV FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 BMCU FP1 UA 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 GDCU FP1 MA 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 EXCU FP1 UA 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 NBEF FP1 UA 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 FBEF FP1 UA 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 NPGF FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 FPGF FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 BSTR FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 BSPR FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 54 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) MARC FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 XHV FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 XPSV FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 XP2V FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 X~I2V FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 RXFR FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 RXLC FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 RXRC FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 RXAK FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SHCU FP1 MA 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 BSAL FP1 PPK 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 BSAL SIG PPK 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CIRN FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CIRF FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CIRNFIL 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CIRF FIL 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 DSIG FP1 CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC FP1 CPS 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 IRAT FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 IRAT FIL 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 NBAC FP1 CPS 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SFNA FP1 CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SFFA FP1 CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SBNA FP1 CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SBFA FP1 CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SFNA SIG CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SFFA SIG CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SBNA SIG CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SBFA SIG CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SFNA FIL CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SFFA FIL CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SBNA FIL CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SBFA FIL CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SIBF FP1 CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SFNC FP1 CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SFFC FP1 CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM FP1 CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SIBF SIG CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM SIG CU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT SIG 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT FIL 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 GR FP1 GAPI 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 RDIX FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CRNI FP1 KHZ 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CRFI FP1 KHZ 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 RSCS FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CTM FP1 DEGC 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 XTM FP1 DEGC 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 TAV FP1 KV 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 FICU FP1 AMP 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 55 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CACU FP1 AMP 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 BUST FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 BUSP FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 RSXS FP1 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI FP1 PU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI SIG PU 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 CCLC FP1 V 1225229 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. FP1 AQTM. FBi CM2V. FP1 RCAK. FP1 FSCE. FP1 HVPV. FP1 NBEF. FP1 BSTR. FP1 XP5 V. FP1 RXLC. FP1 BSAL.FP1 CIRN. FIL IRAT. FP1 SFFA.FP1 SFFA.SIG SFFA.FIL SFNC.FP1 SIGM. SIG GR.FP1 RSCS.FP1 FICU. FP1 RSXS.FP1 DEPT. NPDE. FP1 AQTM. FP1 CM2 V. FP1 R CAK. FP1 FSCE. FP1 HVPV. FP1 NBEF. FP1 BSTR. FP1 XP5 V. FP1 RXLC. FP1 BSAL. FP1 CIRN. FIL IRA T. FP1 SFFA. FP1 10286.500 1562.463 0.661 -12.211 0.000 1.832 160.889 30.378 11.376 5 040 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 14905.451 8459.000 2.349 8878.000 9822. 