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184-005
STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack ~a. Well Status: [] Oil [] Gas [] Plugged [] Abandoned [] Suspended [] WAG lb. Well Class: 20AAC 2S.105 20AAC 2S. ll0 [] Development [] Exploratory [] GINJ [] WlNJ [] WDSPL No. of Completions Zero Other [] Stratigraphic [] Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit Number BP Exploration (Alaska) Inc. 6/1/2003 .~ 184-005 303-118 3. Address: 6. Date Spudded 13. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 03/20/1984 50-029-21068-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Number Surface: 04/07/1984 M PL-01 1970' SNL, 158' EWL, SEC. 08, T13N, R10E, UM 8. Elevation in feet (indicate KB, DF, etc.) 15. Field and Pool Top of Productive Horizon: 2251' SNL, 102' EWL, SEC. 08, T13N, R10E, UM KBE = 56' Milne Point Unit / Kuparuk River Sands Total Depth: 9. Plug Back Depth (MD+TVD) 2393' SNL, 324' WEL, SEC. 07, T13N, R10E, UM 7434 + 7398 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Lease Designation and Serial No. Surface: x- 544759 y- 6031499 Zone- ASP4 9500 + 9421 Ft ADL025509 TPI: x- 544705 Y- 6031217 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 544281 Y- 6031073 Zone- ASP4 N/A MD Milne Point Unit 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey [] Yes [] No N/A MSL 1800' (Approx.) 21. Logs Run: DIL - SFL, BHC Sonic, FDC-CNL, NGT, HDT 22. CASING, LINER AND CEMENTING RECORD CASING ' .. · SETTING DEPTH . HOLE ' '. ' .'. " .. SIZE..' ... WT,' PER''FT::' '" 'GRADE....... '".:~ "TOP ...... :'"BOTTOM ' "'" .StZE' · .', CEMENTING RECORD,. .... . .~ :'AMOUNT PULLED. 13-3/8" 72# L-80 Surface 130' 17-1/2" To Surface 9-5/8" 47# L-80 Surface 2483' 12-1/4" 1000 sx CS Ill, 750 CS II 7" 29# L-80 BTRS Surface 7523' 8-1/2" 750 sx Class 'G', 600 sx Class 'G' Downsqueezed: 100 sx CS I 23. Perforations op. en to Production (MD + TVD of To,,p an_d, 24.." ' · TUBING RECORD .. Bottom Interval, Size and Number; if none, state 'none ): SIZE DEPTH SET (MD) PACKER SET (MD) None N/A MD TVD MD TVD 25, .. .. '. ' '.ACID, FRACTURE, CEMENT SQUEEZE, ETC.. ".' ' ' ... , , DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7035' Set ClBP with Whipstock on top 6990' Set 1st Whipstock 6968' Set 2nd Whipstock 26. 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 I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED I~ OIL-DEL GAS-MCF WATER-BBL O~L GRAViTY-APl (CORR) Press. 24-HOUR RATE~ 27. CORE DATA ....... !';'., !i ..:, ~.,.-~,. ,; ,;.,1 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "noneS. ~(~ . None 9~ O,.C..r,..~,~,.c,.~ ~3t* "Ct. rd , ,. Form 10-407 Revis~:~.(~iNE~ AUG ~ 0 2003 CONTINUED ON REVERSE S,DE L~. -,.- , GEOLOGIC MARKEF~,' 29. {r ~:ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". UPPER CRETACEOUS None Top 3527' 3527' MA 3797' 3796' NA 4054' 4053' OA 4224' 4223' OB 4312' 4311' KUPARUK Kuparuk C 7066' 7038' LZ 7068' 7040' Kuparuk A 7157' 7127' LK1 7160' 7130' LK2 7186' 7155' SAG RIVER 8936' 8891' SHUBLIK 9022' 8953' SADLEROCHIT 9271' 9054' , ,:. ', . , ' 30. List of Attachments: Summary of Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed SondraSt~e TechnicalAssistant Date MPL-01 184-005 303-118 Prepared By Name/Nurnber: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. Drilling Engineer: Mark Johnson, 564-5666 GENERAL: INSTRUCTIONS 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 la: ITEM 4b: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). ITEM 8: ITEM 13: ITEM 20: The Kelly Bushing elevation in feet above mean Iow Iow water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The APl number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). True vertical thickness. ITEM 22: ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: MPL-01 Common Well Name: MPL-01 Spud Date: 5/17/2003 Event Name: REENTER+COMPLETE Start: 5~26~2003 End: 6/14/2003 Contractor Name: NORDIC CALISTA Rig Release: 6/14/2003 Rig Name: NORDIC 2 Rig Number: N2 · Date From - To Hours Task Code NPT Phase Description of Operations 5~26~2003 18:oo - oo:o0 6.00 MOB P PRE Rig move from W Pad to MPL-01 location. 5/27/2003 00:00 - 06:00 6.00 MOB P PRE Moving to MPL-01 location. At 0600 hrs rig at Milne Camp waiting on crew change. 06:00 - 11:30 5.50 MOB P PRE Continue to move to location. 11:30 - 14:30 3.00 MOB P PRE Level out around cellar. Set matting boards. Spot rig. 14:30 - 17:00 2.50 MOB P PRE RU rig Spot auxilary equipment. 17:00 - 19:00 2.00 MOB P PRE Authorization to Proceed Meeting + prespud meeting held at Milne Pt base camp. Attended by Milne Cps,Safety,and Enviro. Nortic, Dowell Schlumberger, Mi,Centraliff, BP CTD 19:00- 21:30 2.50 MOB P PRE Continue to RU rig. 21:30 - 22:00 0.50 MOB P PRE Pull back pressure valve with lubricator. 22:00 - 00:00 2.00 MOB P PRE Test lines and stage vac trucks with Hot seawater. 5/28/2003 00:00 - 01:00 1.00 MOB P PRE Continue to RU for well kill. Monitor well. Tubing pressure 1100 psi, Annulus pressure 1140 psi. 01:00 - 04:00 3.00 KILL P DECOMP Circulate hot Seawater to clean up well. Circulate @ 3bpm with 1330 psi. No losses. 04:00 - 08:00 4.00 KILL P DECOMP Pump 40 bbl 10.7 ppb pill and displace with 10.9 brine, Bullhead 25 bbl of pill to the formation at 1.1bpm (530 psi initial injection pressure and 640 psi final injection pressure). Continue to circulate 10.9ppg brine around with 840 psi at 3 bpm. 50% losses. Reduce rate to 1.5 bpm at 260 psi. Losses decreased significantly. 08:00 - 09:00 1.00 KILL P DECOMP Monitor well, both tubing and IA on vacuum. CA pressure is zero. Well is dead. 09:00- 12:00 3.00 WHSUR P DECOMP Cameron wellhead specialist on location. PT 7" Casing Packoff. PT to 1,000psi for 30min. Good test. 12:00 - 12:30 0.50 WHSUR P DECOMP Install two way check prior to removing tree. 12:30 - 13:30 1.00 VVHSUR P DECOMP ND tree and THA. Inspect 2-7/8" tubing hanger running threads, good condition. 13:30- 13:45 0.25 BOPSUI; P DECOMP Hold PJSM to discuss BOP NU procedure. Decide to remove 7-1/16" stack from cellar for clearance to NU 13-5/8". 13:45 - 14:30 0.75 BOPSUI; P DECOMP Remove 7-1/16" BOPs from cellar. Mount on stand. Set off on location. 14:30 - 14:45 0.25 BOPSUI; P DECOMP PU 11" tubing head x 13-5/8" XO, position in cellar. 14:45 - 15:00 0.25 BOPSUi; P DECOMP PJSM prior to NU 13-5/8" BOP stack. Review procedure, discuss good communication, fall protection and pinch points. 15:00 - 17:45 2.75 BOPSUI; P DECOMP Install 11" tubing head x 13-5/8" drilling spool. Variables, mud cross, Double gate and Annular. 17:45- 18:00 0.25 BOPSUF P DECOMP Tech limits 18:00 - 23:30 5.50 BOPSUI; P DECOMP Continue to NU BOP's. NU annular preventer, riser and BOP control liner. 23:30 - 00:00 0.50 RIGU P DECOMP Remove rig sign and lift ESP spooling equipment thru roof of pipe shed. 5~29~2003 00:00 - 02:00 2.00 RIGU P DECOMP Continue to lift ESP spooling equipment to rig floor. Interrupted BOP rig up based on availability of crane. 02:00 - 07:00 5.00 BOPSUR P DECOMP Continue to make up riser and BOP control lines. 07:00 - 13:00 6.00 BOPSUR P DECOMP Begin BOP test. Call out GBR to extend 16" riser between BOPs and rig floor. Troubleshoot leaks in 3" gray-loc connections on choke and kill line. Replace Gray- Icc fittings. 13:00 - 15:30 2.50 BOPSUR N RREP DECOMP Wait on Gray Icc fittings. Replace Gray- Icc fittings. 15:30 - 00:00 8.50 BOPSUR P DECOMP Continue BOP test with John Spaulding as AOGCC witness. Had to rebuild one HCR. 5~30~2003 00:00 - 02:00 2.00 BOPSUR P DECOMP LD test joint. PU mouse hole. Clear floor. Printed: 6116/2003 2:05:08 PM BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: MPL-01 Common Well Name: MPL-01 Spud Date: 5/17/2003 Event Name: REENTER+COM PLETE Start: 5~26~2003 End: 6/14/2003 Contractor Name: NORDIC CALISTA Rig Release: 6/14/2003 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 5~30~2003 02:00 - 03:00 1.00 RIGU P DECOMP Pull CT to rig floor and stab coil. 03:00 - 05:00 2.00 RIGU N WAIT DECOMP RU ESP shieve. Wait on pup to extend 4ES lubricator. 05:00 - 06:30 1.50 RIGU P DECOMP RU lubricator to pull TWC. 06:30 - 07:45 1.25 WHSUR P DFCOMP Pull two way check. LD Lubricator. 07:45 - 08:00 0.25 PULL P DECOMP PJSM. Review plan forward for pulling tubing hanger, tubing, ESP cable and ESP. Discuss hazards and risks. 08:00 - 09:00 1.00 PULL P DECOMP PU 2-7~8" landing jr. Back out lock down screws (LDS). Pull tubing hanger. PU wt=50K SO wt=38K 09:00 - 10:00 1.00 PULL P DECOMP Route ESP cable over sheave and onto spooler. Change out Farr tong dies to get proper grip on tbg collars. 10:00 - 20:00 10.00 PULL P DECOMP Pull 3 jts and first GLM. All appear to be in good condition. Fill hole using trip tank. Took about 5 bbls. Once filled, fluid level dropping very slowly. Continue to POOH with 2-7/8" EUE 8 rd .50 completion. ESP cable spooler working well. 20:00 - 21:30 1 PULL I P DECOMP LD ESP. ESP NORM'd by Centralift. Pipe inspected by APl. 21:30 - 22:15 0.75 PULL I P DECOMP Clear floor. Fill hole. Monitor well. Loss 8 bbl to fill. 22:00 - 22:30 0.50= PULL P DECOMP Continue to clear floor. Remove 8 damaged joints. (1 punched,4 bad pins, 2 bad boxes and 1 exterior damage gouge). 22:30 - 23:30 1.00 PULL N DECOMP Airboot on riser leaked while filling well with brine. Clean up 15 gal Brine spill. 14 gal in containment 1 on pad. ( IR# 2003-1R-524437 ) 23:30 - 00:00 0.50 PULL P DECOMP RU floor to MU casing scraper for drift run. Scraper has 3-1/2 IF connection. Need to RU Eckley 5-1/2" power tongs to torque it and the subsequent R'I-rS asssembly. 5/31/2003 00:00 - 03:45 3.75 PULL P DECOMP PU Eckel 5-1/2" power tongs and RU tongs, hydraulic lines. Repair leaks .03:45 - 04:30 0.75 PULL P DECOMP PU drift ( casing scraper) and 3 stands of tubing and RIH. POH to surface. 04:30 - 07:00 2.50 PULL P DECOMP RIH with 14-1/2 stands ( damaged one joint) 2-7/8" tubing RTTS and two stands tubing. Set RTTS. 07:00 - 08:30 1.50 PULL P DECOMP Fill hole between RTTS and blinds. Close blinds. Pressure test 7" RTTS w/SSC valve. Cameron monitoring the 7" Casing packoff. OA=0psi, IA=0psi at start. Pressure slowly to 2000psi, IA tracking WHP, 0psi on 7" packing test port. Increase to 3500psi, 0psi on test port. Good test. Evacuate stack. !08:30 - 08:45 0.25 BOPSUF P DECOMP PJSM on ND 13-5/8" stack !08:45 - 13:15 4.50 BOPSUF P DECOMP Disconnect hydraulics. ND riser, 13-5/8" annular and 13-5/8" upper doublegate. Inspect riser failure: likely stem failure on air boot, plan to replace air boot. 13:15 - 14:00 0.75 BOPSUF N WAIT DECOMP Re-align 7-1/16" doublegates with respect to rest of stack. Wait on 11" x 13-5/8" XO to place above 13-5/8" mudcross. :14:00- 15:30 1.50 BOPSUF'~P DECOMP NU XO 11" x 13-5/8" on top of 13-5/8" mudcross. 15:30 - 16:00 0.50 BOPSUF'~P DECOMP PJSM on NU 7-1/16" stack 16:00 - 23:45 7.75 BOPSUF:P DECOMP NU 7-1/6" BOP Stack ( Top down: annular, double gate w/blind shear & 2-3/8" pipe/slip, mud cross, double gate w/VBR& 2-3/8 combi, 7" full opening MV, XO 7" x 11", XO 11" x 13-5/8", 13-5/8" mud cross, 13-5/8" single gate) 23:45 - 23:55 0.17 BOPSUF:P DECOMP PJSM for BOP test. 23:55 - 00:00 0.08 BOPSUF:P DECOMP BOP test. AOGCC John Spalding waived witnessing the BOP test. 6/1/2003 00:00 - 05:00 5.00 BOPSUF:P DECOMP Continue BOP test. AOGCC John Spalding waived witnessing Printed: 6116/2003 2;05:08 PM BP EXPLORATION Page 3 of 12 Operations Summary Report Legal Well Name: MPL-01 Common Well Name: MPL-01 Spud Date: 5/17/2003 Event Name: REENTER+COMPLETE Start: 5~26~2003 End: 6/14/2003 Contractor Name: NORDIC CALISTA Rig Release: 6/14/2003 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 6/1/2003 00:00 - 05:00 5.00 BOPSUF P DECOMP test. Test good. No failures. E-mail results to AOGCC. 05:00 - 06:15 1.25 BOPSUF P DECOMP PJSM before RIH to retrieve R'I-FS. RIH. Engage packer. Open SSC valve & check for pressure under packer. POH with packer. 06:15 - 06:45 0.50 BOPSUF P DECOMP LD RTTS packer & SSC valve. 06:45 - 07:15 0.50 BOPSUF P DECOMP Tech limits meeting, discuss plan forward. 07:15 - 08:00 0.75 BOPSUF P DECOMP Stand back 14 stands of 2-7~8" tubing. Fill hole, took 8bbls to fill the hole. 08:00 - 09:00 1.00 RIGU P WEXlT RU Schlumberger Eline unit. 09:00 - 09:15 0.25 RIGU P WEXlT PJSM on eline ops 09:15 - 09:30 0.25 RIGU P WEXlT Cont RU Schlumberger Eline unit 09:30 - 10:00 0.50 STWHIP P WEXlT PU junkbasket, 6.04" gauge ring, CCL on eline. 10:00 - 13:00 3.00 STWHIP P WEXlT RIH with drift assembly on eline. Sit down at 6800', work past. Drift to 7,060'md. 13:00 - 13:45 0.75 STWHIP P WEXlT LD Drift assembly and PU ClBP (5.687" OD). Found metal band in junk basket and several chunks of rubber. PU setting tools for ClBP, missing XO to ClBP for eline set. 13:45 - 15:30 1.75 STWHIP N WEXIT Wait for Baker to retrieve XO. Review tool requirements for running whipstock with SLB & Baker (again). 15:30 - 16:00 0.50 STWHIP P WEXlT MU Baker ClBP on SLB e-line setting tool with GR/CCL. 16:00 - 18:15 2.25 STVVHIP P WEXIT RIH with bridge plug. Log in and set at 7035'. 18:15- 19:30 1.25 STWHIP P WEXIT POH. 19:30 - 19:45 0.25 STVVHIP P WEXlT Pressure test BP and casing to 1500 psi. Good Test. 19:45 - 20:45 1.00 STWHIP P WEXlT PU Whip stock. 20:45 - 21:45 1.00 STWHIP P WEXIT RIH with whipstock. 21:45 - 22:45 1.00 STWHIP P WEXlT Log in correct +3'. make multiple passes at various speeds but at 14 degrees iinclination tool not rotating. Set WS with top at STWHIP 6990' 30R. 22:45 - 23:30 0.75 P WEXlT POH. 23:30 - 00:00 0.50 STWHIP P WEXlT LD whipstock setting tool and RD "E" line. 6~2~2003 00:00 - 00:30 0.50 STVVHIP P WEXlT Continue to RD E line. 00:30 - 01:30 1.00 STWHIP P WEXlT MU coil connector pull 35k. MU milling BHA. 01:30 - 01:45 0.25 STWHIP P WEXlT Circulate to fill coil. 01:45 - 02:20 0.58 STWHIP P WEXlT MU BHA #1 window milling. Pressure test coil connector to 3500 psi. OK. MU BHA to Coil connector and stab injector on to well. 02:20 - 03:40 1.33 STWHIP P WEXlT RIH. Tag at 6989.9 Correct to pinch point add 4.6'. Corrected tag 6994.5'. 03:40 - 04:12 0.53 STWHIP P WEXIT Mill with 2.6 BPM at 2630 psi. FS. Up wt 31K, DN wt 7K, 60 psi MW. WOB 1700. ROP 34 Milling Ilike casing is thin. Making progress with little motor work and little WOB. Mill to 7001.1 midway point? ~04:12 - 04:35 0.38 STWHIP P WEXIT Park at 7000.1 Mill to 7002. Set brake mill off almost immediately at 7002.8 motor work 270 psi. Mill to 7002.9. Pick up and retag. 