500 1563. 417 1. 322 -12. 191 O. 000 1. 896 161. 003 28. 821 12. 895 5. 040 O. 000 16. 059 O. 873 O. 550 27. 546 CS. FP1 NSCE. FP1 CHV. FP1 RCFR. FP1 RTDF. FP1 FSCR. FP1 BMCU. FP1 FBEF. FP1 BSPR. FP1 XP2 V. FP1 RXRC. FP1 BSAL. SIG CIRF. FIL IRAT. FIL SBNA. FP1 SBNA. SIG SBNA. FIL SFFC. FP1 TRAT. FP1 RDIX. FP1 CTM. FP1 CACU. FP1 TPHI. FP1 CS. FP1 NSCE. FP1 CHV. FP1 RCFR. FP1 RTDF. FP1 FSCR. FP1 BMCU. FP1 FBEF. FP1 BSPR. FP1 XP2 V. FP1 RXRC. FP1 BSAL. SIG CIRF. FIL IRAT. FIL SBNA. FP1 1770.782 2.388 201.823 0.000 0.000 -0.065 33.984 58.873 1.061 12.041 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 47865 000 100 098 2 588 -999 250 1825.955 2.494 202.914 0.000 0.000 -0.035 32.773 52.900 1.061 12.033 0.000 2.761 1.729 0.549 53.173 TENS. FP1 CRRA. FP1 CPSV. FP1 RCLC. FP1 FPHV. FP1 AQTF. FP1 GDCU. FP1 NPGF. FP1 MARC. FP1 2242V. FP1 RXAK. FP1 CIRN. FP1 DSIG.FP1 NBAC. FP1 SBFA.FP1 SBFA.SIG SBFA.FIL SIGM. FP1 TRAT. SIG CRNI. FP1 XTM. FP1 BUST. FP1 TPHI.SIG TENS.FP1 CRRA.FP1 CPSV. FP1 RCLC.FP1 FPHV. FP1 AQTF. FP1 GDCU. FP1 NPGF. FP1 MARC. FP1 X~2V. FP1 RXAK. FP1 CIRN. FP1 DSIG.FP1 NBAC. FP1 SBFA.FP1 942.000 i. 938 5. 050 0.000 1528. 322 O. 661 60.012 0.995 0.000 -12 191 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 447. 371 100. 098 O. 000 -999.250 1067.000 1.835 5.026 0.000 1523.439 1.322 59.946 1.000 0.000 -12.208 0.000 0.843 -0.069 2622.221 49.157 NPHV. FP1 NSCR.FP1 CP2V. FPI RCRC. FP1 FPDE. FP1 SF6P. FP1 EXCU. FP1 FPGF. FP1 XHV. FP1 RXFR.FP1 SHCU. FP1 CIRF. FP1 FBAC. FP1 SFNA.FP1 SFNA.SIG SFNA.FIL SIBF. FP1 SIBF. SIG TRAT. FIL CRFI.FP1 TA V. FP1 B USP. FP1 CCLC. FP1 NPHV. FP1 NSCR.FP1 CP2V. FP1 RCRC. FP1 FPDE. FP1 SF6P. FP1 EXCU. FP1 FPGF. FP1 XHV. FP1 Ri~FR.FP1 SHCU. FP1 CIRF. FP1 FBAC. FP1 SFNA.FP1 SFNA. SIG 1574.708 -0.023 12.217 0.000 1508.027 127.302 3.551 0.999 200.612 0.000 31.544 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 230 840 94 888 0 000 0.010 1564.943 0.082 12.180 0.000 1509.019 128.069 4.103 1.002 200.870 0.000 35.035 1.652 4218.374 28.281 0.471 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 56 SFFA.SIG 0.746 SBNA.SIG SFFA.FIL 25.643 SBNA.FIL SFNC. FP1 22.089 SFFC. FP1 SIGM. SIG 0.395 TRAT. FP1 GR.FP1 1030.895 RDIX. FP1 RSCS.FP1 8463.000 CTM. FP1 FICU. FP1 2.318 CACU. FP1 RSXS.FP1 8878.000 TPHI.FP1 2.783 49 068 23 393 0 892 60750 000 99 365 2 579 17 567 SBFA.SIG SBFA.FIL SIGM. FPl TRAT. SIG CRNI. FP1 XTM. FP1 BUST. FP1 TPHI.SIG 5.633 SFNA.FIL 42.045 SIBF. FP1 23.640 SIBF. SIG 0.016 TRAT. FIL 449.203 CRFI.FP1 100.065 TAV. FP1 0.000 BUSP.FP1 0.675 CCLC. FP1 26.875 27.694 0 962 0 899 244 736 94 993 0 000 -999 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE · FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RST 10290.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): STOP DEPTH .......... 9826.5 04-FEB-98 8C0-069 1700 04-FEB-98 10448.0 10298.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 57 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 9568.0 10275.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESEVOIR SATURATION $ TOOL NUMBER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 10448.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Produced Fluids NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger Depth correlated to SWS CBT (17 Aug 1988) Three pases made with well shut-in (9650-10298) Three passes made with well flowing (9900-10298) Ail passes made @ 1800 ft/hr GR SCALE = 1 TO 1000 DUE TO BARIUM SALT IN CASING chk = 80 during flowing & wfl passes due to floating tool WFL stationary measurements made above & below (5)IC mode Open perforation intervals: 10140-10160' & LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 58 10186 - 10212" Well test summary (1-9-98): chk=104, gfr=12555, or=1632, wc=87, gor=4178 tglr=543, whp=712, wht=196, water rate=lO923, gas rate=6819, gl rate=O THIS FILE CONTAINS THE RAW DATA FOR FLOWING PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1225229 O0 000 O0 0 12 1 I 4 68 0000000000 CS FP2 F/HR 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 TENS FP2 LB 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 NPHV FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 NPDE FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 NSCE FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CRRA FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 NSCR FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 AQTMFP2 S 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CHV FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CPSV FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CP2V FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CM2V FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 59 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RCFR FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 RCLC FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 RCRC FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 RCAK FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 RTDF FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 FPHV FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 FPDE FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 FSCE FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 FSCR FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 AQTF FP2 S 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SF6P FP2 PSIG 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 HVPV FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 BMCU FP2 UA 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 GDCU FP2 MA 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 EXCU FP2 UA 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 NBEF FP2 UA 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 FBEF FP2 UA 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 NPGF FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 FPGF FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 BSTR FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 BSPR FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 MARC FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 XHV FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 XPSV FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 XP2V FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 XM2V FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 RXFR FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 RXLC FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 RXRC FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 RXAK FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SHCU FP2 MA 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 BSAL FP2 PPK 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 BSAL SIG PPK 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CIRN FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CIRF FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CIRNFIL 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CIRF FIL 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 DSIG FP2 CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC FP2 CPS 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 IRAT FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 IRAT FIL 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 NBAC FP2 CPS 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SFNA FP2 CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SFFA FP2 CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SBNA FP2 CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SBFA FP2 CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SFNA SIG CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SFFA SIG CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SBNA SIG CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SBFA SIG CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SFNA FIL CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 60 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SFFA FIL CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SBNA FIL CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SBFA FIL CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SIBF FP2 CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SFNC FP2 CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SFFC FP2 CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM FP2 CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SIBF SIG CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM SIG CU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT SIG 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT FIL 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 GR FP2 GAPI 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 RDIX FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CRNI FP2 KHZ 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CRFI FP2 KHZ 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 RSCS FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CTM FP2 DEGC 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 XTM FP2 DEGC 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 TAV FP2 KV 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 FICU FP2 AMP 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CACU FP2 AMP 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 BUST FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 BUSP FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 RSXS FP2 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI FP2 PU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI SIG PU 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 CCLC FP2 V 1225229 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 10290.000 CS.FP2 1221.267 TENS.FP2 800 000 NPHV. FP2 1579.591 -12.113 RCFR.FP2 0.000 RTDF. FP2 1.903 FSCR.FP2 160.645 BMCU. FP2 30.029 FBEF.FP2 11.857 BSPR.FP2 5.040 XP2V. FP2 0.000 RXRC.FP2 2.498 CRRA . FP2 1 202. 