7004.2 Clean pick up. 04:35 - 05:00 0.42 STWHIP'P WEXlT Mill 2.6 bpm at 2,950 psi 220 psi MW, VVOB 0-2K. At 7003.2 Getting steady motor work. Acts like pinch point. Possible Helical buckling pipe in 7" explaines erratic behavior. 05:00 - 07:30 2.50 S'FWHIP P WEXIT Mill 2.6 bpm at 2940 psi. FS = 2630 psi. Mill to 7007.2' Lose pump #2. Switch to pump #1 on the fly, did not come on line quickly enough. Motor stalls. PU off bottom. 07:30 - 08:45 1.25 STWHIP P WEXIT FS = 2625psi. Ease back down into milling, 0.3fpm. See motor work at 7002', likely top of whipstock. Continue rih to 7007', see Printed: 6116/2003 2:05:08 PM BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: MPL-01 Common Well Name: MPL-01 Spud Date: 5/17/2003 Event Name: REENTER+COMPLETE Start: 5~26~2003 End: 6/14/2003 'Contractor Name: NORDIC CALISTA Rig Release: 6/14/2003 Rig Name: NORDIC 2 Rig Number: N2 Date From-To Hours Task Code NPT Phase Description of Operations 6/2/2003 07:30 - 08:45 1.25 STWHIP P WEXIT motor work. Mill 2.6bpm, 2820psi. 200psi MW, WOB 0-2.5K Mill to 7008.1 08:45 - 09:30 0.75 STWHIP P WEXIT Mill 2.6bpm at 2970psi. See wt back at 7009.5'md, may be off the tray. No addtional motor work as we slack off. 09:30- 11:00 1.50 S'I'WHIP P WEXIT Mill to 7013'md, motor stall. PU, pull heavy to 70K near 7006'. RBIH, stall. PU to 70K, stall. Unable to pull free. Continue to work pipe, unable to push/pull free, trying to get the motor working again. 1.3bpm 3360psi, seeing higher pressures at lower pump rate. Looks like we are stuck at the bit, pumping through a stalled motor. 11:00 - 13:00 2.00 S'I'WHIP N DPRB WEXIT Discuss options with town. Continue to circulate at 1.3bpm. 13:00 - 13:20 0.33~ STWHIP N DPRB WEXIT Pressure up backside to 1000psi. Slack off, set down, no movement. PU to 65K, no movement. Bleed WHP, PU to 75K while circulating, drop pumps. Still stuck. 13:20 - 14:45 1.42 STWHIP, N DPRB WEXIT Drop 7/8" steel ball to disconnect, circulate at 1.6bpm, 3950psi, ball went over the top at 43bbls (12bbls late). Ball on seat at 56.5bbls. Trip pumps at 4400psi, no indication of shearing seat. Run up to 4700psi, nothing, run up to 5,000psi this is Max pressure. No indication of seat shearing. Call out pump truck from cementers in Kuparuk. 14:45 - 19:30 4.75 STWHIP N DPRB WEXIT Wait.for pump truck crew. Crew stuck on wrong side of Kuparuk R., the bridge was closed this afternoon. In the mean time spot Eline unit and prep new whipstock. 19:30- 20:00 0.50 S'FWHIP N DPRB WEXIT RU cementers. 20:00 - 20:15 0.25 STWHIP N DPRB WEXIT PJSM for pressuring disconnect. 20:15 - 20:30 0.25 STVVHIP N DPRB WEXIT ~Test lines to 8000 psi. Line up to coil and pressure up while 'holding neutral weight. Disconnect sheared at 2238 psi. 20:30- 20:45 0.25 STWHIP N DPRB WEXIT RD cementers. 20:45 - 22:00 1.25 STWHIP N DPRB 'WEXIT POH. 22:00 - 22:30 0.50 S'I-WHIP N DPRB WEXlT LD BHA #1. Fish left in hole Speed mill,string reamer,2-7/8 extreme motor,circ sub, and lower section of HYD disconnect. 22:30 - 00:00 1.50 STWHIP N DPRB WEXlT RU "E" line and Pu whipstock assembly. 6/3/2003 00:00 - 01:15 1.25 STWHIP N DPRB VVEXIT RIH with whipstock. 01:15 - 01:30 0.25 STWHIP N DPRB WEXlT Log in and set whipstock 5 deg LOHS top of whipstock at 6968'. Lost 300~ of PU weight. 01:30 - 02:30 1.00 STVVHIP N DPRB WEXIT POH to surface with E line. 02:30 - 03:30 1.00 STVVHIP N DPRB WEXIT LD whipstock running tools and RD wireline. 03:30- 04:00 0.50 STWHIP N DPRB WEXIT PU window mill BHA. 04:00 - 05:45 1.75 STWHIP N DPRB WEXIT RIH and dry tag at 6974.2' Top of Whipstock 6968'. Pinch point 4' down. 05:45 - 06:30 0.75 S'I'WHIP N DPRB WEXIT PU, bring on pumps to 2.55bpm. RIH at 0.8fpm. See motor work and lose wt at 6979.3' correct -7' to pinch point 6972.4'. FS=2260psi, RIH wt 12.8KLbs, PU wt 29KLbs. Milling 2.54/2.54bpm, 2350-2390psi. PVT= 229bbl (active system: pits 2,3,5) IA=60, OA=0psi. 06:30- 07:00 0.50 STWHIP N DPRB WEXIT TK Limits meeting: discuss plan forward, LL'd 07:00 - 08:40 1.67 STWHIP N DPRB WEXlT Milling 6974.0 2600-2650psi, 2.55/2.55bpm. Mill to 6975.5 08:40 - 09:45 1.08 STWHIP N DPRB WEXIT Milling 2360-2600psi, 2.52/2.52bpm. Mill to 6976.3'md 09:45 - 11:00 1.25 STWHIP N DPRB WEXIT Milling 2380psi, 2.52 / 2.52bpm. Mill to 6977.1 Should be at the halfway point on the tray. Mill to 6977.9 11:00 - 12:30 1.50 STWHIP N DPRB WEXlT Milling 2500psi, 2.53/2.53bpm. Mill to 6977.8 Send two 5bbl High vis sweep around. 12:30- 14:45 2.25 STWHIP N DPRB WEXlT Milling 2475psi, 2.53/2.53bpm. Mill to 6980.3 Send 5bbl High Printed: 6/1612003 2:05:08 PM BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Name: MPL-01 Common Well Name: MPL-01 Spud Date: 5/17/2003 Event Name: REENTER+COMPLETE Start: 5/26/2003 End: 6/14/2003 Contractor Name: NORDIC CALISTA Rig Release: 6/14/2003 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 6~3~2003 12:30 - 14:45 2.25 STWHIP N DPRB WEXlT vis sweep around. Bottom of the tray should be at 6980.3 (7.9' below the pinch point) 14:45 - 15:30 0.75 STWHIP P WEXlT Milling 2200-2350psi, very little motor work 10-100psi. 2.5/2.5bpm. ROP picking up, 0.3fpm. Mill to 6986.4'md 15:30 - 15:50 0.33 STWHIP P WEXlT PU, pu wt=32k initially, dropped to 28K. Hung up near 9682' came free. Pu to 6950'md. RBIH, 1.6fpm, RIH wt=12klbs, slight motor work at top of whip 6972'md. See slight motor work at 6981', bottom of window. Tag up at 6986.4'md, right where we left it. Continue drilling formation, 2300-2450psi, 2.5/2.5bpm, 0.Sfpm. Send another 5bbl sweep around. Mill to 6990. 15:50 - 16:00 0.17 STWHIP P WEXlT PU clean through window to 6960'. RBIH clean through window. Tag up at 6990, mill to 6990.3 This should be 10' outside window. 16:00 - 18:00 2.00 STWHIP P WEXlT POOH with window milling BHA #2. Formation on shakers. 18:00 - 18:30 0.50 S'FWHIP P WEXlT Speed mill in gauge. Add string mill to BHA. 18:30 - 20:00 1.50 S'FWHIP P WEXlT RIH 20:00 - 21:30 1.50 STVVHIP P WEXIT Ream through window. Little motor work on first pass. Two additional passes O.K. Dry tag. O.K. 21:30 - 22:45 1.25 STVVHIP P WEXlT POH to 3089'. 22:45 - 00:00 1.25 STWHIP N WAIT WEXlT Wait on mud to complete mud swap. Due to limited vac truck availability ( River closure) are having to round trip Va¢ trucks. 6~4~2003 00:00 - 02:00 2.00. STWHIP N WAIT WEXlT Continue waiting on mud delivery. Stored mud (due to bridge outage) has been sitting for days unagitated and has crosslinked to the extent it is in is difficult to move. Will dilute with some of the 10.9 ppg brine. 02:00 - 03:00 1.00 STWHIP N WAIT WEXlT Standby while diluting mud on truck. Cannot blow it off. Have to ship brine from rig, agitate and blow back to rig. 03:00 - 03:30 0.50 STWHIP P WEXlT Continue to POH to surface while changing over to FIo Pro. 03:30 - 04:00 0.50 STWHIP P WEXlT LD milling BHA #3. Mills in gauge. 04:00 - 04:45 0.75 STWHIP P WEXlT Change out coil connector and pull test to 44K. Presure test to 3400 psi. O.K. 04:45 - 05:30 0.75 STVVHIP P WEXlT MU 3.0 building assembly. 05:30 - 06:45 1.25 S'FWHIP P WEXlT RIH 06:45 - 07:35 0.83 STWHIP P WEXlT Tie-in, log down from 6790'. (-5' correction) At 1.Sbpm, losing the majority of returns over the shakers, changeout to new screens (175). Drop pumps to prevent losing mud over shakers, mud needs to be heated and sheared. Unable to drill with the current mud system. 07:35 - 10:00 2.42 STWHIP N FLUD WEXlT Park above the window & circulate at 2.5bpm, bypass shakers, steam the pits. Gradual improvement. 10:00 - 10:30 0.50 STVVHIP P WEXlT Orient, RIH past window with pumps off. Window looks clean. Takes a couple of stalls/pick-ups to get started drilling. 10:30 - 14:30 4.00 DRILL P PROD1 FS= 3730psi at 2.45bpm. RIH wt. = 12K-13K Drilling 4100-4250psi, FS 2900 psi 2.6/2.6bpm. Very slow, <10 FPH (good MW, but slow diggin). Drill to 7030'md. RA marker seen at 6978' corrected as expected. This puts corrected TOW= 6972, BOW=6980. 14:30 - 18:45 4.25 DRILL P PROD1 Directionally drill at 2.6 / 2.6 bpm at 4000 psi. FS = 3730 psi. Drill to 7048. 18:45 - 19:00 0.25 DRILL P PROD1 Wiper to 6990 19:00 - 19:15 0.25 DRILL P PROD1 TF 60L. 19:15 - 22:00 2.75 DRILL P PROD1 Directionally drill 2.6 / 2.6 bpm @ 4080 psi. FS = 3730 psi. Printed: 6/16/2003 2:05:08 PM MPL-01A requested permit changes 303-118 and 203-064 Subject: MPL-01A requested perlm~ changes 303-118 and 203-064 Date: Thu, 8 May 2003 12:07:53 -0500 From: "Johnson, Mark O" <JohnsoMO@BP.com> To: "Winton Aubert (E-mail)" <winton_aubert@admin.state.ak.us> CC: "Hubble, Terrie L" <HubbleTL@BP.com> Hello Winton, 1) For MPL-01A we would like to change the Sundry approval 303-118 to abandon the existing perforations with a 7" CIBP set at 7030' md rather than pumping cement past the whipstock (original sundry application). The CIBP meets all isolation objectives for the sidetrack and the sidetrack targets the same Kuparuk reservoir. In addition, liner lap cement from the CTD liner job will provide additional isolation. Please see attached modified well schematic. 2) For both the MPL-01A Sundry approval 303-118 and permit to drill approval 203-064 we would like to change the BOP configuration to the 2 attached diagrams. The main change is that practically speaking it will be better to completely swap out from the 13 5/8" workover stack to the 7 1/16" drilling stack during well operations. This is a change from running a combination 13/7 stack in the sundry and permit to drill. As always, two levels of protection from the reservoir will exist whenever BOP swaps are made. Please let me know if you have any questions or need hard copies of any/all of these attachments. Thx much, MOJ <<MP L-01A proposed with CIBP.ZIP>> <<Nordic 2 wkol3 stack - moj 5-8-03.jpg>> <<MPL-01 Nordic 2 - 7 drilling stack -5-8-03 moj.jpg>> _~ ii Name: MP L-0 lA proposed with CIBP.ZIP ] MP L-01, A pro'posed wi,th CIBP.ZIP1 Type: Zip Compressed Data (application/x-zip-compressed)] · 1 Encoding' base64 ...... i ! Name: Nordic 2 wkol3 stack - moj 5-8-03.jpg! ! [~ ,N,ordic 2 wko 13 stack-moj 5-8-03.jpgI Type: JPEG Image (image/jpeg) I I Name: MPL-01 Nordic 2 - 7 drilling stack-5-8-03 [~MPL-01 Nordic 2- 7 drilling stack-5-8-03 moj.jp_gt Type: JPEG Image (image/jpeg) ........................................................................................... t~Encoding: base64 'l)Ga:~"~g~poolw/ 1i~x 21~' , 1:33~" ~2 PPY..L~a [ .115' J KO,~.6OO0' ' ~LU .I ' [ 1I: : ..... ~ ~:::a~.~,':= 2':'.~;~:,: .~ ;'S''~ ";~:~'~:'~:;~:O:~:~:~?~a'::'E'~E:'~g::', ( :':' ; [' , .~: i15 tp ~otor, ~a3o u./33 I · ~ ~;~: :a~:.,:P.~.~ ~.~ "':: :'" i I , ....... iL:?,' ~O~O~O -~9t.'~ u 'lb~. ~e x~o :,:.,: :::,:,, . (~ ,. '~ pp~raton Summ~c' :~':;:,,,~',.':.: ,' ..... :~::,,, ~ ~O~0 md : ~ ~~... ~' ':""'::" "':'":':" ,:': . . '; . · .... ~..., =~..~ .. ~....... ~,:;:~'~::;~:::~,,,;~::~:~:.,: ::['::::::::::::::::::::: ~ .... ,.. ' ;'.:~':::;.~:~:~:~::i~:'::~".:.~ : :. f:::~ ~:e:::' : .. ::'?:g?i:~i:: :' · .. ..: . ::':"' :":" ::: .~ ::ll~:::::~:[e' 3 ::~ ~:'e f..:0~;:T~,l:,:.~: ~,:~ ~::5~ :.'~,:'~:::,., i , , ,, ,, ,,,,, ,,,,, ,,,,,,, ,, , .Xr~ "~C9 ~v .... cO~'~cN'~S '"' ' ':........ MILNE POINT UNIT 05/0;/g6 JaF ReconpbteObVNabor,, Es APl NO' 50-029-21068 ',,,,,,, '" ' .... ~: ....... I II III IIII II I IIII I I] I IIII I1'111 ]1111 ....... I''111 i'] I'1'' I'1 JPEG image 544x670 pixels NOrdiC::2wOrkOver"B~ stack annular pre/:entor. HCR valve .HCR' valve =a'--I 2 7/8" X'5" VBR .13scs",o~, pipe. ram JPEG image 502x560 pixels NOr'diC2drilling i ,- BOp with CoilTraklPmssure [~- i d'eploym e'nt capability annUlar ,preventor. ~.. ~ '~(]~o".~~ :2~8 PiPe~S!iP.combi ram. ~o~, Klll ill: l, I · l~ · · Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL [] Abandon [] Alter Casing [] Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. [] Suspend [] Repair Well [] Operation Shutdown 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ~ ~ ~' 1970' SNL, 158' EWL, SEC. 08, T13N, R10E, UM At top of productive interval 2251' SNL, 102' EWL, SEC. 08, T13N, R10E, UM At effective depth 2300' SNL, 65' EWL, SEC. 08, T13N, R10E, UM At total depth 2393' SNL, 324' WEL, SEC. 07, T13N, R10E, UM 12. Present well condition summary Total depth: measured 9500 feet true vertical 9421 feet Effective depth: measured 7375 feet true vertical 7341 feet Casing Length Structural Conductor 130' Surface 2483.. Intermediate Production 7523' Liner' Size 13-3/8" 9-5/8" 7" 5. [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate Type of well: [] Development [] Exploratory [] Stratigraphic [] Service X = 544759, Y = 6031499 X = 544705, Y = 6031217 X = 544669, Y = 6031168 X = 544281, Y = 6031073 Plugs4~rneasured) Junk(measured) Cemented To Surface 1000 sx CS III, 750 sx CS II 750 sx Class 'G', 600 sx Class 'G' E)ownsqueezed: 100 sx CS I [] Other Plug Back for Sidetrack 6. Datum Elevation (DF or KB) KBE = 56' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-01 9. Permit Num~ 184-005 ~ 10. APl Number ~,~ 50- 029-21068-00 11. Field and Pool Milne Point Unit / Kuparuk River Sands MD TVD 130' 130' 2483' 2483' 7523' 7486' Perforation depth: measured 7068' - 7128', 7160' - 7180', 7186' - 7214' true vertical 7040' - 7098', 7130' - 7149', 7155' - 7183' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 6984' Packers and SSSV (type and measured depth) None RECEtVED APR 14 tOO & c as Cons. Comamm 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation May 1, 2003 16. If proposal was verbally approved 115. I Name of approver Date Approved Contact Engineer Name/Number: Mark Johnson, 564-5666 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Terfle Hubble, 564-4628 17. I hereby certify that ~he.foregoing is Signed MarkJohnson~ and correct to the best of my knowledge Title CT Drilling Engineer Date Conditions of Approval: ao representative may witness ~3..~(3~t~.