066 CPSV. FP2 5 O. 000 RCLC. FP2 0 0.000 FPHV. FP2 1523 0.105 AQTF. FP2 0 33.691 GDCU. FP2 59 57.888 NPGF. FP2 0 1.079 MARC. FP2 0 12.041 XM2V. FP2 -12 0.000 RXAK. FP2 0 -999.250 BSAL.SIG -999.250 CIRN. FP2 -999 NPDE. FP2 1566.964 NSCE. FP2 AQTM. FP2 0.661 CHV. FP2 CM2V. FP2 RCAK. FP2 FSCE. FP2 HVPV. FP2 NBEF. FP2 BSTR. FP2 XP5 V. FP2 RXLC. FP2 BSAL.FP2 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.FP2 -999 IRAT. FP2 -999.250 IRAT. FIL -999.250 NBAC.FP2 -999 SFFA.FP2 -999.250 SBNA.FP2 -999.250 SBFA.FP2 -999 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999 SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999 SFNC. FP2 -999.250 SFFC. FP2 -999.250 SIGM. FP2 -999 928 NSCR.FP2 -0.170 040 CP2V. FP2 12.173 000 RCRC. FP2 O. 000 439 FPDE. FP2 1509.591 661 SF6P.FP2 128.325 684 EXCU. FP2 3.551 992 FPGF. FP2 1.002 000 XHV. FP2 200.854 211 RXFR.FP2 0.000 000 SHCU. FP2 31.219 250 CIRF. FP2 -999.250 250 FBAC. FP2 -999.250 250 SFNA.FP2 -999.250 250 SFNA.SIG -999.250 250 SFNA.FIL -999.250 250 SIBF. FP2 -999.250 250 SIBF. SIG -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 61 SIGM. SIG -999.250 TRAT. FP2 -999.250 TRAT. SIG GR.FP2 15295.752 RDIX.FP2 63662.000 CRNI.FP2 RSCS.FP2 8459.000 CTM. FP2 98.633 XTM. FP2 FICU. FP2 2.285 CACU. FP2 2.588 BUST. FP2 RSXS.FP2 8878.000 TPHI.FP2 -999.250 TPHI.SIG DEPT. NPDE. FP2 AQTM. FP2 CM2V. FP2 RCAK.FP2 FSCE.FP2 HVPV. FP2 NBEF. FP2 BSTR. FP2 XP5V. FP2 RXLC. FP2 BSAL.FP2 CIRN. FIL IRAT. FP2 SFFA.FP2 SFFA.SIG SFFA.FIL SFNC. FP2 SIGM. SIG GR.FP2 RSCS.FP2 FICU. FP2 RSXS.FP2 9826.500 1566.240 0 661 -12 113 0 000 1 904 160 819 29 162 11.960 5.039 0.000 17.424 O. 749 0.540 35. 821 O. 715 35. 384 35.326 0.643 1144.231 8459.000 2.291 8878.000 CS.FP2 NSCE. FP2 CHV. FP2 RCFR.FP2 RTDF. FP2 FSCR.FP2 BMCU. FP2 FBEF. FP2 BSPR.FP2 XP2V. FP2 RXRC. FP2 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.FP2 SBNA.SIG SBNA.FIL SFFC. FP2 TRA T. FP2 RDIX. FP2 CTM. FP2 CACU. FP2 TPHI.FP2 1815.662 TENS.FP2 2.504 CRRA.FP2 202.066 CP5V. FP2 0.000 RCLC.FP2 0.000 FPHV. FP2 -0.015 AQTF. FP2 33.252 GDCU. FP2 51.574 NPGF. FP2 1.155 MARC.FP2 12.030 XM2V. FP2 0.000 RXAK.FP2 2.748 CIRN. FP2 1.113 DSIG.FP2 0.544 NBAC. FP2 49.629 SBFA.FP2 3.043 SBFA.SIG 46.349 SBFA.FIL 34.710 SIGM. FP2 1.248 TRAT. SIG 76413.000 CRNI.FP2 101.074 XTM. FP2 2.582 BUST.FP2 40.272 TPHI.SIG -999.250 452.726 100.098 0.000 -999.250 1016.000 1.769 5.069 0.000 1523.439 0.661 59.871 0.995 0.000 -12.207 1.000 0.769 0.875 2753.579 35.388 3.442 38.635 34.330 0.026 447.015 100.098 0.000 1.185 TRAT. FIL CRFI.FP2 TAV. FP2 BUSP.FP2 CCLC. FP2 NPHV. FP2 NSCR.FP2 CP2V. FP2 RCRC. FP2 FPDE.FP2 SF6P.FP2 EXCU. FP2 FPGF. FP2 XHV. FP2 RXFR.FP2 SHCU. FP2 CIRF. FP2 FBAC. FP2 SFNA.FP2 SFNA.SIG SFNA.FIL SIBF. FP2 SIBF. SIG TRAT. FIL CRFI. FP2 TAV. FP2 BUSP.FP2 CCLC. FP2 -999.250 234. 849 94. 888 O. 000 O. 026 1574. 708 -0. 004 12.231 0.000 1510. 583 128. 380 4.114 0.997 200. 941 0 000 35 911 1 100 4444 974 34 721 0 653 34. 748 28. 170 O. 959 1.243 252. 758 94. 980 0.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 62 FILE HEADER FILE NUMBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SU~mL~RY VENDOR TOOL CODE START DEPTH RST 10291.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9824.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAB~A RAY RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 04-FEB-98 8C0-069 1700 04-FEB-98 10448.0 10298.0 9568.0 10275.0 1800.0 TOOL NUMBER ........... CGRS-A RST-A 8.500 10448.0 Produced Fluids THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 63 TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger Depth correlated to SWS CBT (17 Aug 1988) Three pases made with well shut-in (9650-10298) Three passes made with well flowing (9900-10298) All passes made @ 1800 ft/hr GR SCALE = 1 TO 1000 DUE TO BARIUM SALT IN CASING chk = 80 during flowing & wfl passes due to floating tool WFL stationary measurements made above & below (5) IC mode Open perforation intervals: 10140-10160' & 10186 - 10212" Well test summary (1-9-98): chk=104, gfr=12555, or=1632, wc=87, gor=4178 tglr=543, whp=712, wht=196, water rate=lO923, gas rate=6819, gl rate=O THIS