~ ~:~;3~' Plug integrity__ BOP Test ~,. Location c~arance ' Mechanical Integrity Test Subsequent form required 10- order of the Coma,ss,on ~ t"~t"~ ~-~ Form 10-403 Rev. 06/15/88 ' U ~"'~l ~ i l'~ ~ L,,. ~ ~.;~,. Approval No. Commissioner Date i~bi~i~n ~,~cate April 10, 2003 Alaska Oil & Gas Conservation Commission 333 W. 7t~ Avenue, Suite 100 Anchorage, Alaska 99501 BP Exploration Alaska Ino. Drilling & Wells Coiled Tubing Drilling Team Attention: Winton Aubert Petroleum Engineer Subject: Milne Point MPL-01 CTD Sidetrack Prep MPL-01 is scheduled for a sidctmek to be drilled with coiled tubing by Nordic 2. The Nordic 2 fig will pull the ESP, P&A the well, sidetrack, and reeomplete with a new ESP. The following summarizes the MPL-01 P&A procedure and is submitted as an attachment to Form 10403. The new sidetrack MPL-01A will be a producing v~ll. A schematic diagram of this proposed completion is attached. Note that Nordic 2 will be rigging up a workover BOP stack and then a drilling BOP stack (pictures attached). MPL-01 P&A Steps: Planned for 5/1103 oo~N~o~ 5. 7. 8. Pre-rig - test 7" casing packoff, confirm injection through ESP, set BPV MIRU Nordic 2. Pull BPV, kill well, set TWC. ND tree. NU 11" BOPs and test. Pull TWC. Pull 2 7/8" ESP completion. Set 7" storm packer ~25' below wellhead. ND 11" annular preventor. NU 7" CTD BOP stack on top of remaining 11" BOPs. Test 7" BOPs against storm packer. Pull storm packer. With 2 3/8"CT - mn 6.059' drif~ and tag TI). With 2 3/8"CT - set 4 ½" x 7" whipstock at 6978' md. With 2 3/8"CT - P&A Milne Kupamk perforations by pumping 25 Bbls of 15.8 ppg Class cement with aggregate. Cleanout and target top of cement at top of whipstock at 6978'md. WOC. Pressure test wellbore to 1000 psi. P&A complete. Ifthe cement were to fail the pressure test, a second squeeze is not planned since this portion of the wellbore will be isolated by cement during the primary cement job of the new sidetrack liner. ~.. CTD Drill & Recomplete MPL-01A program: Planned for 5/4/2003 (see &tiling permiO ~ 10. Mill 3.8" window off of whipstock. 11. Drill CT sidetrack with 3.75" x 4 1/8" bicenter bit to TI) of 8935' md. 12. Complete with solid 3 3/16" x 2 7/8" cemented liner. 13. Perforate up to 1000'. 14. Set storm packer. ND 7" BOPs. NU 11" annular preventor on remaining 11" BOP stack. Test annular preventor. Pull storm packer. 15. Run 2 7/8" ESP completion and land hanger. Set TWC. 16. ND 11" BOPs, NU THA and tree. Test. Pull TWC. 17. Freeze protect well. Set BPV. RDMO Nordic 2. Nordic 2 is expected to MIRU on 5/1/03 for the P&A. commence on 5/4/03. Mark O. Johnson 564-5666, 240-8034 cell CT Drilling Engineer Sidetrack op~ons ~e expected to Tree: 2 9116" 5M We,heed: 13 8",x11" 5MC, W MPU L. 01 'DGB' tbg spoolw/ 11"x 27/8" ~'~ · ~" ~ ~ ' * Orig. KBElev. = 56.0' (N 27E) ClW Tubing Pianger, 2 7/8" EUE 8 Pad GL Elev. = 17' rd threads top and bottom and 2.5" j ClW 'PI' BPV profile 13 3/8" 72 ppf, L-80 1115'1 Btrc. 2 7/8" x 1" sidepocket I 126' I KOP ~ 6000' GLM I I Max. hole angle = 11 to 15 deg. f/ 6300' to TD' Hole angle thru' perfs = 12 deg. max. DLS = 5 de,q./100' ~ 8066' I 483: iI 7" 29 ppf, L-80, Btrc. production casing drift ID -- 6.059", cap. = 0.0371 bpf ) Halliburton 7'' Divert valve at 4348' md . 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. · ( drift ID = 2.347'', cap. = 0.00592 bP0 7" short joint from 6870' to 6850' ~ md 6883' tvd Centrilift GC-,200 ESP, J 6911' series 513, GP-B, 1468tg. --i Centriliff GSB-Tseries,I 6928' 513 seal section Stimulation Summary Centrlliff KME1 562 series, 10/30/90 -194.5 M lbs. 16 / 20 ~[ 115 hp motor, 2030 v. / 33 I 6941' Carbolite~ amps. Perforation Summary Ref log: DILI SFL 04108/84 Size SPF interval (TVD) 5" 12 7068' - 7128' (7040'-7098') 5" 12 7160'- 7180' (7129'-7149') 5" 12 7186'-7214' (7155'-7182') I ] Uid-perf = 7111 7'' Halliburton Model "N" J bridge plug (milled out) 5/6196 i r 7357' tvd f 7'' float 7390' shoe Fish * ~ 7'' float collar 7436' · Fish - Gee Vann 5" hollow carrier ~ L · (PBTD) gun 7525' Fill cleaned out to 7375' md DATE REV. ~Y COMMENTS MILNE POINT UNIT 04 / 28/84 JBF Drilled end Completed by Nabors 27E W EL L L- 1 05/08/96 JBF RecompletedbyNabors4ES APl NO: 50-029-21068 BP EXPLORATION (AK) Tree: 2 9/16" 5M Wellhead: 135/8"x11" 5MCIW MPU L - 0lA CIW Tubing Hanger, 2 7/8' EUE 8 Pad GL Elev. = 17' rd threads top and b6ttom and 2.5" ClW 'H' BPV profile 13 3/8" 72 ppf, L-80 / Btrc. KOP l~ 6000' = , , 2 718" x 1" sidepocket 126' Max. hole angle 11 to 15 deg. f/ I ~k GLM 6300' to TD' Hole angle thru' perfs -- 12 deg. max. DLS = 5 dee.Il00' gl~ 8066' 9 5/8", 47 ppf, L-80 Btrc. I 2483' 20 PPf, L-80, Btrc. production casing l~Ik i Halliburton 7" Divert valve at 4348' ( drift ID = 6.059", cap. = 0.0371 bpf ) ~' Centrilift GC-1200 ESP, I ' I ~ series 513, GP-B, 146Stg. ~j~ Centriliff GSB-T series I ...... I 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ~ 513 seal section ( drift ID== 2.347", cap.= 0.00502 bpf)[~ Centriliff KME1 562 series I ~ lalmSphs.P motor, 2030 v. / 33 I I in D silt Stimulation Summary I0/30/90 -194.5 M lbs. 16 / 20 Carbolite Perforation Summary Eel log: DIL / SFL 04/08/~4 4 1/8" x 3 3/4" bi-center openhole Size ~PF Interval J (TVD) ~; ::ii:?:i[:. 5" 12 7160'- 7180' (712g'-714g') ~/'//~/ cement Mid-perf = 7111 -~ i LSL sub at 7620' md ~ 7" Halliburton Model "N" /L ~ ~ bridge plug (milled out) 5/6/98 7357' tvd 7" float shoe 7390', * Fish - Gee Vann 5" hollow carrier · 7" float collar 7436' gun (PBTD) 7525, Fill cleaned out to 7375' md DATE REV BY COMMENTS ...... MILNE POINT UNIT 04 / 28 / 84 J"F Drilled and Completed by Nabors 27E WELL~.,'-4 05108/96 JBF Re°°mpletedbyNab°rs4Es APl NO: 50-029-21068 4-1.0~ ~ , ,, pro_.osedCTDsidetmckVer. 2 .................. BP EXPLORATION Obp SUBJECT ENGINEERING DATA SHEET NO. OF BASED ON ENGINEER DEP~APP'VL DATE BUDGET/AFE NO. FILE NO. ! /S AK 2337-1 (11/00) NOrdic 2 workover BOP stack Cho~ke line I ,, HCR valve 11" ~, annular preventer I 11" BOP i~------~ blind ram Kill line MOJ 4/9/03 © 11" BOP 2 7/8" x 5 1/2" VBR ~== pipe ram 2 3/8" pipe ram 11" tubing head I I Nordic 2 wOrkover/sidetrack BOP Choke line HCR valve 7 1/16" annular preventor XO 71t16' x 11" 7" riser to rig floor 11' BOP Blind/shear combi ram 2 3/8" pipe/slip combi ram blind ram Kill line © © 11" BOP 2 7/8" x 5 112" VB R pipe ram 2 3/8" pipe mm 11" tubing head MOJ 4/9/03 BOP Testin_. O_oti~ns throu_eh 7" BOP a) Hanger wi TWC (po~ible ID oonstralnts) b) RTT$ for ~aaing <7" c) IBP >7" when no hanger solution I 7" riser to rig floor I I 7 1/16" annular preventor Nordic 2 workover/sidetrack BOP with CoilTrak pressure deployment capability ((~ Blind/shear combi ram 6A 2 3/8" pipe/slip combi ram I 2 3/8" x 3 1/2" VBR pipe ram 3" slip ram XO 7 1/16" x 11" Choke line HCR valve 11" BOP blind ram Kill line check valve MOJ 4/9/03 © © 11" tubing head 11" BOP 2 7/8" x 5 1/2" VBR pipe ram 2 3/8" pipe ram -- ' Milne Point 2001 Shut In_ Wells Date Reason for Future Utility Plans & Sw Name Shut-In Well Shut-In f Current Mechanical Condition of Well~ Possibilities 3 Comments IMPB-07 Jul-97 A No known problems I High GOR well, Facilities can not handle gas. Possible production after gas expansion project. MPB-08 Ma~'-94 E No known problems 3 Futher use as an Injector not required MPB-13 Jan-86 B GL well that was shut in due to high 3 We#house and towlines removed water cuL Possible channel into water zone. 'MPB-17 Jan-96 E No mechanical problems. Quick 3 ' We#house and towlines removed communication with producer MPB-19 Jul-91 B GL well. High water cut producer. 3 Wellhouse and towlines removed Possible frac into water zone !MPC-11 Feb-96 E No known problems 3 Further use as an injector not required while associated producer shut-in MPC-12 / Jan-O0 E Fish in hole, drilling problems 3 Suspended due to drilling problems. !12~ MPC-16 Aug-93 A High GOR well, perfs and completion 3 Wellhouse and towlines removed abandoned MPC-17 May-O0 D Leak in 9 5/8" casing to surface I Evaluating possible plans for solution to =roblem. MPC-20 Apr-O0 B High water cut well, no mechanical I Evaluating possible plans for solution to problems ~roblem. MPC-21 Feb-02 D Problems with Jet Pump completion I Evaluating possible plans for solution to =roblem. MPD-01 Dec-90 C Dead ESP completion, no support to I Evaluating possible plans for solution to block =roblem. Possible alternative uses for wellbore MPD-02_/ Aug-99 B Dead ESP completion, very high water I Evaluating possible plans. 02a cut well IMPE-02 Jun-05 C No known problems 2 Recomplete to upper Kup zone MPE-19 Aug-99 C Failed ESP on tubing string 2 Well brought on line in 2002 MPL-01' Feb-O0 B High water cut well, no mechanical I Evaluating possible plans problems dead ESP in hole MPL-IO Feb-99 E No proof that is supports other wells I Evaluating side track possibilities MPL-17 Apr-O0 B No menchanical problems, dead ESP I Evaluating side track possibiliti~s MPL-21 0ct-98 E High pressure~lock - 5000psi, no I Possible-use for injection'when pressure support needed for producers lowers MPL-37a Nov-99 C Dead ESP, no-other mechanical I Evaluating. possible side track plans or issuses recompletions MPL-39 Jan-99 E Could not inject gas into well, no use I Evaluating possible side track plans or for iC recompletions *Note - Wells were shut in 100% during 2001 Milne Pt Shut In Wells 2001 .)ds ~--'" 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 ESP Replacement 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3310' NSL, 5177' WEL, Sec. 8, T13N, R10E, UM At top of productive interval 3027' NSL, 5177' WEL, Sec. 8, T13N, R10E, UM At effective depth 2979' NSL, 5213' WEL, Sec. 8, T13N, R10E, UM At total depth 2970' NSL, 5215' WEL, Sec. 8, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic I-]Service 6. Datum Elevation (DF or KBE) KBE = 56' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-01 9. Permit Number / Approval No. 84-5 93-100 10. APl Number 50- 029-21068 11. Field and Pool Kuparuk River Field 12. Present well condition summary Total depth: measured 7390' feet true vertical 7365' feet Effective depth: measured 7375' feet true vertical 7340' feet Casing. Length Size Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Cemented 74' 13 3/8" To surface 2427' 9 5/8" 1000 sx Coldset III 7467' 7" 1300 SX Class 'G' MD TVD 130' 130' 2483' 2483' 7523' 7486' Perforation depth: measured true vertical 7068'-7128',7160'-7180',7186'-7214' 7040'-7098',7130'-7149',7155'-7183' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 6984' Packers and SSV (type and measured depth) None APR '1 $1998 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ~aska 0il & Gas Cons, Commi&~.i~ Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ~ ~ ~,~ Title Engineering Supervisor Date ,,~'~/ Prepared By Name/Number: Mary Youngers 564-5242 Submit In Duplicat~ Form 10-404 Rev. 06/15/88 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX ! ARCO Well Name: MPL-01 Rig Name: N-4ES AFE# 33906 Accept Date: 05/02/96 Spud Date: . Release Date: 05/08/96 MAY 02, 1996 ACCEPT RIG @ 0300 HRS. SCOPE DERRICK DOWN, BRIDAL UP, LAY DERRICK OVER. MOVE RIG OFF L29. SPOT RIG ON L-01, BERM RIG UP SAFETY EQUIPMENT. RAISE DERRICK, BRIDAL DN SCOPE UP. RIG UP HARD LINE TO TREE, TIGER TANK. RIG UP LUB, PULL BPV, TAKE ON 10.5 BRINE. MAY 03, 1996 TEST SURFACE LINES TO 3500#, TAKE ON 10.5 BRINE, BUILD 20 BBL XANVIS PILL INITIAL PRESS TBG 1070# ANN 360#. BLED ANN TO 0# FILL ANN W/10.5 BRINE, BULL HEAD 20 BBL XANVIS PILL FOLLOW W/315 BBL 10.5. SHUT IN PRESS O/TBG 750#, BLEED TO 350#, PRESS INCREASE TO 490#, MON & BLEED IN 15 MINUTE INTERVALS, TBG = 120#, ANN = 40#, FLOW BK 28 BBL MON BLEED TBG, ANN TBG = 70#, ANN = 130#. BULLHEAD 20 BBLS 10.5 @ 3BPM, 1200 PSI, MON WELL, PRESS BLED DN TO ANN = 140# TBG = 100# BLEED BACK 20 BBL CRUDE. BULLHEAD 50 BBL 11.0 BRINE, MON WELL, ANN = 290#, TBG = 120#. BULLHEAD 50 BBLS 11.0# BRINE DN TBG, MON WELL, TBG 120#, ANN = 360#. RIG UP CAMCO TEST LUB TO 500#, RIH SET VALVE @ TOP GLM (652'), POH RIH W/RET TOOL, PULL PRONG ON BTM GLM (6832') POH. RIH W/CAMCO. PULL PLUG BODY @ BTM GLM, POH. RIH W/CAMCO PULL PLUG BODY @ BTM GLM, POH. BULLHEAD 60 BBL 11.0 BRINE DN TBG, MON WELL, TBG BLED TO "0", BLED ANN TO "0". MAY 04, 1996 RIH W/CAMCO PULL DUMMY @ 652, TBG 50#, ANN = 80#, RIH RESET DUMMY @ SAME. PUMP 5 BBL XANVIS 55 BBL 10.6 BRINE @ 4 BPM, MON TBG PRESS F/800#, SHUT DN PRESS DN TO "0" IN 45 MIN. RIH SET DUMMY @ 652', W/420# ON TBG POH. BULLHEAD 26 BBL XANVIS PILL FOLLOW W/240 BBL, 10.7 BRINE DN ANN, THRU TOP GLM 652' @ 2000#, MON PRESS BLED F/900# TO 340# IN 45 MIN. BLED 12 BBL BACK, MON PRESS UP TO 130# BLED 8 BBL TO "0" PRESS SHUT IN MON, PRESS WENT TO 90#, BLED 11 BLS PRESS TO "0" MON WELL. RIH SET DUMMY @ 652' RIH PULL DUMMY FROM GLM @ 6832'. HOLD 500# ON TBG, PULL DUMMY @ 6832' RIG DN CAMCO. MON WELL FLOW FFFBG @ RATE OF 6 BPH, DROP TO "0", TOTAL 4.5 BBLS BACK SET TWC TEST SAME TO 1500# LEAK PULL TWC SET BPV ND COMP TREE, NU BOP SERVICE MAN VALVES ON CHOKE MANFLD & BOP PULL BPV SET TWC. TEST BOPE. MAY 05, 1996 TEST BOP, WAIVE WITNESS PER B. FOSTER W/AOGCC, GOOD TEST RIG DN TEST EQUIP, RIG UP LUB PULL TWC, RIG DN LUB. MU LANDING JT BK OUT LDS UNSEAT PKR (40K OVERPULL) CIRC RECIP PIPE PAR RETURNS W/CIBC BY PKR Page 1 of 2 SUMMARY OF DALLY OPERATIONS 38 BBLS CRUDE RETURNED W/CIRC MON WELL. SINGLE OUT LD HANGER 17 BJS TBG, LD SSSV 7" PKR. CIRC COND HOLE MON WELL STATIC. TOH W/2 7/8 COMPL STRING, LD ESP & EQIP. STRAP MU BHA, RIH SPACE OUT SCRAPER, CONT RIH W/2 7/8 TBG WORK STRING. MAY 06, 1996 RIH 2 7/8" WORKSTRING, TAG TOP OF FILL @ 7320' REV CURC & WASH F/7320 TO 7375' (VARIABLE LOSS RATE 42 BBLS HR). REC CIRC XANVIS SWEEP (20) BBLS POH TO 7263', SPOT 40 BBL LCM PILL. POH TO 6860'. CUT DRILL INE BUILD 40 BBL XANVIS PILL WAIT ON CLEAN BRINE (NO VAC TRUCKS AVAIL) PUMP CSG WASH @ 5 BPM @ 1000# PSI, 38 NTU RETURNS, ON WELL STATIC TOH W/2 7/8 TBG, LD BHA, DRIFT TBG W/TRIPPING OUT. PU SERVICE ESP EQUIP (CENTRILIFT HAD WRONG XOVER HAD TO CHANGE) RIH W/2 7/8 TBG/ESP COMP. MAY 07, 1996 SERVICE RIG, RIH W/2 7/8 ESP COMPL MU HANGER, INSTALL PENETRATOR, MU ESP HANGER SPLICE, CHECK SAME, OK. LAND TUBING RILDS, SET TWC. ND BOP, ND ADAPTER FLANGE NU ADAPTER FLANGE TREE PLASTIC PACK HANGER TEST PENETRATOR TEST ESP, TEST FAILED BEGAN REMOVING COMP TO FIND ESP FAILURE ND COMPL TREE, NU BOP TEST BOP & CHOKE MANIFLD, PULL TWC, BOLDS. WAIT ON CENTRILIFT 45 MIN TEST, INSPECT PENETRATOR, TEST SPLICE TEST FAILED. RU FOR PULLING TBG. POH ESP TESTING ESP CABLE. MAY 08, 1996 SERVICE RIG, POH W/ESP CHECK ESP LINE OVER 1000' PULL WET. INSPECT ESP, MOTOR CHECKED GOOD. FAILURE IN POTHEAD. RESERVICE ESP, SPLICE NEW MOTOR LEAD ON ESP LINE TIH W/ESP COMP, USED 109 GUARDS 8 STEEL BANDS MU HANGER LANDING JT. SPLICE ESP LINE TO HANGER PIG TAIL, TESTLINE PENETRATOR LD TBG HANGER RILDS, INSTALL BPV. ND BOP, NU TREE PLASTIC PACK ADAPTER, INSTALL TWC, TEST ADAPTER & COMPL TREE TO 5000# CENTRILIFT TESTED PENETRATOR, TEST SURFACE LINES TO 3000# PULL TWC INSTALL BPV. FREEZE PROT WELL, BULLHEAD 60 BBLS DIESEL DOWN ANN. ALL BANDS/CLAMPS RECOVERED ON TRIP OUT. BULLHEAD FREEZE PROTECT DOWN TUBING, SECURE WELL - RELEASE RIG @ 0800 HRS. Page 2 of 2 Conocolnc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (9071 564-7600 October 18, 1993 Mr. David Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive ~' Anchorage, Alaska 99501 RE: MPU L-l; REPORT OF SUNDRY WELL OPERATIONS D. ear Mr. Johnston, Attached are duplicate copies of the Report of Sundry Well Operations, Form 10-404, for replacing the electrical submersible pump in Milne Point Unit Well L-l, Approval No. 93-100. Please direct any questions or concerns regarding this form to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Att: cc: TJY Chevron Occidental L-1 Well File RECEI /£D .