FILE CONTAINS THE RAW DATA FOR FLOWING PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR~1998 07:30 PAGE: 64 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CS FP3 F/HR 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 TENS FP3 LB 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 NPHV FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 NPDE FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 NSCE FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CRRA FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 NSCR FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 AQTMFP3 S 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CHV FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CP5V FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CP2V FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CM2V FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 RCFR FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 RCLC FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 RCRC FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 RCAK FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 RTDF FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 FPHV FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 FPDE FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 FSCE FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 FSCR FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 AQTF FP3 S 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SF6P FP3 PSIG 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 HVPV FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 BMCU FP3 UA 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 GDCU FP3 MA 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 EXCU FP3 UA 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 NBEF FP3 UA 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 FBEF FP3 UA 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 NPGF FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 FPGF FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 BSTR FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 BSPR FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 MARC FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 XHV FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 XPSV FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 XP2V FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 ~2V FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 RXFR FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 RXLC FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 RXRC FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 RXAK FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SHCU FP3 MA 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 BSAL FP3 PPK 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 BSAL SIG PPK 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CIRNFP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CIRF FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CIRNFIL 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CIRF FIL 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 65 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DSIG FP3 CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC FP3 CPS 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 IRAT FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 IRAT FIL 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 NBAC FP3 CPS 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SFNA FP3 CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SFFA FP3 CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SBNA FP3 CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SBFA FP3 CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SFNA SIG CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SFFA SIG CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SBNA SIG CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SBFA SIG CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SFNA FIL CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SFFA FIL CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SBNA FIL CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SBFA FIL CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SIBF FP3 CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SFNC FP3 CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SFFC FP3 CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM FP3 CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SIBF SIG CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM SIG CU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT SIG 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT FIL 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 GR FP3 GAPI 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 RDIX FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CRiVI FP3 KHZ 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CRFI FP3 KHZ 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 RSCS FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CTM FP3 DEGC 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 XTM FP3 DEGC 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 TAV FP3 KV 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 FICU FP3 AMP 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CACU FP3 AMP 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 BUST FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 BUSP FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 RSXS FP3 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI FP3 PU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI SIG PU 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 CCLC FP3 V 1225229 O0 000 O0 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. 10290.000 CS.FP3 1832.621 TENS.FP3 991.000 NPHV. FP3 NPDE.FP3 1565.706 NSCE. FP3 2.507 CRRA.FP3 1.969 NSCR.FP3 AQTM. FP3 0.661 CHV. FP3 201.581 CPSV. FP3 5.089 CP2V. FP3 CM2V. FP3 -12.172 RCFR.FP3 0.000 RCLC. FP3 0.000 RCRC.FP3 1574.708 -0.049 12.173 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 66 RCAK. FP3 FSCE.FP3 HVPV. FP3 NBEF. FP3 BSTR.FP3 XP5 V. FP3 RXLC. FP3 BSAL. FP3 CIRN. FIL IRAT. FP3 SFFA.FP3 SFFA.SIG SFFA.FIL SFNC.FP3 SIGM. SIG GR.FP3 RSCS.FP3 FICU. FP3 RSXS.FP3 0 000 1 916 160 645 29 771 12 376 5 050 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 9270 598 8463 000 2 349 8878 000 DEPT. 9824.500 NPDE. FP3 1564.218 AQTM. FP3 1.102 CM2V. FP3 -12.191 RCAK. FP3 O. 000 FSCE. FP3 1.917 HVPV. FP3 161 . 272 NBEF. FP3 28.167 BSTR. FP3 12.216 XPSV. FP3 5.041 RXLC. FP3 0.000 BSAL.FP3 13.866 CIRN. FIL 0.846 IRAT. FP3 0.540 SFFA.FP3 27.196 SFFA.SIG 0.757 SFFA.FIL 26.509 SFNC. FP3 24.344 SIGM. SIG 0.443 GR.FP3 1057.869 RSCS.FP3 8463.000 FICU. FP3 2.288 RSXS.FP3 8878.000 RTDF.FP3 FSCR.FP3 BMCU. FP3 FBEF. FP3 BSPR.FP3 XP2V. FP3 RXRC. FP3 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.FP3 SBNA.SIG SBNA.FIL SFFC. FP3 TRAT. FP3 RDIX. FP3 CTM. FP3 CACU. FP3 TPHI.FP3 CS.FP3 NSCE.FP3 CHV. FP3 RCFR.FP3 RTDF. FP3 FSCR.FP3 BMCU. FP3 FBEF. FP3 BSPR.FP3 XP2V. FP3 RXRC. FP3 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.FP3 SBNA.SIG SBNA.FIL SFFC.FP3 TRAT. FP3 RDIX. FP3 CTM. FP3 CACU. FP3 TPHI.FP3 0.000 FPHV. FP3 0.023 AQTF. FP3 33.398 GDCU. FP3 58.619 NPGF.FP3 0.980 MARC. FP3 12.041 XM2V. FP3 0.000 RXAK. FP3 -999.250 CIRN. FP3 -999.250 DSIG.FP3 -999.250 NBAC.FP3 -999.250 SBFA.FP3 -999.250 SBFA.SIG -999.250 SBFA.FIL -999.250 SIGM. FP3 -999.250 TRAT. SIG 80249.000 CRNI.FP3 101.074 XTM. FP3 2.583 BUST. FP3 -999.250 TPHI.SIG 1837.344 TENS.FP3 2.496 CRRA.FP3 202.066 CPSV. FP3 0.000 RCLC.FP3 0.000 FPHV. FP3 0.035 AQTF.FP3 33.001 GDCU. FP3 52.018 NPGF. FP3 1.018 MARC. FP3 12.035 X~I2V. FP3 0.000 ~.FP3 2.776 CIRN. FP3 1.609 DSIG.FP3 0.546 NBAC.FP3 53.099 SBFA.FP3 2.818 SBFA.SIG 52.621 SBFA.FIL 24.554 SIGM. FP3 0.993 TRAT. SIG 92996.000 CRNI.FP3 100.830 XTM. FP3 2.577 BUST. FP3 21.743 TPHI.SIG 1523.439 0.661 60.668 1 001 0 000 -12 211 0 000 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 450.727 99.609 0.000 -999.250 978.000 1.847 5.050 0.000 1524.659 1.102 59.918 1. 005 0.000 -12.210 0.000 0.818 0.118 2826.473 41.309 5.733 41.881 24.887 O. 017 465. 838 100.167 0.000 0.784 FPDE.FP3 SF6P.FP3 EXCU. FP3 FPGF. FP3 XHV. FP3 RXFR.FP3 SHCU. FP3 CIRF. FP3 FBAC.FP3 SFNA.FP3 SFNA.SIG SFNA.FIL SIBF. FP3 SIBF. SIG TRAT. FIL CRFI.FP3 TA V. FP3 B USP. FP3 CCLC. FP3 NPHV. FP3 NSCR.FP3 CP2V. FP3 RCRC. FP3 FPDE.FP3 SF6P. FP3 EXCU. FP3 FPGF. FP3 XHV. FP3 RXFR.FP3 SHCU. FP3 CIRF. FP3 FBAC.FP3 SFNA.FP3 SFNA.SIG SFNA.FIL SIBF. FP3 SIBF. SIG TRAT. FIL CRFI.FP3 TAV. FP3 BUSP.FP3 CCLC. FP3 1510.774 128.325 3.551 O. 996 200. 854 O. 000 32.845 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 228.915 95.031 0.000 0.020 1569.825 0.026 12.151 0.000 1510.011 128.673 4.002 1.003 201.096 0.000 35.934 1.668 4266.004 29.514 0.497 27.924 26.931 0 964 0 962 252 244 94 990 0 000 -999 250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-APR-1998 07:30 PAGE: 67 **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/04/ 9 ORIGIN : FLIC TAPE NAME : 98080 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : BP EXPLORATION, 2-28/P-19 MPI, ENDICOTT, API# 50-029-21847-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/04/ 9 ORIGIN : FLIC REEL NAME : 98080 CONTINUATION # : PREVIOUS REEL : CO~k4ENT : BP EXPLORATION, 2-28/P-19 MPI, ENDICOTT, API# 50-029-21847-00