----. , "-"" /"I STATE OF ALASKA AL,¢,,.., ..A OIL AND GAS CONSERVATION COMMIS~,oN REPORT OF SUNDRY WELL OPERATIONS . Perforate_ Other 'X' Replace E 6. Datum elevation (DF or KB) ~ I 1. Operations pedormed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator 5. Type of Well: Development ._~ Conoco Inc. Exploratory__ 3. Add ress 99503 Stratigraphic __ 3201 C Street, Suite 305, Anchorage, AK Service__ 4. Location of well at surface 1970' FNL, 5122'FEL, Sec 8, T13N, R10E, Umiat Meridian At top of productive interval 2253' FNL, 5179' FEL, Sec 8, T13N, R10E, Umiat Meridian At effective depth 2304' FNL, 5216' FEL, Sec 8, T13N, R10E, Umiat Meridian At total depth 2393' FNL, 323' FEL, Sec 7, T13N, R10E, Umiat Meridian 56 ' KDB feet 7. Unit or Property name Milne Point Unit 8. Well number 1',-1 9. Permitnumber/approvalnumber 84-5/93-100 10. APInumber 50-- 029-21068 11. Field/Pool Kuparuk River Field 12. Present well condition summary Total depth: measu red true vertical Effective depth: measured true vertical Casing Length Structural Conductor 74 ' Surface 2427 ' Intermediate Production 7467 ' Liner Perforation depth: measured 9500 feet Plugs (measured) 7390 ' 9420 feet 7390 feet Junk (measured) 7365 feet Size 13-3/8" 9-5/8" 7" 7068-7128'; true vertical 7040-7098 '; Cemented Measured depth True vertical depth to surface 130' 130' 1000sx Coldset III 2483' 2483' 750sx Coldset II 1300sx Class G 7523' 7486' 7160-7180'; 7186-7214' 7130-7149'; 7155-7183' Tubing (size, grade, and measured depth) 2-7/8", L-80, 6989 ' Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 572'; Otis RDH 13. Stimulation or cement squeeze summary Pkr @ 593 REEE VED Intervals treated (measured) None Treatment description including volumes used and final pressure OCT 2 0 1993 ,Alaska 0ii & Gas Cons. 6ommissio" 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 666 220 160 0 888 293 302 0 Anchorage Tubing Pressure 380 423 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I her~at t~g is true and correct to the ;;~e:0_404 R~e~06,15,88 best of my knowledge. Title SHEAR Specialist Date SUBMIT IN DUPLICATE WELL No. L-1 COMPLETION SKETCH MILNE POINT UNIT (P) APl No.: 50-029-21068 PERMIT No.: 84-5 COMPLETED: 4/27/84 LAST WORKOVER: 4/21/9,3 WKM 1-UBING HANGER W/ 2 1/2 .... H" PROFILE BPV (FIELD VERIFIED) --17 JTS 2 7/8", 6.5#, L-80, 8rd EUE l'BO 1/4" S.S. CONTROL LINE I ELECTRIC SUBMERSIBLE PUMP CABLE -- NO. 4 AWG CL 550 ABOVE PKR NO. 2 AWG CL 350 BELOW PKR NOTES: 1. ALL DEPTHS MEASURED KDB = `31.5' KDB-SL-- SL-56' MAX. ANGLE = 12'7' @ 8157' K.O.P. = 2935' SLANT HOLE: YES MIN. ANGLE = .28' @ 7278' TREE TYPE: CAMERON WELLHEAD/FMC 3 1/8" VALVES, 5000#, W/ `3 1/2" 8rd TREETOP CONNECTION MIN. I.D. = 1.875" @ 56.5' COMPLETION FLUID: 11 PPG NoCL FRACTURE STIMULATION 10/50/90 PUMPED 194,495 #'S 16/20 MESH CARBOLITE . 3. 4. 5. 6. . 572' OTIS 2 7/8 .... FMX" TRSV 585' "XO" 2 3/8" x 2 7/8" (1.995" I.D.) 593' OTIS 7 .... RDH" PACKER (1.94" I.D.) --60.3' OTIS "X" LANDING NIPPLE (1.875" I.D.) 608' "XO" 2 7/8" x 2 3/8" (1.995" I.D.) --652' 2 `3/8" CAMCO GLM W/ ORFICE (1.945" 68.32' 2 5/8" CAMCO GLM W/ HOT OIL VALVE SET @ 2600 PSI (1.945" I.D.) 6877' CHECK VALVE (CENTRILIFT BALL) 6943' TOP OF ESP CENTRILIFT OC 1200, 146 STAGE 100 HP, GP INTAKE, 1:5 AR, KRYTOX, TANDEM SEALS -- 6989' BOTTOM OF ESP PERFORA-I-ION DATA MD TVD DEPTH: LZ 7068'-7128' (7040'-7098') LK-1 7160'-7180' (7129'-7149') LK-2 7186'-7214' (7155'-7182') DENSITY: 12 JSPF RECEIVED OCT 2 0 199~ Alaska Oil & Gas Cons. 6ommissior~ Anchorage 7390' HALIBURTON MODEL "N" OUICK BRIDGE PLUG 74`36' PBTD 7525' 7", ,_6~. L-80 ~.Tr,~, ~CONOCO) CONOCO INC. ANCHORAGE~.,vr~'x' ~'ONo, JAPPROVED EB';": JI4A/'tIDS D;',~E' 5--i;. " j DRAFTED BY: CFP CAD i li!- WCC':: ' j OCT 18 '93 8:05 ---. TO .... EAR P~GE.010 Oe'; i.y OrJ ~ ~ ~n~ Report AFEt 10 ;ECTZOg TO.' 0,0 POLLUTZON: N R~G: 22E PLANNED FORI4ATION: ACCIDENTS; NC)NE :6AFET¥ NEETING5 O~ 0.0 08 0.0 :~ .,.:~. ~:.-.:....,. :: ~ ..*~ ~.:.~:::::::.., ~.,~ ........... ~:~:.,.:: ::.: :~ .......................... .T..O.: ................... :..:.::Oa~.:~.:.....:.:.:..:. :~.C:'~;. ~I- .~ ~:.,-;~ :...~ ::~.~:. :::.'.: :~.:.'.,'.: ~;~.:~ ............... *.~..~.~:~::::..~::~:~:.~::~...~,~:.?:~:~:=::.*..~::;::::::::::::::::::::::::::::::::::::: ,, .., · . . · ....... , ........ ..'...*:.:.r.;.:.;'.'~:'-'.'.'.'*'- .'.'**':" ' ', '.1;~.:.~:.:.;.:.:-.....:..:.:.<.:....-,..*...;.*.....:..':.....,.:..*:.:...:.:...:.:.:.:*:...:':..:.:.."'.:':e..'..'~- .-.-. -.. --, ,..-- 1 Plli IC 6.50 00.' O0 ~.'30 0.0 FK:~SI T ~ON RIG 1 LIC 10 6.$0 06;:50 13;00 0o0 RIG ON STAI~B¥, WH~LE FILLIN; TN ,~OFT INOU UITH ~I,IANP NAT$ 1 PlB lC 3.00 15;00 11 P9 14B 2.00 15,'00 17;00 0.0 C~'I~, VALVES ON ~LLHEAD, DEAD, TRY TO ~ILEED OFF'CONTROL L%NE PRESSURE~ WOULDN'T BLEED OFF~ WAIT ON ~tPV LUB, 11 P9 ~5 1,00 17;00 18:00 0.0 RU LUBRICATOI~ PULL BPV~ BLEED OFF GAS, FLU;D TO' g-JR'FACE, $! PREBEURE ~00 PS! 11 T5 /,5 3.t:)0 18;00 21;00 O,,O TRY TO PU~ PO'aN k~I~LL, COULDN,~T THREADS; IN FLGE BAD,, FIND ANOTHER FLGE, ND/NU FLGE, PRESSURE UP TO ~000 PSi, COULDN'T PUI4P ;NTO WITH AHY RME 11 A6 29A 2,00 21;00 2.'.~.,00 O.O laA~Y' ON BL[CKL%NE UNIT 11 A~ 35A 1,00 23;00 00:00 O.O RU iL%CKT.%NE UN%T TO S;N;FT SLIDING SLEEVE .... .... ._j_ ,,_ ..,.;,..~..........:.:....... :,. _ _.~.. ~1 ~.!.~.....~....,:.... ,:.~....:................. ..... .....'.L ) m.l.: ................. . ........... k** ¥*:*~::-':-*:: .... :':':*~'.::::..: ....... :,~.:~..:....*.'.;:::::.~: ......... :~:<.:~:~>~*~::~:~:::~:~:.*:~:.:~:~:~:~:~:~::~..~.*:~:~:::~::.~.~*~:.:`~:~:~ .:::..>......q..........:.:..~.. ~*.:~:~.~*~:~:~.~&~.*:°:~:::~:*x.:.~.¥~*`.::~:*~:~:*:~:::.~:?`**~?.::::*`.:::~?::~::~:~?::`.*.~.~*~;.:~.~/~/.;~:*~:~:.::.:~*;::~`..X~:~:~:~:~*.~::.~:<~:.:.*^::×:*:::~<~.~:~:?:~:x~:~: '*: c_ · ............ ,~.c.:<.:,,'..: ............ '.;f'_:'.'." *.'-*.-'..'. **,',*.'~,=.:*:-,'-.:~--'-::.::':':;:*:':':':':*"'"*":"'*'**'-'"'"'"": ' :L'-::~';_"*'*'" "":'"*:' ',v '.'.. ::.: ... 8.20 0 O.O 0.00 0.00 0,00 0,00 0.0 O.O0 0.0 0.00 O.OO 0.00 0.00 0.00 0.00 O.O0 O.OO 0.0 0 I SOURS: OTHER DAZLY I, ILfl).. 0.00 [;Ui, qUI.,~T~VI~ l,~dD= 0.00 · -=.-- ~= , ,.~ .............. .-.--.. r..... SERVICE PER;~NNEL ~ 14ATERIALs I CONOCO, 3~ NABOR$, 1 BAROiD, 2 P~, 1 S. L~I~T%, t E~, ~ CENT, 2 ~TH ~]TE 0,0 RECEIVE'"" o.o NEAT 0.0 HELl'EL 0.0 DIESEL ' ~T ~ATEE PE~LE ~ L~m ~ Alaska Oil & Gas Cons. Co[~ozL o.o 0.0 81T$ AFE# AFE AFE S:U'PPL AFE TOTAL I0-61-1501 1ZZ?~,09,00 0.00 DAILY O.~'LX.~ 0.00 0-00 TROUBLE O.OD 0.00 ~.os~r ~.~ o.oo _o.oo TOTAL 0.00 -.--.; -:.::.: --*-~: -_ ~TTOIq HOLE A~E~BLY # ,, ~ : :.:£ I .... $1.,O~ PUHP RATES DEPTH' 0.0 DEPTH 0.O ~ 1: 0.(~ O Pi.ll4P I: O.(~ O I:'LJNP 2: O.II~ O ;q)14P 2; O.(~ O CEMENT; 0,1~ 0 CEHENT; O,~g 0 LENGTH HRS ON JARS O RTO ~ 0.0 T(~ ON BHA WEZGHT NXN lO P/U 0,0 TOR(;KJE OFF DP FTGE 0.O TYPE (g.[N ID) S/'O 0.O TOROUE MAX RE EiVED OCT 2 0 199,~ AJaska OJJ & Gas Cons. (;omrnissbn Anchorage OCT 18 ~93 8:0£ .... TO~'~HEAR PAG£.008 DAYS Ho/'rvo; O. O / O, 0 ACT.- ~_ PR(XiRES~: 0.0 SI:~; ~ DRLG HRS: FTb~: '0 PR~ TO: ( AFE~ 10 ~CTZ~ TD~ 0.0 RIG~ 2~ "~RENT ~ ~L~ 2 ~Y CHECK, Ru OTiS TO ~LL PLUG DRILLS ~:~IDtT]~: PARTLY CLOUOY PIT: g TE#PERATURE: 28.0 TRIP: N WINO (SPEED/D[R); 0,0 FIRE/ABANOONt H WAVE (HEIGHT/DZR); 0.0 POLLUTION~ N PLANNED FORNAT !OH: ~AFETY HEETINGS ( tie mim ): 2 ~ S.O 0 E 0.0 0 & 0.0 11 PlO 35A ~.00 00:00 03:00 11 PlO 148 5,50 03;00 08:30 0.0 RU CANCO, TEST LUBi~ATOR TO;~OGO PSI, RiH OPEN SLIDING SLEEVE, KO CNqCO 0.0 DISPLACE t. ELL ~/ 8,~ PP~ BRIN~, STILL 11 PlO ~SA 1.00 08:;~0 tl PlO 35A 6.50 09:30 16:00 1t PlO 14B 2.00 16:00 18:00 11 pi0 I&A &.O0 18:I)0 ~1 PlO' 1SA t,00 ~2;00 11 PlO 15A 1.00 23:00 T~N ~ILT PRESg~E TO 500 PSI, COIq]NG IH THRU CHECI( VALVE~ 1.]AIT ON 0.0 RU ~, TEST LUBRI~?~ 0.0 RZH RETREI~ ~F~CE VALe, SET D~ VAL~ ~N GLM ~ SE~ RUN, SET ~ PLUG ~ ~ R~ IN X NI~LE A~ER ~P~NG 7fiLS OF IRIK, RD ~, SET 8~ 0.O BL~ ~ OFF ~ TB~ ~O ~ ANKLe, R~ TREE, RE~ ~T~L L~NE 0.O NU/K ~'$ A~ FL~INE, CL~R FL~ 0.0 RU TEST ~P, ~LL :HECE VALe, INSTALL ~ ~Y O.O ~ I dT 2 ~/B' TBG, ~ TZ~ AND DART VAL~ SURVEY ;-, ? - .:4.:,.:-¢..,..x.:...~,.c..~:.~:....:4::,.;.:.;.......4.;<..: ........... 4.....:.;...:.x::.:..::~:::....`::..:.:::.:.:;~.:.:.:.:.:;.:.~..~:.:.:.:.:.:.:~..`~..:.:.~:~..%~%;:;::~(~.:~..:4..;..~.i~:~.:.:...-:... .: ....................... !:.,:,..:;';:.x.: ::.'.';,~:";~ ~ ~ x 4.:.~;~:~:~,..:4 ,.~: ........ :~::; ~:-:, ..... ;:.....*-..;;}4..'¢ :; :;;:::; :;:;:;:::: 3:; ::; :::~.:; ;:. ::; ::; ::.;:~: :~; :..<.:.'-; ;: ~:::.: ~:: :~;: :;':.:~..!: ::% :~: :3: :~ PEOPLE AT LOCATIO~ OOT 0 ~.,~laska Oi~ & 6as C;ons. 0 MATERIALS BARITE BENT~tITE 0.0 BLENO 0.0 NEAT HELZFUEL 0.0 D%ESEL 0.0 f~ILL 'dATER 0,0 T WATER 0,0 ll~SE OIL 0.0 BRINE 0,0 AFE# 10-6t-1501 AFE AFE SUPPL 0.00 AFE TOTAL 1Z27409.00 DAILY CUM. DRILL%NG 3359~.00 33594.00 TROUBLE 0.00 0.00 LOST TINE 0.00 0.00 ADDITIONAL 0,00 ~ TOTAL ~3594.0D OCT 18 ~98 8:04 ~-,. TOnSil, EAR PAG£.009 DaiLy DrilLing :.:...: · · ,~ .:.:.~. ,~ .. · ~.:::::..,,,.:.:,:~... ..... . .~:.~.....:.:.:.....:...:....~,.:........:.~:.:..,.....~..:...~ ..... - ....... ....v.:.:.:.:.:...:...-.:...:.:.:.:.-.-/...:..:.-.:..,:.:.:.:....:.-.:..../.-...,....~-.....,....,..:.:...:...:.:.:.:....../.:.:..,-.....~ ~....~.......,.o...~..;...o:.:.o,....o.. :. <~4..'.:., · . :, .~.~.~...:~;.:,;... · ,~. ,. -, ..;...~ .:.:.4.,6,o.,;c 'o'o.::,.'o '.:.~*;,o,:.::.o: o:,.:.,,;.,- ..,:. j:.. It ~,. ~, .,.:. ~,,~. ~- ~. ,.. · ,.~.~ :~..* -:-:.-:-:.:.x~;.:-'.:-',-..'.:.:.:...:.'.'....~ .-,,...,- .'.'-',-..'.,.'.~.,'..~.',';..,...~,....-.-;-.-.....-~ ,...-....~...~....:..:...-..:,......~..:.:.~:...:-:-:-.,:./~:.:-: . -:-:,:-: -:':.:' .: . ' .:.:~..,~ ..... .-:.;...... ',.i,. ...,:,,.........:.:.~..:.:,:., ;4. ~.."- <.,'. 4. :4. ,:o. · · :.~. ~ ;~.~ ~,:~::::~-::~:::~::~:.~.:~ ..-~.' .......... · ............................................................. -:..:..: ........................................... : .-c · '..'-.':'~- '.'-':':'..';':':':'.':-::...~..'~ ~ ~':':';'!-!', i.~..~.', ~ ~.~ ~ :.':.. :..: ~ ~.[~:;: ';,,~.~.~.'~..~ .~:~:~:~:~. .............. .<.o~:~ *.~'[~ ~ + ~.:..-:.o,:;:..~/~..o...,<, ,.;2--;.:,~:::.':;:~:.'::/;':.~;.:;:.:';,-..:.~ ..... .~:.--~-T'-- ,,.,-:~-:.:-.:..' :.:.:'%i-..~::%-s:':::'-'%':;:'.:TM ....... :-.-:-.-.-.-..:.:..-.-.-:-.--. · ....... -'.:-'.'..-:-: ................. :-:-:.:.: ............. !:-'-'-'.:-'.:-:-;-:-:.;.:-: .......... ~-: ........ ~.:-,.,,' ....... ::~?:c'~::~ii?;-;:;:;ii: r'=:ix:~i' :: c :oo'~:;~:;; "' ;io;.:.F"::.;:.;": ;oi,~+- · .~r~..:...,..:...~.....l.~ .:~,..~..~E.T..;.~.ZE$~.,,..~.,.[ .................. .T.~ .................. .~ ................. ?~a~:-.~:.~[~i .......... ~HP..~. ....... ~H~ .......... ~E~:~.~::: z..:.~, ~ ........ ~ ....... ~( ..... G ....... ~ ......... ~: .......... I.,..?....;~:.:.:::.~.; .::... :.:..,.:.:,.:....< .............. :~: .................... ,~...:;+..:..:.-...:.~x.:.:.-.-....................-.,-.-...,.....:-...----..-...,..-.---..-..... ....... "':';;':': """" ""' :;i'"'_"?::::_~'":: ) "":~":'"' .v ;.'.'.::::::'_-; ._.o.._. ,- ,- '-,.,,,:.:,,<,,.'.c: :°-,.*-'-.--':-?-----;';.---::~i- .......... :;;,;;.,..; :;;;;;,, ::;.-::.:::,,<:;;U:::,c/.,:;; ,,.<:: BOTTGN HOLE ASSEHBLY # SLOM M.IMP RATES DEPTH 0.0 DEPTH 0.0 PtJ~ I-' O.(B 0 ~ 1: 0.~ 0 PLI~P ~-: 0.I~ 0 PUI, tP 2: O.C~ 0 CENENT: O.m O CEMENT.' O.Oil O LENGTH HRS ON JARS 0 RTG VT O.O TORQUE ON BNA I~IGHT NIH ID P/U 0.0 TORqUF. OFF DP FTGE 0.0 TYPE (MZN ID) S/O O.O TORGAJE II, AX ..- --"------.~--'~-,----~:- - i CASING i "~'~r~'*:'-"'<' .; ,.....?:....<.:-;..v.-....,.;-:.;-:.-.,..~:...,... ~.. ,:.:..~...,..~:.:.:->:->:.:~.x.:.:<+..- ,..:.:.:.:,:.:..:.:.-.-,-.....-.:...-...-.-.:.-.-.,---.......:.-.- :..,~..~.~.~..~...~.:.~..~:~.~:..:.:...~:~:~.~:~:~:.~.~.:.:~:~:.:~:~:~:4.;~:4+:~>::-~..~``~j~ ,,.o.. ~,ij.:T-,~,.~,~'' ~,~i',~;~':"c"°':':":':':';':*:~;':<+;':<°:';"]i~'~i~ ~: :" "* '/ ' ' c.>. z -,:. oo /. .,. ,o .;, ,.,..,., ..o.. .... ,. .... : '4 ' . · ', · ~,.- ......................,.....,.,,....,.:.... `~.~.:~:~.''.*''~-.:..':.:~:~:~:.:~:':~:~:<~.~.~.~.~.~.~'~-~`~'~'~..~'v'.. · -.-.-.......... :...-............:. · · .~.:.:..'.:,.:...:<.:.:.:.:.:. ..'.~.<,x.,..:- -'... -..>.-:.' ." ' · -< :':'. "' '" ,c,.:.. ...... . ........ . ,.., ..... ~... · ..., .....:,,....... ...... ,:......:... R[ E VED OCT 2 0 !t99, Alaska Oil & Gas Cons. Commissioi~ Anchorage OCT 18 ~8 ?:5~ .... TO ~E~R P~GE.OOB PLANNE~ ~P: 0.0/0.0 DRILLS CONDITioN; CLEAR 0.0 PIT: N TEMPEBATURE; 28,0 TRIP: N WX~ (~IDXR) ~ 0.0 ( ) FI REIAgA~ N ~VE (HEZGHT/DIR): 0.0 0,0 ~LL~I~; ~ FI:XU~T ! ON: ACCI DENTS; ~0 ~0 ~ NONE ~,FETY NEETIN~S ( # 8rain ): 2 & 5.0 I ;;) &S.O 0 g 0.0 1 ESP IL'UNN%NG PROCEDURE Id/ (:REId .: :.'-.. .. · ..... . ...... . .......... , ..... 11 PlO 1SA t.S0 00:00 01:$0 0.0 TEST IIOP,'S AND CHOKE MANIFOLD TO 500/5000 11 L3 2/+ 2.00 01=30 03:30 0,0 ATTt~PT TO PUL. L 2 WAY CHECK, SALT ON Ta~ OF HANraER, LOG'T RETR%i~VING TOOL IN THE HOLE 11 LIO I&A 2.00 03-'30 0.5:30 0.0 NO ltO~'g RETRETVE RETREI:VING TOOL, WASH SALT OUT OF HANGER, 11 LIO 15A 1.00 05:30 06.'30 O.O TEST BOPt$ 11 Ct0 3~A 1.50 06-.30 OB;O0 0.0 SLiCKLINE, RETRIEVE XX PLUG 11 PlO 14~t I,.00 08;00 09:00 0.0 BACI(OUT LOCI~ $CREi~ ANO UN~F. AT PKR 11 plo .5 &.50 l~:~O 13:30 0.0 TRY TO CIRC TItE LONG ~Y, PRESSURE ULCER PKR RESET THE RUBBERS AHD LOCKDOggB, TRY TO UNSEAT PKR, TO NU~H D I FFERENT%AL PRES~LIRE 11 PlO 3SA 6.50 13:30 18=00 G.O RU SL$CKLINE Rig TO RETRIEVE DIJPlCY IN GL NANDEL~ LAI'~EI) IRIMY, PU ANO L~NE BROKE, ADO NORE LUBRICATOR AND REHEAD WIRE, RIH Id/ LEAD ]NPRESStON BLOCK~ FOUNO TOOLS HAD DROPPED TO BOTTON, RD SLICKLI#E ' 11 Pig 3~;k 2.S0 18:00 20-'$0 0.0 PU ON LANDING JT FREE LGIdER HANGER AND PKR BACK DOIdN HOLE, RU SLICKL~NE SET DLII~Y, RD SLICKLZNE 11 PI0 5 0.50 20::50 21:00 0.0 RU.TO REVERSE CIRCULATE, 1'I P'10 19 1.50 21=00 22=$0 0,0 TRY TO CIRCULATE ZH REVERSE, PRESSURE UP TO 500, THEN 1000, THEN 1500 SLIPS SETTZNG AND ELENENTS STAYING INFLATED, Idl,llLE tdOREl#G. PIPE UP HOLE 11 PI0 35A 1,50 22::~0 00:00 O.O RU SLICKLZNE RETRZEVE DLN4Y 18. o o ° o.oO 0.0o '0.0o o.o e.oo 0.0 o.oo o.eo o.oo o.oo o,oo' e.O0' 0,oo 0,oo 0,o 0'/ ~ERVlCE PEIL,~ONNEL CONOCO, :]4 NABORS, 1 BAROZD, 7_ PEAK, LOGISTZ, 2 Id~.ATH, 2 CENT, 1 EUS OCT 'Z 0 't99 PEOPLE AT LOCATION ^ias~ Oil & Gas Cons, · 'AnGhora~e HATERIAL$ 8~ITE 0,0 BENTONITE 0.0 BLEND 0 NBAT 0.0 HEL! FUEL 0.0 DIESEL 0.0 DRILL UATER 0.0 POT UATER BASE OIL 0.0 BRINE 0.0 AFE# 10-61-1S01 AFE AFE SUPPL 0.00 AFE TOTAL 1227&0~, O0 OAI LY CUN. ORILLING /.,7'7'10.8~ TROUBLE 0. O0 0. DO LO~T TINE 1772q.17 17~1.17 ADDITIONAL 0,00 0,00 TOTAL 65~2,00 9902.~,00 u I~O~lp$ CZR~LATING ~YST~ PRESSURE HU STROKES O DP 14~NUTES 0,O RSR RATES D[PTH 0o0 DEPTH ' =~'~0' - PIMP 1: O.(B 0 PUIIP '1-' 0.~ 0 P~P 2: 0,~ O ~NP Z.' O.~ O C[#ENT'. O.~ O C~ENT; 0,~ O BQTTC~q HOLE AGGEMBLY # LENGTH HR$ GN JARS 0 RTG I~T O.O TGRQUE ON BHA hlEZGHT HIN ~D P/U 0.0 TGRQUE OFF DP FTGE O,O TYPE (MIN ID) $/O O,O TORQUE ~AX ~NT~;: GO~T$ INCLUDE CABLE BUT HOT PL.q~, PRESENTLY ~EP ~S AT SURFACE RECEIVED OCT ~: 0 199~ ~,lask~ Oil & Gas Gons, Commissior~ Anchorag~ 0C9 18 '~8 7:56 ..... TO "-~EAR PAGE,004 CcO oco) I 'Conoco Deity Or~ttfna Report DAYS ACT., 4 SPUD: 4 FTGEz D AFE, 10 RIG.- 22E ND/TVD; PROGRESS: DRLG fiRS: SECT ION TD 0,0/0,0 0.0 0.0 CURRENT PLANNED FORMATION ~tIH V/ NEW PUHP 01~ TBG ACCIDENTS; NONE ~FETY #EETzNOS ¢ # ~i rain )., 2 ii 5,0 Oa 0.0 DRILLS PIT.' N TRIP: N FIRE/ABANDON; N POLLUTION: N CONI)ITION; TENPERATURE: WIND (SPEED/DIR); VAVE (HE~GHT/D~R): 11 LIO 3SA 0.50 00:00 00:$0 11 LIO 19 2.50 00:30 ~:00 11 LIO $5A 1.S0 03:00 04:$0 11 LIO 5 O.SO 04:30 OS;O0 11 LIO 35A O,SO OSCO0 05:30 11 P6 5 2.S0 05:30 o8:oo 11 L6 2~A 3.00 08:00 11 =00 11 P6 5 1.50 11:00 11 PlO 6F $.00 1Z;$0 0.0 RI{; DOgN CAY~CO 0.0 FREE UP PACKER AND ESTABLI~;H C ZRCULATION O.O RiG UP CANCO, INSTALL OLilCNY VALVE 0.0 REVERSE CIRCULATE. THROUGH CHOKE 0.0 RD CANCO 0.0 REVERSE ~0 BElL HEC AND ~IOURCE gATER U/ 12~ NETHANOL, THROUGH CHOKE 0.0 I/AITING ON S~URCE WATER AND 08SERVING 0.0 CIRCULATE I~LL UNTIL CLEAN 0.0 TBG OUT OF BALANCE~ PUNP DRY J06~ LD 11 PlO 6F ?,00 15:30 ~2:30 0.0 11 PtO 6F I.~0 ZZ:]O 00~00 0.0 PULL OUT OF ,OLEt// TaG C~ SSSV Pla~, GL NANOREL, SLIDING SLEEVE PREP PUMP TO LD AND LD SANE, BAD ~ iN PZOTAIL ON TOP OF PKR AT : r-__..-~. :: :1~: ..... , 8.20 0 0,0 0.00 0.00 0.00 0,00 O.O 0.00 0.0 O.OO 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0 SOLI~CE: DALLY SURVEY SERVI CE PER~OIdNEL MATER IAL$ AFE# 10-61 - 1501 2 {)ONOGO, 36 NA~S, I ~ROIO, Z P~, 1 S. AFE 122~.~ L~ISTI, I XNTECH, 2 ~TH, Z CENT, 1 ~S ~ITE O.O AFE SUPPL 0.00 ~NTONITE 0,0 A~ T~AL 1~7~.~ " N~T 0.0 DAILY ~, HELIF~L 0.0 OCT 2 0 t995 ,,,[[ .ATER O.O TREBLE ~ vAT~ O.O L~T TIME ~0~~5S~Ou,. ~ OIL 0,0 ~ITI~AL 0,00 0,~ PE~LE AT L~T)~ Oil & Gas Cons. eRz~ o.o T~AL ~135,00 .... ~:~:::::~K~: ':'::":~'"'?:?'"'::~ ~:., ' : ·: ~:- '.:~: ~:s:.-'- ~. v ...... ~:~ ........................... ~ .......................... :::::: ........... : .......... ~ .................... ~.:-:-~:~-:--'-.,"--~ ................................. .:"'-'-~-: ........ : .................. r::~:.~::::.~ ...... '.~:~.=:~:.~:-:.:-(: :~::: :~: -~ ~ ~F: ~ ~f::-~] ~: ~: ~]::f4:~ ~ -::-~: ;~ 3 ;:~ ~ C ~: ~.~::~ ::: ~..~ 8 ....... 4..- &..~.-;..-J.~.. ~.~:;:. -:...~;..: :-:: .~.~..~::: :::::~::;:~-::: ~: ~.~: ~: ~::~:~:~ ~. :u~:.: ~: ~:~ "...H~ 4..' ' ' ':~.~. 4.~ ~-~ '" [ ........ -~-.--?:.:-:~=~:-:.-~':~ .................... ~ ....... :: .......... ~ .................................................................................................................................................................... ~ ....... ~ ................ NW ...... ~ ............... --:~ ........ ~.;,.~:~ ............ h'-~ .~ ~:'-'-'-'.'-'.'.'.'- .'.' ~' <'~:.:.:...... :~_; .........~..~. =../. ~,.. ,:c.'~.. ....................... -.-.~-~...~.-,...-.:.:.:...-.....-:-.<-:..->.- -.,- ,.-~:..-.-.-:.:...:-:-:.;.: .>r-:.:.: :-:<.:-:.:-;.:c.:.:~.?.~ -:.: <.:.:. ~ ~ -.:-:-:...:...:.:-:. :~.'.>:.?,:-r-..:.-- :. -.- -..,:-~.x.:-r.:.:...,..~.... -.-:.:....: ......,..;.......,..-..,:-....:.:.:. -...-.~-.~->...~-..:..-:..¢-;4-~;...:-..:-....~.-:%:;~ ,:-..:-;:=. ~.~-;4~-,;-..,~ OCT 18 ~93 7:58 -~ TO ~ '~AR PAG£.005 Oa~ty Drilling Report U P~fP$ C~RC1JLATIN{Z SYSTEH SLOI,I ~ RATES .~<..q.,.7.::.,~-..~- ----.-~.-.----. --.~,--,, .-~ .,~-.,-~.~. ---. · - .] PRESSURE HW Ix,~l~P I: O.Q~ 0 PLUMP 1: 0,~ 0 STRO~:E$ 0 DP PUHP ~; 0.~ 0 PUMP 2; 0.~ 0 NINUTES 0.0 I~Slt CE~E#T; O.dm 0 CEMENT: 0.~ O lliOTTI;~,t HOLE ASSEMBLY # LENGTH HRS ON JAR~ 0 RTG WT 0.0 TOR{IUE ON BHA WEZGI'IT MIN ZD P/U 0.0 TORQUE OFF DP FTGE O.O TYPE (MIN ZO) S/O 0.,0 TO~JE ~ ~NTS: CO~T$ ]NCLLI~E prj~p, M~T~, ALL CO LAii~ AND ETC, Oil & Gas Cons, Corr_.uDissi~F' Anchora.qo OCT 18 '98 ?:58 ?-_. TO--~HEAR PAGE,OOR A~T; SPUD= FTGE= 0 AFE: 10 RIG; g2E lelTVD: PROGRESS: DRL; HAS; PROPOSED TD: SECTION TD= Conoco DalLy D¢~L[~g Report 0.0/0,0 0.0 ¢ 0,0 DRILLS PIT: TRIP: FIRE/ABANDOn: POLLUTION: CURRENT PLANNED FOI~ATIOIt: TESTING TBG HANGER _.. CONDITION: SNO~ TEMPERATURE: 18.0 gZNO CSPEEO/DIR): 25.0 gAVE CflEIG#T/DIR)~ 0.0 ACCIDENTS; ~ NONE SAFETY MEETINGS C # ~ mfn ); 2 ~ 5.0 11 PlO 6F 1.50 00;00 01~30 11 P9 13A 5,00 01:30 06:30 11 P9 &5 1.50 06:30 08:00 11 P9 13A 8.50 08:00 16;30 11 P9 45 3.50 16;30 20:00 I~ P9 45 1.50 20;00 21:30 11 p9 13A 0,50 21:30 22:00 11 P9 S g.O0 ~;00 00:00 0.0 LDPUMP ANO~OTOR, RECOVERED 501 BAND; 0,0 PUANO SERVICE NL~dPLIMp AND MOTOR 0,0 SPLICE ARNOR 0ti ESP CABLE 0.0 RIN g/ ~BG~ PU PAC:KER AND INSTALL PIGTAIL 0.0 SPLICE ESP CABLE BELOg PKR 0.0 PU SSSVAND ~NSTALL, H~ CONTROL LiNE AND TEST SANE O.O RI~ TO LAST dOINT, STARYED TAKING gEIGflT, PU 0.0 RUAMD CIRCULATE RAN C~JT OF SOURCE ~TER, 8.20 0 0.0 0,00 0.00 0.00 0,1)0 0,0 O.O0 0.0 0.00 O.O0 0,00 0,00 0,00 0.00 0.00 0,00 0,0 0 SOLIRCE~ PIT DA~LY MUD; 0.00 CUMULATIVE MLIOt 0.00 SERVICE PERSONNEL ~ CONOCO, 3~ NABOBSt 1BAROID, 2 PEAK, LOGISTI, 2 gEATH, 2 CENT, 1EgS PEOPLE AT LOCATIO~ 8lTg T 2 0 Bas GoDs. Go MATERIALS gARITE BENTONITE BLEND NEAT HELIFU~L DIESEL DRILL gATEE POT gATER BASE OIL BRINE 0.0 0,0 0,0 0,0 0,0 0.0 0.0 0,0 0,0 AFE# 10'61'1501 AFE 1227409.00 AFE SUPPL 0.00 AFE TOTAL DALLY CLM. DRILLING 67058,00 ;?.27116.$~ TROUBLE 0.00 8775,50 LOST TINE 0,00 ADDITIONAL 0,00 8775,50 TOTAL 4?058,00 $16698,00; MUD PUMPS CIRCULATING SYSTEM MiNi~TEc: O. 0 R~R .... Ii ii SLOIdPUMP RATES · DEPTH 0,0 DEPTH 0.0 Pt,MP 1~ O.O;~O PLOP I: O.C~O Pt~P 2; 0.~0 P~P 2: 0,~0 ~EHT: 0.~0 CEMENT; 0.~0 OCT I8 ~ 7:55 .~. TO-'~"4ERR PRGE.00~ DaiLy OtilJing Repor~ BOTTOM HOLE ASSENIILY # LENGTH HRIS ON JARS 0 RTG VT 0.0 TCIRI:IUEON BHA b'EIGHT l~[g lO P~ 0,0 T~ OFF DP FT~ 0,0 T~E (HIN I0) S/O 0,0 T~ ~ _._~: ~:.: ~:~.~ .-.. _ SHO~I ::::::::::::::::::::: ................. ~: .............................. ::~.s..~ ............................. ~.:.~:,,~..s..: ................................. ~o.~ .................................. ~ .......................... .e..~.:~ ......... ~.:.~::.,,:~.::~.,.:~:~.:..,.~ ~.~a::~:::::::::::::::::::::::::::::::::::::::::::::::::::: ~.:., J I I COMNENT~: REASON TAKING ~EIGHT ~AS ICE PLUG O CT 2 0 199~ 41aska 0il & Gas Cons. Commission Ar~chorage DAYS MD/TVD '. 0.0 / O. 0 DR l L LS CONO / T ! ON = OVERCAST ACT: 6 PROGRESS :- 0.0 P' ! T '- N TENPERATURE .' Z2.0 SPIJO-* 6 DRLG HRS: TRIP: N WIND (SI:~ED/DIR): 0.0 FTGEt O PROPOSED TD'. ( ) F[RE/Ai~NDONi N WAVE (HEZGHT/I)]R).' O.O AFE; 10 SECTION TD: 0,0 POLLUTION: N RIG: 22E CURRENT PLANNED FORMAT ION HOVING RIG TO L-11 ACCIDENTS: NONE .~A. FETY HEETINO$ ¢ # ~ min ): 2 ~) 5.0 0 El 0.0 0 ~1 0.0 11 P9 29A 1.50 O0=O0 01;30 tl P9 5 O.SO 01:30 02:00 11 1:,9 13A 1,00 02;00 05:00 11 P9 I~A 2.50 03:00 05~50 11 ~ 15c 2.00 05:30 07=30 11 P9 5 1,50 07:50 09;00 11 R9 15E O.SO O~:O0 0~:30 11 I~ 24 1,50 09:30 11:00 11 p9 14A &.O0 11:00 15:00 1t P9 I~C 2,50 15;00 17:30 11 1:,9 31g 3,00 17:30 20=50 11 P9 5 0,00 20t30 20;30 0,0 WAITING ON SOURCE WATER 0.0 CIRCULATE & RIH PAST ICE 0.0 NU LAST JT AND HANGER 0.0 SPLICE ESP CABLE AND RU SPOOLING UNIT 0.0 INSTALL $S~VTgG iN HANGER, LAND HANGER LOCK~ HANGER, iNJECT SEALANT iN HANGER~ TEST HANGER TO 5000 PSI, OK 0.0 DISPLACE ANNULUS W/ 58 BBLS OF DIESEL AND TBG W/ 12 9BL$ OF DIESEL 0.0 DROP' BALL AND SET PKR W/ 3000 I:~I, TEST 0.0 LD LANDING dO[NT, iNSTALL BPV, CLEAR FOR OF TBG TOOLS O.O NU/ND BI~)~S, CHANGE RAMS TO 5", RD FLOWLINE~ CLEAN P~TS~ 0.0 NU YREE, CHANGE MASTER VALVE~ PULL BPV, S~T TWO CHECE, TEST TREE AND SEAL$, SET TWO WAY CHECK, 0.0 FINISHING CLEANING OUT ~ITS, VAC OUT CELLAR, DISPLACE FLUIDS, DISPLACE L-I~ 7" x 9 5/8" ANNULUS W/ DIESEL O.O RELEASED.RIG AT ZO$O HRS ON 5/22/93 8,50 0 0.0 0.00 0.00 0.00 · ~URCE: PiT DAILY HUD: .. 0.00 0.0 0,00 0,0 0.00 0.00 ~-dMULAT I VE MUO: O.OO 0.00 0,00 0,00 0,00 0,00 O.O0 0.0 0 ~URVEY SERVICE PERSONNEL 1=0C0, 34 NAB, S, ~PEAK, 15. LOGI$TI,..J ..,~.~,.~ gAROID. I BAK. R RECE - PEOPLE AT LOCATION 40 0 CT 2 0 !997 Aiask~ Oil & Gas Cons, Cornm Anchorage , NATERIAL$ BARITE o.o BENTONITE O. O BLEND 0.0 NEAT 0.0 HELl FUEL 0,0 0.0 ;~LLLwATER 0.0 POT WATER 0,0 BA~E OIL 0.0 BRINE 0,0 AFE# t0-61-1501 AFE 1227~09.00 AFE ~JPPL o,oO AFE TOTAL 1~27~09,00 DAILY Ct,IH, DRILLING &1~67.00 2~9083,52 TROUBLE 0.00 8775.50 LO~T TINE 0.00 72030.48 ADDITIONAL 0.00 8775.50 TOTAL &1967.00 358665.001 t DalLy DrilLing Report P~GE.01! C;ZRCULAT%NG SYSTEN FLO~RATE PRESSURE H~ STROICE$ 0 DP #ZNUTES 0.0 ASR PUMP I~TES OEPTH 0.0 DEPTH 0.0 ~ 1; O.OaO PU~P 1: 0.1~0 PUNP Z; O.OgO ~ Z: O.C~O :rdtENT: 0.i~0 CEI~NT; BOTT(~ HOLE AS~ENBLY # LENGTH HAS ON JARS 0 RTG ~T 0.0 TORQUE ON BHR 'Id~IGHT NIN ID P/U 0'.0 TI~gUE OFF DP FTGE 0.0 TYPE (HIN 1P) S/O 0.0 TORI:IUE MAX SHO~S ~, :~,-¢-~:¢~,:s~-* ~m-C.:;I:~.".$:~&.'.'..'~:~:;~:~-:;:::(::~:ig:~-':¥:~.:.:.:<::-..~:4:~:.~ :;::-':'-.~.-:~-x:::.-: ::¢: .......... :< ¢:-..-::.>:.~ ~:~ ;i ~::.']2 ~;;~.'.;x.,:w;.'.;:: ;;~::::;.~;.~::~¢ !~ ~:::~::~.~ :L~,.:}~.~::~ ;:L%:.~:~],~!.?~.~!~!S ~!D~;.x..~ ~S~2 ~.~..~.:.:::~*:.-~.:*~-. ~::> <,<,.,.:.~.:.;.× ~ (;:::~:i;:-'.:)::,;..'.~. I:~NT$.' RAN ~ ~NDS RE{EIVED 0 CT E 0 Alaska Oil & Gas Cons. Comrnissior' Anchorage Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 April 21, 1993 ORIGINAL Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission. 3001 Porcupine Drive Anchorage, Alaska 99501 RE: APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached is an Application for Sundry Approval, Form 10-403, for replacing the electrical submersible pump and installing additional downhole equipment, as described in the attached procedure summary, in Milne Point Unit well L-1. Please direct any questions regarding this application to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist Attachments RECEIVED APR 2 6 1993 Alaska 0ii & Gas Cons. Gommissior~ Anchorage CC: CVL, JHA, TJY Chevron Occidental L-1 Well File STATE OF ALASKA AI..~S~ OIL AND GAS CONSERVATION COMMIoolON APPLTCAT'rON FOR SUNDRY APPROVALS 0 L 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing __ Repair well __ Plugging__ Time extention __ Stimulate__ Change approved program __ Pull tubing __ Variance __ Perforate Other X Replace ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development x 56' KDB feet 3. Address Exploratory , 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic__ Milne Point Unit 4. Location of well at surface 8. Well number 1970' FNL, 5122' FEL, Sec. 8, T13N, R10E, Umiat Meridian L-1 At top of productive interval 9. Permit number 2253' FNL, 5179' FEL, Sec. 8, T13N, R10E, Umiat Meridian 84-5 At effective depth 10. APl number 2304' FNL, 5216' FEL, Sec. 8, T13N, R10E, Umiat Meridian 50-029-21068 At total depth 11. Field/Pool 2393' FNL, 323' FEL, Sec. 7, T13N, R10E, Umiat Meridian Kuparuk River Field 12. Present well condition summary Total depth: measured 9500' feet Plugs (measured) 7390' true vertical 9420' feet Effective depth: measured 7390' feet Junk (measured) true vertical 7365' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 74' 13-3/8" To Surface 130' 130' Surface 2427' 9-5/8" 1000 sx Coldset III 2483' 2483' Intermediate 750 SX Coldset II Production 7467' 7" 1300 sx Class G 7523' 7486' Uner Perforation Depth: measured 7068-7128'; 7160-7180'; 7186-7214' RECEIVED true vertical 7040-7098'; 7130-7149'; 7155-7183' Tubing (size, grade, and measured depth) 2-7/8", L-80, 7011' APR2 6 199; Alaska 0ii & Gas Cons. Commission Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 514'; Otis RDH Pkr. 535' Anchorage 13. Attachments Description summaryof proposal X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: July 1, 1993 16. If proposal was verbally approved Oil X Gas __ Suspended __ Name of ap prover / Date approved Service 17. I hereby ce tify that~~foregoing is true and correct to the best of my knowledge. / Signed ~ r~l /'~ ~0~ J.H. Andrew Title Sr. Production Engineer Date April 20, 1993 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness/IAppr°val No.7 Plug integrity__ BOP Test__ Location clearance __ -'; ~_~ C, ot~¢J Mechanical Integrity Test ~ Subsequent form required 10- ~/O~f \°?'~'~' · ' ~ ' ,.-~ r.:'~'~ ~~ .;~7 Origins! 8!,zned By ~_~.~¢--~ Approved by order of the Commission David W. doi~nston Commissioner Date '~' ~,~ ~).-- Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE le · · · · · · · · 10. 11. 12. 13. Milne Point Unit L-1 Well ESP Replacement Procedure Summary MIRU Nabors 22E rig. Kill well by circulating hole full with 8.4 ppg source water. ND tree. Nil and test BOP's. MU landing joint to tubing hanger. PU 25,000# above pipe weight to release Otis RDH retrievable packer at 556'. POOH with 2-7/8" production tubing and ESP. RU wireline. GIH and tag sand fill in casing. POOH and RD wireline. TIH with sand bailer on production tubing and bail to clear perf interval, if necessary. Perform casing cleanout procedure if sand is bailed. MU new ESP assembly and TIH on 2-7/8" production tubing. Install check valve two joints above pump and gas lift mandrel with dummy one joint above check. MU an Otis dual packerwith side penetrator. Install gas lift mandrel with gutted check valve one joint below. Install a 2- 7/8" tubing retrievable SCSSV in the production string above the packer and space out to place SCSSV at least 500' below ground level. Land production tubing hanger. Freeze protect tubing and annulus. Set packer bypressuring up against a wireline plug run below the packer. Pressure test packer bypressuring up on annulus to 1800 psig. ND BOP's, NU and test tree. RDMO rig. RU and test flowline. Return well to ESP lift production. RECEIVED Alaska Oil .& Gas Cons. CommiSsion Anchora9o WELL No. COMPLETION MILNE POINT SKETCH UNIT (P) APl No.: 50-029-21068 PERMIT No.: 84-5 COMPLETED: 4/27/84 LAST WORKOVER: 7/15/91 WKM TUBING HANGER W/ 2 1/2" "H" PROFILE BPV (NEEDS FIELD VERIFICAllON) ~ 15 JTS 2 7/8', 6.5#, L-80, 8rd EUE TBG 1/4" S.S. CONTROL LINE- EIFCTRlC SUBMERSIBLE PUMP CABLE -- NO. 4 AWG CL .550 ABOVE PKR NO. 2 AWG 01_ 550 BELOW PKR NOTES: 1. ALL DEPTHS MEASURED KDB = 31.5' KDB-SL --- SL-56' 2_. MAX. ANGLE = 12'7' @ 8157' & K.O.P.: 2933' ,~. SLANT HOLE: YES 5. MIN. ANGLE: .28' @ 7278' 6. TREE T~Pa C^M~ON WELLHeAd/fMC ~ 1/8' VALVES. 5000#, W/~ 1/2" TREETOP CONNECTION 7. MIN. i.D. = 1.875"' @ 565' 8. COMPLETION FLUID:. 11 PPG N~CL 9. FRACTURE STIMULA.110N 10/50/90 PUMPED 194,495 Fs 16/20 MESH CARBOUTE 10. NO ESR CHECK VALVE 535" 542' 556' 565' 570' ~605' ~6881' 6952" 6953" ~6997' OTIS 2 7/8" "FMX" TRSV LOCKED OUT 2.313" OTIS FXE WRLSV "XO" 2 5/8" x 2 7/8" (1.995" I.D.) OTIS 7" 'RDH" PACKER (1.94' I.D.) OTIS 'X" LANDING NIPPLE (1.875" I.D.) "XO" 2 7/8" x 2 3/8" (1,995" i.D.) 2 7/8" CAMCO GLM W/ ORIRCE (2.547" LD.) OTIS 2 3/8.". "XA" SUDING SLEEVE (!.D.:1.875") 'XO" 2 5/8" x 2 7/8" (1.995 I.D.) TOP OF ESP CENTRIUFT FC 650, 245 STAGE 100 HP FRSXT HP-2 INTAKE BOTTOM OF ESP PERFORATION DATA MD l'VO DEPTH: LZ 7068'-7128' (7040'-7098') LK- 1 7160'-7180' (7129'-7149') LK-2 7186'-7214' (7155'-7182') DENSITY: 12 JSPF RE¢£1VED APR 2 6 199~) Alaska Oil & Gas Cons. Gomm~sS~O~--" Anchorago 7390' HALIBURTON MODEL "N" QUICK BRIDGE PLUG 7436' PBTD 7523' 7', 26~, L--80 BTRC CONOCO INC. A~','CHORAGE DI\qSIO:': APPRO'¢£D BY: JHA/HDS ~'-', ,. :-%-,'h ..BY: CF'!?' DATE: CAD F~i.E: ','.'CO~' STATE OF ALASKA ALA;. -., OIL AND GAS CONSERVATION COMMI5 REPORT OF SUNDRY WELL OPERATIONS Stimulate __ Plugging ~ Repair well __ I5. Type of Well: Development Exploratory Stral]graphic Service 1. Operations pedormea: Operation shutdown ~ Pull tubing ~ Alter casing __ 2. Name of Operator CONOCO INC. 3. Address P. O. Box 340045, Prudhoe Bay, AK 99734 Perlorate __ ~1~~.~ % '~- Other REPL 6. Datum elevation (DF ~r KB) Location of well at surface 158' FWL, 1970' FNL, SEC 8, TI3N, RiOE, UM At top of proouct~ve interval 102' FWL, 2258' FNL, SEC 8, Ti3N, RiOE, UM At eflecbve depth 64' FWL, 2303' FSL, SEC 8, T13N, R10E, UM At total depth 307' FWL, 2394' FSL, SEC 7, T13N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective oepth: measured true vertical Casmg Structural Conductor Surface Intermediate Production Liner Perforation deptl~: 9500' RKB feet Plugs(measured) 9421 ' feet 56' KB MSL feet 7. Unit or Property name MILNE POINT UNIT 7390' RKB feet Junk (measured) 7355 ' feet Size Cemented Measured depth 13 3/8" CMT TO SURF 130' 9 5/8" 1750 sxs 2483' 7" 1450 sxs 7523' - 7128' 7160' - 7180' 7186' - 7214' , , ~ngth 95' 2448' 7488' measured 7068~ truevertical 7040' - 7098' 7129' , '¢Jbmg (s~ze, grace, and measured depth) 2 7/8", 6.5¢/', L-80, EU to 6881' (BOTTOM OF Packers and SSSV (type and measured depth) OTIS ' ~t~C(: ' sssv @ 542' (510' RGL)¢ OTIS Stimulation or cement squeeze summary Intervals treated (measured) 13. 8. Well number 9. Permit number/approval number 84-5 10. APl number 50-- 029-21068 11. Field/Pool KUPARUK RIVER - 7149' 7155' , CENTRILIFT FC 650 'RDH' @ 556' - 7182' ~ue ~rticaldepth 130' 2483' 7486' SUBMERSIBLE PUMP AT 6997) RE('EIVED %reatment description including volumes used and final pressure DEC 1 4 1992 Alaska Oil & Gas Cons. 6ommis~ Anchorage 14, Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Tubing Pressure Service Date SUBMIT IN DUPLICATE 16. Status of well classification as: Oil X 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 Title SR PRODUCTION FOREMAN CONOCO INC. WELL: /~'/P'u /_~2 PROJECT: ¢~'E ,C~L.,~ d E ACTIVITY AT REPORT TIME: DAILY WELL ACTIVITY REPOR'I ALASKA C~/ ~ G ~~ ~~ CURRENT DEPTH: 7~ ~ ACTEflTY D E C 1 4 SERVICE PERSONNEL- NO. d ~ ~ 0-_~ 2.1 ~) ~-"/'~ '~ ~UID~PE/DENS~: ~~ ~'~ PPG~LOSSESTODAY/CUM RIG S~ PERFOR~CE ~ ~L DNLY COSTS ~s w~,ou~! 7s I~q ~/c~ ~/~ ENVIRONMENTAL INCIDENTS DAYS WITHOUT ,-~Z YEAR TO DATE ..~ ENGINEER / .~o O BBLS J CUM. FLUID COST: $ ~,,//L_/ PILLS SCSSV OPEN~ BP~I~OUT PLUG DESC. COST SUMMARY PREVIOUS TOTAL PLANNED TROUBLE TOTAL DALLY 0 5~= AFE COST .,~,.,~ ,~'//~/~ EST. FINAL COST · J SUPERVISOR ~L~ c-- CUMULATIVE r ~ co co Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 June 11, 1991 Mr. David Johnston • Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: RE: Application for Sundry Approval; Milne Point Unit; Well L-1 Attached please find an Application for Sundry Approval for WeII L-1 at the Milne Point Unit. If you have any questions or require additional information please contact me at 564- 7617. Yours very truly, Bob Soptei Environmental Coordinator _ ~ +~ ~'`~ ~,~, RJS(jcd) Attachments cc Well L-1 File _- ~ STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMI ION appilr_ArioN FoR SUNDRY APPROVALS` 1. Type of Request: Abandon _ Suspend _ Operation shutdown _ Re-enter suspended well After casing _ Repair well _ Plugging _ Time extention _ Stimulate _ Change approved program _ Pull tubing _ Variance Perforate _ Other X Replace ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc Development x 56' KDB feet . 3. Address Exploratory _ 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigrapnic _ Milne Point Unit Service 4. Location of well at surface 8. Well number 1970' FNL, 5122' FEL, Sec. 8, T13N, R10E, Umiat Meridian L-1 At top of productive interval 9. Permit number '~ ~ 2253' FNL, 5179' FEL, Sec. 8, T13N, R10E, Umiat Meridian $ ~ . At effective depth 10. API number 2304' FNL, 5216' FEL, Sec. 8, T13N, R10E, Umiat Meridian 50-029-21068 At total depth 11. Field/Pool 2393' FNL, 323' FEL, Sec. 7, T13N, R10E, Umiat Meridian Kuparuk River Field 12. Present well condition summary Total depth: measured 9500' feet Plugs (measured) 7390' true vertical 9420' feet Effective depth: measured 7390' feet Junk (measured) true vertical 7365' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 74' 13-3/8" TO Surface 130' 130' Surface 242T 9-5/8" 1000 sx Coldset III 2483' 2483' Intermediate 750 sx COldset II Production 746T 7" 1300 sx Class G 7523' 7486' Liner Perforation Depth: measured 7068-7128 ; 7160-7180 ; 7186-7214' true vertical 7040-7098; 7130-7149'; 7155-7183' )' , ,. ~. Tubing (size, grade, and measured depth). 2-7/8", L-80, 7011' Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 514 ; Otis RDH Pkr. 535' 13. Attachments Description summary of proposal X Detailed operations program _ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: July 15, 1991 16. If proposal was verbally approved Oil X Gas _ Suspended _ Name of approver Date approved Service 17. I hereby ce fY that t e foregoing is true and correct to the best of my knowledge. si nea ~~( ~~ J. H. Andrew rue Production En ineer Date June 10 1991 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. ~ ~ ~...-~ "'~ Plug integrity _ BOP Test _ Location clearance uired 10-~~ ~ Subse uent form re rit T i l I t t M h GOPy q q y an ca n eg es _ ec Vea n~ppro Returned ~~~ ORIGINAL SIGNED BY ~ ~ v~ / Approved by order of the Commission LONNIE C. SMITH Commissioner Date (.l' "'~ Form 10-403 F[eV O6/15/t3S CJ ~/ SUBMIT IN TRIPLICATE ~~ .~- 1 -. • • Milne Point IInit L-1 Well E3P Replacement Procedure Summary 1. MIRU workover rig. 2. Kill well by circulating hole full with 8.4 ppg source water. Spot salt-based LCM pills, if necessary, to control fluid losses. 3. ND tree. NU and test BOP's. 4. MU landing joint to tubing hanger. PU 25,000# above pipe weight to release Otis RDH retrievable packer at 535'. 5. POOH with 2-7/8" production tubing and ESP. 6. RU wireline. GIH and tag sand fill in casing. POOH and RD wireline. TIH with sand bailer on 2-7/8" production tubing and bail to clear perf interval, if necessary. 7. MU new ESP assembly and TIH on 2-7/8" production tubing. 8. MU an Otis RDH packer with annular vent valve. Install a 2- 7/8" tubing retrievable SCSSV in the production string above the packer and space out to place SCSSV at least 500' below ground level. 9. Land production tubing hanger and freeze protect annulus. 10. RU wireline and set a plug in an Otis X nipple located below the production packer. Pressure up against the plug to set the packer. POOH with plug and RD wireline. 11. Pressure test packer and annular vent valve by pressuring up on annulus to 500 psig. 12. Freeze protect tubing. ND BOP's, NU and test tree. 13. RDMO workover rig. RU and test flowline. Return well to ESP lift production. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ 2. Name of Operator CONOCO INC. 3. Address P_I'I_ ROX' .3&rll"l&R_ PRIII3HI'iF RAY. Al( 4. Location of well at surface 158' FWL,1970' FNL, At top of productive interval 102' FWL, 2258' FNL, At effective depth 64' FWL, 2303' FSL, At total depth 307' FWL~ 2394' FSL, 12. Present well condition summary Total depth: measured true vertical SEC 8, T13N, SEC 8, SEC 8, SEC 7, Effective depth: measured true vertical Casing Length Structural Conductor (-I-/- ) 9 5 Surface 2448 ' Intermediate Operation shutdown Re-enter suspended well _~. Plugging __ --Time extension__ Stimula~_.Z. Pull tubing -X- variance __ Perforate --X' Other 5. Type of Well: Development _.~ Exploratory __ Stratigraphic ~ RIOE,UM. T13N,R10E,UM. T13N,R10E,UM. T13N,R10E,UM. 6. Datum elevation (DF or KB) 56' KB MSL 7. Unit or Property name MILNE POINT UNIT 8. WeU number L-1 9. Permit number 84-5 10. APl number 50- 029-21068 11. Field/Pool KUPARUK RIVER ~.I~:RKB feetfeet 7390' RKB feet 7355' feet Size 3/e" 5/8" Plugs (measured) Junk(measured) Cemented Measured depth OTIS "PX" PRONG WITH LOCKING MANDREL 07012'RKB True vertical depth CMT TO SURFACE 1750 SKS. (+/-)130'RKB (+/-)130' 2483'RKB 2483' feet Production 7488 ' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 11 7068' TO 7160' TO 7186 TO 1450 SKS. 7523'RKB 7486' 7128' RKB 7180' RKB 7214' RKB RECEIVED 7040' TO 7098' 7155' TO 7182' 7129' TO 7149' OCT 1990 3 1/2", 9.2#/FT., L-80, 7043" RKB ""';;~;~i;..'[~ll[~li0ra~ Packers and SSSV (type and measured depth) BAKER "SAB" HYDRAULIC PERMANENT PKR. @ 6970' RKB. CAMCO TRDP -lA SCSSV g 2019' RKB 13. Attachments Description summary of proposal __ L- 1 RE-COMPLETION PROGRAM Date approved 14. Estimated date for commencing operation nCTNRFR 7.3, lggo 16. If proposal was verbally approved Name of approver Detailed operations program ~ BOP sketch __ 15. Status of well classification as: Oil .,[. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title ~p_, "~D~c)O,3c. rtOt,,t ~-~~:~' FOR COMMISSION USE ONLY Signed · Gas __ Suspended __ Date to ~.'~.,~ ~ ~ Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ,~. (} Zf Original Signed BY David W Johnston Approved Copy · Returned Approved by order of the Commission .~O [~;x~j ~ Commissioner Form 10-403 Rev 06/15/88 IAppr°va'N°' ?0- Date SUBMIT IN TRIPLICATE MPU L-1 WELL Milne Point Unit PROPOSED REPERF, STIMULATION, ESP RUNNING PROCEDURE AFE No. 10-61-1319 (Reperf & Stimulate) AFE No. 10-61-1320 (P&I ESP) 10/11/90 - CVL Objective: Pull existing tubulars; burn over packer; clean the wellbore fluids; perforate the LK-2, LK-1, and LZ sands; fracture stimulate; run an ESP and postpone start-up until surface equipment hook-up is completed. Surface Location: 1970' FNL & 158' FWL of Sec. 8, T13N, RIOE Depths: All depths are measured from original RKB (56.0') and open hole logs dated 4/8/84. Casinq: Surface: 9-5/8", 47 #/ft, L-80, btrs. set @ 2483' Production: 7", 29 #/ft, L-80, btrs. set @ 7523'. Capacity = 0.0371 bbl/ft Drift ID = 6.184" Burst Pressure = 8160 psi Tubinq/workstr: Misc: 2-7/8", 6.5 #/ft, L-80, EUE 8rd (approx. 7000' required). Capacity: 0.00579 bbl/ft tubing; 0.0291 bbl/ft annulus ID: 2.441"; Drift ID = 2.347" Burst Pressure = 10,570 psi Torque (ft-lb): Min : 1730; Optimum = 2300; Max : 2880 3-1/2" ~s,~~drill pipe for burning over packer PBTD = 7390'("N" BP) TD = 95OO' Present tubing = 3-1/2", 9.2 #/ft btrs & DSS-HT (40,000 lb shear from PBR) Wireline plug = Otis "PX" prong/plug in "XN" nipple @ 7012' Baker "SAB" packer @ 6970' (w/ millout extension) Pore pressure = 9.6 ppg equivalent (3500 psi) Fluid in well = Diesel Proposed workover fluid : 9.9 ppg NaC1 Proposed completion fluid = 11.0 ppg NaBr/C1 {10 deg F TCT} Max Angle = 15 deg; Angle through pay = 11 deg RECEIVED OCT 2 91990 ;Anchorag~ Proposed RU, Tubinq Pull inq, and Packer Burninq Procedure: NOTE: Hold frequent on site safety meetings prior to all potentially hazardous tasks. 1. Skid rig to the L-1 well and RU on well. ND tree. NU BOP's. Install pipe rams for 3-1/2" tubing. Test rams to 250/4000 psi and test Hydril to 350/3500 psi. Record tests on AOGCC and Conoco daily reports. 2. Back out hold down pins for tubing hanger. Latch into tubing hanger and pull 40,000 lbs over string weight @ PBR @ 6957' to shear out of PBR. 3. PU 5' above PBR. Circulate out diesel by displacing at maximum pump rates with filtered 9.9 ppg NaC1. Di~$placement should consist of a 5 bbl HEC (2-3 #'s/bbl) spacer pill followed by 250 bbls of brine. NOTE: Safety and environmental precautions must be taken when handling brine and chemicals. Review MSDS sheets prior' to handl i ng. /q' ' _ ' ~ _-/~"~!! ~1~1 (]~ C_~~ F, Li]q/, F~,L,, __~. 5. POOH and L/D tubing. Monitor hole and replace displacement w/ filtered 9.9 ppg brine while POOH. 6. MU burning shoe w/ packer plucker (3.25" bore through packer) on 1 joint of washpipe and GIH to Baker "SAB" pe~anent packer ~ 6970' on 3-1/2"~ ~ drill pipe. Burn over slips and POOH slowly. Monitor hole while POOH. L/D packer and fishing equipment. Proposed Wetlbore Cleanup, ,Procedure- NOTE: Hold frequent on site safety meetings prior to all potentially hazardous tasks. I · MU bit w/o jets and full gauge nominal rotatable casing scrapers on drill pipe. . PU drill pipe and GIH to 7390' to verify sufficient rathole exists. PU bit to 7220' (below bottom perf @ 7214'). Reverse circulate the following cleansing pill at maximum pump rates. C, Lead pad - 25 bbls of 3.5 #'s HEC/bbl of brine Chemical pad - 50 bbls of brine + i drum of surfactant/dispersant(Safe-Kleen, Dirt Magnet, etc..) Tail pad - 25 bbls of 3.5 #'s HEC/bbl of brine Post flush - circulate with filtered brine (10 microns) at maximum rates until less than 50 NTU NOTE: 1. Safety and environmental precautions must be taken when handling brine and chemicals. Review MSDS sheets prior to handling. 2. Chemicals must be mixed and maintained above 70 deg F. 3. Monitor brine clarity every 50 bbls during post flush with a Turbidity Meter. Submit results to engineering. 4~ If fluid losses are excessive, PU above top perf @ 7068' and continue sweep. 3. POOH and L/D drill pipe. Proposed LK-2, LK-1, LZ Reperforatinq Procedure: 1. RU Schlumberger electric line. Hook up down-joint w/ pack-off and place in Hydril for pressure control. 2. Hold safety meeting and discuss hazards and required precautions associated with wireline perforating. Pressure test lubricator. NOTE: All Conoco and Schlumberger (see attached) perforating safety procedures must be strictly adhered to. These procedures and safety meetings shall be repeated with each subsequent gun run. 3. MU 13' x 4.5" OD gun assembly (5 SPF, 37gm, 51B deep penetrating charges) · --~-with GR/CCL for depth control. GIH and correlate w/ open hole logs. Place guns on depth and shoot LK-1 @ 7167'-80'. POOH and monitor hole. L/D spent guns. NOTE: Measure OD and length of all tools to be run in the hole. Measure and record distance from top shot on gun assembly to GR/CCL. 4~ Repeat step 3. three additional times as follows w/ CCL as depth control, if first run proves CCL correlation feasible. Se Run No. Length Interval Sand 2 28' 7186'-7214' LK-2 3 30' 7098' -7128' LZ 4 30' 7068' -98' LZ RD electric line. Monitor fluid level. Do not attempt to keep the hole full to surface. This may result in large volumes of fluid lost to the formati on. Proposed Hydraulic Fracturinq Procedure: · Spot seven 500 bbl frac tanks on location. Elevate the rear of the tanks approximately 8". Visually inspect the interior of the tanks for cleanliness. DO NOT ENTER THE TANKS. Fill five tanks with 475 bbls clean injection water. Check pH of injection water in each tank and neutralize if necessary. Fill the sixth and seventh with 205 bbls filtered 11.0 ppg NaBr/C1 completion fluid w/ 4 gal/lO0 bbl Unitreat 3900 biocide/inhibitor for flush. The water/brine should be heated and filtered to 10 microns absolute with a hot oil truck and maintained at 75 to 80 degrees F to insure proper hydration of the gelling agent. Water from the central facility, carried in clean transports is acceptable. 2. Rig up Dowell Schlumberger to perform the frac treatment. NOTE: a. Use of threaded connections, crossovers, swedges, etc. in the treating line is not acceptable. b. Use two in-line densitometers. c. Use two shut-off valves on the wellhead. d. Set the backup pumps for the crosslinker and diesel. ee Standby pumps (50%) are required. These pumps must be manned and primed to come on line immediately if needed. A standby blender should be hooked up and ready to come on line in case of primary blender failure. f. BOP saver installation shall be coordinated by Conoco and DS personnel on-site prior to frac RU. Insure that "donut" is butted against 4" pipe rams prior to pumping. g. Tank bottoms are included in the volumes listed. Plan for 75 bbl tank bottoms. he Use the in-line densitometer during the treatment. rate, pressure, and density on a chart. Record i · Take samples of the crosslinked gel during the treatment. Place these samples in a bath at 170 deg F. Note the actual break time. Note the pre-pad is not crosslinked and does contain diesel. j · Shut down after pre-pad for meter to tank verification and 15 minute pre-job ISIP. k. DO NOT OVERDISPLACE THE TREATMENT UNDER ANY CIRCUMSTANCES. . Batch mix 2375 bbl gelling agent at 50 lb/lO00 gal with additives. The pre-pad consist of non-crosslinked gel (no diesel). Particulate fluid loss additive (40#/1000 gal)should be added in ~,~p~r~-~t~nm~pad fluids Page 5 OCT 2 91990 A/asa.Oil .& Gas Cons. GQmlliis$1Oln chorage only. Diesel (5%) and crosslinker activator are the only additives that should be mixed on the fly. Sand (Carbo-Lite) will be added in the prescribed stages through the blender. 4. Hold on-site safety meeting with rig personnel and frac crew to communicate hazards of the operation. Se Pump the frac job as follows at 40 BPM' Stage Name Stage Barrels Cumulative Treat Pump Proppant Gel Pumped Barrels Press Time (Lbs) (Ea. stage) Slurry Pumoed (psi) (Min) Pre-Pad - 0 200 200 3100 5.01 PAD 0 1200 1200 4100 30.0 2 PPG Slurry 5400 64 1270 4000 1.8 4 PPG Slurry 11000 65 1350 3800 1.9 6 PPG Slurry 22900 91 1460 3500 2.9 8 PPG Slurry 37300 111 1610 3200 3.8 10 PPG Slurry 53100 126 1790 2900 4.6 12 PPG Slurry 63300 126 1990 2700 4.8 FLUSH 0 258 2248 2500 6.2 , e Shut down. Allow the pressure to bleed off into the formation. Record the ISIP, and pressure for 30 minutes (5, 10, 15, and 30 minute readings). Close all surface valves and leave the well shut in. Insure well is dead. Monitor the break time of the last sample collected. Rig down pumping equipment. 7. After the frac treatment there is a possibility of proppant in the wellbore. Rig up slickline and RIH with a sinker bar to insure the perforations are clear. Tag bottom to identify the amount of proppant in the casing. Rathole should be sufficient to prevent proppant from covering the perforations. If the bar tags proppant in the perforation interval then GIH with bailer to remove proppant from the well to clear the perforation interval. Use the tubing 'bailer with sufficient barrel length based on fill. Rig down slickline unit when complete. Page 6 Proposed ESP and Tubinq Runninq Procedure: · MU ESP assembly on 2-7/8" tubing as illustrated on the attached Otis completion guide. Strap and record the length of each component. Run a standard Centrilift motor centralizer for 562 Series motors and 7", 29 #/ft casing on the bottom of the motor. . RIH w/ ESP no faster than 30' per minute. RIH w/ sliding sleeve in open position. Maintain sufficient hydraulic pressure on the control line while RIH to maintain valves in the open position. Attach two cable bands per joint. Attach additional bands above and below each cable splice. Set the bottom of the motor at 7035'. · Locate packer and safety valves such that the tubing retrievable SCSSV is at a depth of 500' or greater. Packers should be pinned to begin setting at approximately 1100 psi. Pump 52 bbl of diesel down annulus for 1800' of freeze protection prior to setting packer. . RU slickline and RIH w/ plug and set in "X" nipple located below packer. Pressure up to 1000 psi. Set packer by gradually increasing pressure from 1000 psi to 2500 psi in 500 psi increments. Retrieve plug and POOH. RD slickline. e Pump 11 bbl of diesel down tubing for 1800' of freeze protection prior to closing SSSV' s. 7, Bleed off control line pressure to close the annular vent valve and SCSSV. Pressure test the packer and vent valve system w/ 500 psi of annular pressure for 10 minutes. Bleed off pressure. connection for production. Prepared by: ~.,k~-~an Lin,begger Sr. Prod. Engineer ND BOP's. NU tree. RD and move to next well. Await surface facilities Reviewed by: Approved by: Marc Shannon Supervising Prod· Engr. t' ,/ I"' ~! · ;/,- D. E. Howell Production Supt. CC.' DEH, PMS, MPU Sr. Fm. (2), CVL, Original to File: L-1 Well File Page 7 o . =il' ~ -'~ 15 ~- · ~.. z~'. '. 19 FrW~n NAME: Milne Point l~:~'. NAME: L Pad "E~'P" C~etions (~: 7" 29~TR I. r80 ~ ~: 2-7/8" 6.4 LB E~3 8RD X 2-3/8" 4.6 LB ~3 8RD REFERE/~(~: 432/1001/01/90 [1~: Se~,~"~_r 17, 1990 ~u~ BY: Ray ~avers - An~, Alaska (907) 261-7780 t~gl~3.~£iC~ I.D. 1. 2-7/8" 6.4 lb ELTE Tubir~ 2.44" 2. Electric Cable - S~ 3. i/~" ~~ ~. 0.~9" W~ x ~' ~ 316 (P~ 22 ~ 31060) 4. 2-7/8" 2.3~" ~ "~ ~ ~o ,~~ s~, ~ ~ ~1-75, 2-7/8" 6.4 ~ ~ 8~ ~. ~ ~ ~ooo, (P~ 778 5. 2-7/8" 6.4 ~ ~ ~ 2.44" ~ Jo~ w/~~ 6. ~~~ ~1~ 2.44" 2-7/8" ~ 8 ~ x 2-3/8" ~ 8 ~ ~ ~105 2.313" 7. BIW Power Cable F_~t ~ For No. 2 Rmund Cable. 100 AMP, 2400 Volts, 4 KV Rated. Field A~le Male Connec~r and Power Feed Thru with a 20' Electric Cable Pig-Tail. (P/N 12 CO 1225) 8. Tubir¢) Seal Sub ~ptor 1.97" 2-7/32"-14 UNS-2 x 2-3/8" ~J 8Rd BxP (P/N 120 6722) 9. Otis Annular Vent Valve 1.83" 3,000 psi W.P. Set~ Depth 540', 2-3/8" EU 8Rd BxP (P/N 78 AVS 200~) i0. 2-3/B" 4.6 lb ED B Rd 1.99" P~p Joint P-lO5 668" · 25" 4.76" 3. 668" 2.25" 2.62" 3.09" EC=. 3.69" 3.06" 7.0' 6.0t .6' 23' 1.8' 2.61' 8.0t ~A,""~Septsm~oer 17, 1990 ",~ PA~E2 11. Otis "RUH" Dual Hydra, lc RetrievaDle Pr~d. Pac/~_r 7" 26-32 lb 2-3/8" ~J 8Rd Box x Pin - Pr~y and s~u~7, um~ strin~ s~t. Han:3er T~e. St~. Service (P/N 12 P/iH 7003) I.D, 1.94" 1.94" Sec. 12. 2-3/8" 4.6 lb ~J 8~d 1.99" Pu~ Join~ w/~ P-los 13. Otis "X" Selective Lar~ 1.875" Ni~le W/CouDlir~ P-L10 (Ni~le P/N ~ X 187~A ,,~,, ~ ~~ f~ 2-3/8" ~ 8 ~ ~)* a. 2-3/8" 4.6 ~ ~ 8~ 14. 2-3/8" 4.6 lb ~3 8 Rd 1.99" Pu~ Joirm w/cou~lir~ P-lOS 15. ;~tm~fcor 2-3/8" EU x 2-7/8" 1.97 ~ BxP P-105 ** 17A. 16. 2-7/8" 6.4 lb ~JE T~bir~ 2.44" 17. Otis circulat/r~ Ball 1.29" CaTxaher Shear ~. at 1,000 ~ D~f. f~ 2-7/8" ~ ~)* 2-3/8" ~ '~' S1~ 1.875" s~ ~r (~ ~/~ 18. ~ (1) 2-7/8" 6.4 ~ ~ 2.44" Jo~ of ~ or Jo~~ ~li~ 19. ~~c ~~le O. D.: 5.95" 3.06" 3.06" 3 · 06" 3 3.76" 3. 668" 3. 668" 3 · 093" 3.668" 7.1' 2.0' !.0t 4.0' .6' .80' 3.0' CENTRi[ :T EQUIPMENT QUOT/' ION A B&ke¢ ~uqnes comi:)an¥ 200 W. Stuart Roos~ Cir. · Ciaremore. Oklahoma 74017 · {91 $) 341-9600 8-03-90 :OTATI~3N NO. ' D2Z13-'06-22-3185 ;~SENq:ED By ' - 5. ~aS~;er ! '" CAPACITY ! TOTAL ~EAD 'I--- FREQUENCY .. soo 900 ,, CONOC0, INC. 3201 "C" Anchorage, ,, A~N: V~u ~neber~er w--EL~ N~M~: SP. GR. · 97 PERFS Below mcr. ~_E3-I'ING DEPTH . 7012 ..-,O% 50 ELH.L 17-5 mRIMARY vOLTAGE '-80 RED. SURFACE VOLTAGE2 ~00 REQUIRED KVA G.D.R. 3,~,3 CASING O.D. 7" WEIGHT 26~ TUBING SIZ~ 2-7/S" THR~D 8Td N~T Li~ SURFACE PS1 FRICTION LOS5 'T.D,H. Va~te a ~VARIABLE FREQUENCY - 60 HER~ ' 50 HERTZ MOTOR H.P, [00 VOLTAGE 2[45 AMPERAGE 27 NO. PCS. [ RATING SERIES-562 MODEL ~ ~ LENGth [2,0 ~ PUMP STAGES TYPE ~C-650 ~SG. NO. [~ NO. ~CS. [ [ 230 SERIES ~00 MODEL ~ L~NGTH [9.2 ~ 582 PUMP OSCHRG. SERIES MODEL LENGTH CONN [ ~30 SEAL SECTION SERIES 513 uOOEL GSS- ]- LENGTH 6.3 ~ 203 POWER CA~LE AWG TYPE ;,ENGT,-~ A~MOR J FLAT CABLE FLAT GUARDS CABLE BANOS CABLE BANDS SWAGED NIPPLE Adaptor 400 x 513 CHECK VALVE DRAIN VALVE EQUIPMENT COAT;NC: MOTOR CONTROLLF-R ACCESSORIES INCLUDE: . TYPE ~.ENGTH MODEL SiZE VOLTAGE OVERLOAD ~ UNDERCURRENT SD.." RECORDING AMMETER AUTO RESTART '- LIGHTINGARREST~R - OTHER 200 ~VA ItS TYPE SECONDARY TAPS VARIABLE FREQUI[NCY CONTROLLER: TRANSFORMERS SIZE 200 5 KV PRIMARY TAPS VARIABLE FREQUENCY TRANSFORMER JUNCTION BOX (VENTED-SAFETY) TUBING HEAD PMD Inductor Packaze · , CONOCO Mods CABLE GUIDE Discount CAgLE REEL NO. REELSUPPORT ' SHIPPING CASE QTY. SIZE "-HIPPING CA,.~E QTY. SIZE SHIPPING CASE QTY. .~IZE SHiPPiNG CASE QTY. SIZE EQUIPMENT MAY BE RETI.jRN~O FOR :00% CREDIT WITHIN 6 MO SUBJECT TO A R~PA~R JAL TO 25% OF THE LIS'[ PRICE. ........ CO'HOCo V$C System Performance MILNE POINT L-I I'[ §000 7000 6000 5000 4O00 3000 2000 1000 I00 200 :300 400 500 600 700 800 900 I000 I I00 1200 1:300 BPI) ~,,..,o~,,.-.~,,,~,"' ,,,,.,,...,..,...,,,,,: I ,,~,..,,o,.,,.o !1 ,,,,:.,,,z,,,,,:~,,,,.,.,,,,,:,,,,~, i .,.,,,. I_ ',,,,..,.,,.,,. ,~o ~e '7. 9¥ . . ....... ............ .......................................... aJTi 8',,va ,, B rc 9,.Z ''~ 7"8G. z-,Fo .. co/,-/o~ooo tg. ~ 7 A i(/' ,.,S-:/$c.~ ct..,,, G,,,..s _ F~ o ~ P Co Z L ~ ,- ..7 %? q' . /?~',e, :22' $,~" 1o, ~/' .5',?2" .. · . ?~'~.~ '-4 / ~7,,S"s .6o" ~-" . .~ qo 76, ~o ' . . ,~..OOOO ...................... IL.M ~.IDHMM) ............. .~.O. 5 ~..... 5.1 , ~.OOO0 SF~I~ (OHMM) , I. ' I I ~ J il I · Maoe By - Choc~eo ~v Conoco Inc. Calculation $ beet Title JoD State Interoffice Communication TO: FRO~: /P~ ->~-> CVL [""CYL ~"-'"'-' DATE: October 11, 1990 SUBJECT: MPU L-2, L-l, L-5, L-6 Completion Procedures - Summary of Changes The procedures are basically the same as the L-3 procedure. The frac design has changed slightly. These designs go up to 12 ppg proppant. Also, the gel concentration has been increased from 40 to 50 # loading. I've attached a 40 # L-2 design so that you can see the benefits of going to 50. Apparent viscosity increases from approximately 200 to 300 cp at our temperatures with this revision. I am still working on Proposed and Blank Well Schematics. I'll circulate them Mondayish. If we see anything that calls for an adjustment from well to well as we progress, I'll propose addendums. As of now, our plan is to move EWS to L-5 and then L-6 upon completion of the L-3. Pool will rig up on L-2 and then move to the L-1. The Pool rig is better equipped (rotary table, etc...) to handle the L-1. The Pool rig will then go to H-Pad and EWS will kick off the workovers and possibly knock out G-Pad. Let me assist you should you have questions. Sr. Prod. Engr. EX LOSFv'E ! $c:hlum~erc?er ~~ (~'~C~ {~j Verify that CairnS-to-Ri[ m ~ ~at ~~ I~ man O.~V. ~mi~~P~ (hi Clear line of fire oi all m ~t.~m ~t~ (il At~ CST or ; ~m m ~ ~ o~ he~o~m hole. m d o~ h~o [~ a~ B~ to ¢oli~ I~mr aha for p~ d~ ~n~ L-- ~ ~ p~ ,n hMe. 5. A~m~ SC ~ ~ G~ AT L~ON fa) Clear I,fle of I. HoLd spM safety mNumr. 2. Hold conmdmt2mt w,th client if [] 3. Chock weti arum for hazarc~ &nd OI~2~TXONAL 1. Ho mnokU~ ezcmzt m Dermtm~zie aunld when i~vmg mm~ areal ~ ~o1~ M~Mr. ~ not 4. ~ m at~ ezpiml~ (b) Check c~nmctor v,,rt.s for · ~Xm. me somrsrmf. (c) Fnm ~n~r wl~ (d) ln~n ot~n~ cad ,n ~lMt* inf ~D ~aietv ~f ~u~. (e) ~ ~utml ~D ie~ to ~v ~f ~ and c~D to pn~- ~lMunf ~o C~omg ~lie~. (g) p~ ~ ~or wear t,~ht (h) P~ ,nm ~l. 6. ~mtlO~ ~U~ In Hole fi) At 1~ de~. tu~ on s~ch. sma AC gene~mr. Wo~ ~ln[ corian to (C) Come out of holM(OD at &~vm kev to ng floor otxmtor. 100' ann r~l~at ~afetv r~- (b) Shut o~ AC gene~mr, lat~ C-4 la tm~ln (c) Turn off main circuit ~ D CO~ON OF lOB (e) D~ GNP ~ ~ b~nt to t~e ~*0 ,I i~a~ on ~ ~M n~ ~ for t~ to ~ ~tu~ ~ Dtitn~. ~W o~m~ ~ P~i~ tree area (or orz~cora (0~ o~ ~ ~m ~ ~n~. char[., trun. CONF~D~'FrZAL PREVENTATIVE MAINTENANCE FREQUENCY CODES M1 M2 0 W Y1 Y2 MONTHLY BI -MONTHLY QUARTERLY WEEKLY ANNUALLY SEM!-ANNUALLY PM FILE COLORS BLUE GREEN ORANGE RED YELLOW MONTHLY BT-MONTHLY OUARTERLY NEEKLY ANNUALLY SEMT-ANNUALLY · ~ ~ STATE OF ALASKA ~ .... ~ A!' KA OIL AND GAS CONSERVATION C .MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend E1 Operation Shutdown E3 Re-enter suspended well [] Alter casing [] Time extension [] Change approved program E3 Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator CONOCO, I~NC. 5. Datum elevation (DF or KB) 56 ' KB feet 3. Address 6. Unit or Property name Pouch 340045, Prudhoe Bay,-Alaska 99734 Milne Point Unit 4. Location of well at surface 158' ~4L, 1970' Iq~L, Sec. 8, T13N, R10E, U.M. At top of productive interval 102' FW-L, 2258' ~-~P-, Sec. 8, T13N, R10E, U.M. At effective depth 64' FWL, 2303' FNL, Sec 8, T13N, R10E, U.M. At total depth 307' FEL~-2394' FNL, Sec. 7, T13N, R10E, U.M. 7. Well number L-1 8. Permit number 84-5 9. APl number 50-- 029-21068 10. Pool Kuparuk River 11. Present well condition summary Total depth: measured true vertical 9500' RKB feet 9421 ' feet Plugs (measured)7" Float Collar @ 7434' I~B Effective depth: Cas'..Lng Structural Conductor measured 7390 ' ~ feet true vertical 7355' feet Length _ Size + 95' 13-3/8" Junk (measured) Halliburton Model "N" Bridge Plug @ 7390' RKB Cemented Measured depth True Vertical depth Cmt. to Surface ± 130' ~IKB ± 130' Surface Intermediate Production 2448' 9-5/8" 7488' 7" 1750 Sks. 2483' RKB 2483' 1450 Sks. 7523' RKB 7486' Liner 7068' to 7128' RKB Perforation depth: measured 7160' to 7180' RKB 7186' to 7214' RKB true vertical7040' to 7098' 7129' to 7149' to 71 82' Tubing (size, grade and measure~ ~e~h) 3-1/2", 9.2 lb/ft, L-80, 7043' RKB Packers qpd S~SV(type and measured depth) Baker "SAB" Hydraulic Permanent Pkr. @ 6970' RKB. RECEIVED ' S P (.':: / Alaska Oil & Gas Cons. Commis Camco TRDP-1A SCSSV @ 2~0r~ 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] Not Applicable 13. Estimated date for commencing operation _ Date approved 14. if proposal was verbally approved Approved by Name of approver Not Applicable 15. I hereb~ .c,e~tify~t t~ing is true and correct to the best of my knowledge Signed D. F. RAINWATER Title SENIOR FOREMAN Date 8/3/87 Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test IT-i Location clearance~ ,,,~:~-;..;..-.:~ ~ ~._~,..*~ ~ "~' ~':' ff '='~ ~ -~ ~ Commissioner ;i01i by order of Date ~'~- ~'~- ~ the commission Sub'nit in triplid._at~,~ Form 10-403 Rev 12-1-85 c , oco) AuguSt 31, 1987 Conoco inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 Mr. Russ Douglas Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Douglas RE: Suspension Applications for Milne Point Wells L-l, M-iA and N-lB Conoco requests a suspended status for the Milne Point Unit L-l, M-iA, and N-lB wells. Attached are 10-403 forms for these wells. A suspended status is necessary because production of these wells await design, delivery, and construction of production facilities. Conoco requests an exception to 20 AAC 25.110.(c) which states that the operator shall set a bridge plug between 200 and 300 feet below the casing head and cap with 100 linear feet of cement. The exception is requested due to anticipated development and production of these wells. The following information concerning each well further supports our exemption request. Milne Point Unit L-1 L-1 contains a PXN'plug at 7012 feet, a SSSV at 2019 feet, a Packer at 6970 feet and a back pressure valve in the tree. Milne Point Unit M-lA M-lA contains a PXN plug at 9700 feet, a SSSV at 1908 feet, a Packer at 9663 feet, and a back pressure valve in the tree. Milne Point Unit N-lB N-lB contains a PXN plug at 3294 feet, a SSSV at 2009 feet, a Packer at 3258 feet, and a back pressure valve in the tree. Conoco believes that the wells as they are constructed provide adequate protection to ensure that hydrocarbons and freshwater are confined to their respective strata. Mr. Russ Douglas August 31, 1987 Page 2 Please contact Doug Frey or Jim Dosch at 659-6336 if you should have any questions. Yours very truly, D. F. Rainwater/E. L. Robinson DFR/JTD/pck File 4.25 - 1569/WP22 cc: w/attachments Field Superintendent - Anchorage Production Technician - MPOC P. J. Grimmer - Anchorage Safety & Compliance Coordinator - MPOC Signe >/~~~'*'i/'~. - . . tleManager of Alaskan Operations The spa~e below for Commission/se Conditions of APproval, if any: Approved Form 10-403 BT LOH iE. r,. S ]ITIt Approved Co97 Returned By Order of COMMISSIONER the Commission Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~[;~ OTHER [] 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 200, Anchorage, Alaska 99503 4, Location of Well 158' FWL, 1970' FNL, Section 8, T13N, 5. Elevation in feet (indicate KB, DF, etc.) 56' KB 12. R10E, U.M. 7. Permit No. 84-5 8. APl Number 5o- 029-21068 9, Unit or Lease Name Milne Point 10, Well Number Milne Point 1 1. Field and Pool Unit L-1 Kuparuk River 6. Lease DesignatieWand Serial No, ADL 25509 Check Appropriate~ox To~ndicate ~atureofNotice, Report,~r'OtherData NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) {Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing []' (Note: Report multiple completions on Form 10-407 with a submil~ted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearlv state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year as long'as the status of the well is suspended. This well will remain suspended pending eng±meeCi~g evaluation of.development of the western portion of the Milne Point Unit.. Alaska 0il & Gas Coos. commission Anch0rag~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. S ignea,,-~~~'~,~_,,~,--L~ ~r~ .~~TideManager of Alaskan Operations The spacVe below fo'r C-omr~ission i~se ~' Conditions of Approval, if any: Approved by J~J Llltlll[, I~. Sall~ COMMISSIONER Approvect Col~y Returned By Order of the Commission Date !O -'7,~5 Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate MEMORANOUM Statb of Alaska TO: THRU: Lonnie C. Smith -"! ' ' Commissioner ~-~ FROM: Bobby D. Foster'<¢ '' Petroleum Inspector ALASKA~OiL AND GAS CONSERVATION COmmISSION C. V/ ~t~ton DATE: September 17, 1985 Chai~m~''-'~ / FILE NO: D. BDF. 8 9 TELEPHONE NO: SUBJECT: Location Inspection Conoco, Inc.-MPU-#L-i Permit # 84-5 Kuparuk River Field Thursday, August 29, 1985: i met with Roy Robinson, Conoco Rep- resen~ative ~nd'inSpeCted the following location: Miine Point Unit Well #L-l, Permit No. 84-5 Attached to this report are pictures of the locations and copies of suspended well reports. Attachment 02-00IA(Rev. 10/79) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 Surface n~cJ~i~n-°~'~le~l~ ' - permit ~o._.'~~ ~' Sec.~, T ],~ ~_, R~~, ~M. Unit or Lease Name~/]~ ~ ~.~ Well No. ~] ~ Field & Pool ~~Z~_~g~m _.:. Condition.of Pits Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard Attached to Information correct No Ye s No No - Opened '~ No Rat Hole Open Yes ~ Cel lar Fil led Ye s No Fil led Ye s No Covered Yes No Covered Yes No WaterWell - Plugged off Capped Ope n Explanation Photographs taken to verify above conditions~ No Explanaton Work to be done to be ac.cgptable ',/~O/L,h/"~ ~ ~,}6;~L~__., ~.~L/,/~ .L43¢/~ ~ ,:~,,~ location is ~(unacceptable) This well and suspended f.or the~ o~_ ~.~_ .~ 19~_~thru ~o__~~ Inspected byi_/~~~~-~ ~ ..... ,~.~~ ' Date, ~'~.: ~ - ~ ' ~ to be classified as Revised 8/24/82 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 December 17, 1984 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: This letter is in response to your letter of inquiry (attached) concerning dried cuttings samples that were not submitted to the AOGCC for the fo].lowing Milne Point Unit well: Conoco - Chevron MPU L-1 Section 7, T13N, R10E, U.M. Permit No. 84-05 We regret the oversight and submit the requested samples along with this ].etter. There are five boxes as follows: 1. 2500-5560' 2. 5560-6730' 3. 6730-7720' 4. 7750-8800' 5. 8800-9500' Yours very truly, Mike Bradshaw Operations Supervisor RECEIVED OEC 1 Please acknowledge receipt for our records by signing and returnimg the attached copy of this letter. November 6, 1984 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 Mr. Jim Trimble Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-I, A-2, B-i, B-2, B-3, B-4A, B-5, C-l, C-2, C-3, D-i, L-I, M-lA, N-lB, and Gwydyr Bay State 2A. Ail of the above are classified suspended wells. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the wells are suspended. Please contact Jim Dosch at 279-0611 if you have any questions. Yours very truly,, ~:~::r of Alaskan Operations JTD/ks Attachments RECEIVED NOV 0 91984 Alaska Oil & Gas Cons. Commission Anchorage ~ STATE OF ALASKA -, ALASF OIL AND GAS CONSERVATION )MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ 2. Name of Operator 7. Permit No. Conoco Inc. 84-5 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50- 029-21068 4. Location of Well OTHER [] 158' FWL, 1970' FNL, Section 8, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 56' KB 6. Lease Designation and Serial No. ADL 25509 9. Unit or Lease Name Milne Point Unit 10. Well Number Mil. ne Point L-1 11. Field and Pool Kuparuk River 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the well is suspended. This well will remain suspended pending engineering evaluation of development of the western portion of the Milne Point Unit. 14. I hereby the best of my knowledge. Manager of Alaskan Operations The space " for Commission use ~ Date 9-26-84 By Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA OIL AND ~AS CONSE~?¥ATION.~,OMMISSION / Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALAgKA 096014-3192 TELEPHONE(gOD 279,-1433 RE: We wish to bring to your attention that the Commission has no~'" yet received the following required items on the subject well which our records indicated was completed _ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing material. C. V. Chatteruc~- Chairman lc:C.024 John R. Kemp Manager of Alaskan Operations September 12, 1985 Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-76OO Harold Hedland Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hedland, · Attached are completed 10-403 forms for Milne Point A-3, D-I, N-lB, L-I, M-IA and Gwydyr Bay State #2A. Ail of the above are classified as suspended wells. Conoco will contact ohe of your representatives to conduct an inspection each year as long as the status of the wells is suspended. Please contact Jim Dosch at (907) questions. 564-7649 if you should have any · Very truly yours, John R. Kemp f~ ~.~f Manager of AlaSkan ~perations RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION C. VI ~b~tgrton DATE: August Chai~%~/ MEMORA,,IDUM State of Alaska To: 22, 1984 FILE NO: D. 3I. 52 TELEPHONE NO: THRU: Lonnie C. smith~ Commi s s loner FROM: Bobby Foste Petroleum Inspector SUBJECT: Inspect Suspended Wells and Locations at Conoco Sites. Thur_sday., August 16, 1984.- I traveled this date to Prudhoe Bay and met with Jerry Fritch and Jim Dosch, Conoco representatives, to inspect the suspended drill sites and wells listed below. Gwyder Bay .2A Milne Point N-lB Milne Point M-IA Milne Point L-1 Milne Point Pad A (4 wells) Milne Point Pad C (4 wells) Milne Point Pad B Milne Point Pad D I recommend to the Co~ission that these wells and drill sites be accepted as suspended. PiCtures attached. · · 02-00IA(Rev. 10179) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: Address ~.~~' ~ ~ ~~ /~ ~.~_.. ~~.' ' Surface foc~ti°n Of w fl- sec.~, T~ ~~R/D ~, ~ M. Unit or Lease Name~]~ ~.~ Wel 1 ~o. Conditio~ _ ~ Condition' of Pits ~/~//~ Well head - Ail outlets plugged Wel 1 sign - Attached to well head Attached to well guard Attached to Information correct No Yes No No Cellar - opened Yes No Rat Hole O?~n Fil led Yes No Fil led Covered ~ No Covered WaterWell - Plugged off Capped Open Explanation_ ~//~ Ye s No Ye s No Photographs taken to verify above conditions~ No Explanaton Work to be done to be acceptable This well and location is a~?cc~e~ta~bl~ (un~ac~ceptable) to be suspended for the period of--~-~---~ , l~~thru ~/& Ins~cted by~/~ /~ _~~~ . . classified as 19~_. Revised 8/24/82 SHOT SHDT SUMMARY Llvl'ING PERFDRMED 09-APR-84 - ~. STATUS DEPTH TENSION I FIRED 9353.9 453.5 2 FIRED 9332.1 496.5 3 FIRED 9313.9 391.? 4 EMPTY 9284.0 316.2 5 EMPTY 9244.0 391.2 6 EMPTY 9230.0 249.0 7 EMPTY 8963.1 257.5 8 EMPTY 8961.0 276.2 9 EMPTY 7585.0 409.0 10 FIRED 7210.0 260.2 11' FIRED 7200.0 253.2 12 FIRED 7190.0 219.3 13 EMPTY 7174.0 244.2 14 FIRED 7172.0 281.2 15 FIRED 7125.0 208.5 16 FIRED 7121.0 287.0 17 EMPTY 7104.0 192.? 18 FIRED 7102.0 236.1 19 FIRED 7088.0 178.0 20 FIRED 7083.0 320.0 21 FIRED 7079.0 321.7 22 FIRED 4325.8 360.2 23 FIRED 4314.0 375.7 24 FIRED 4254.9 539.0 25 FIRED 4248.0 230.7 26 FIRED 4236.0 407.7 27 FIRED 4143.0 308.5 28 FIRED 4125.9 381.5 29 FIRED 4109.9 278.~ 30 FIRED 4095.9 629.0 31 FIRED 4056.9 265.7 32 FIRED 3941.9 731.5 33 LDST 3931.9 1630. 34 FIRED 3870.0 210.8 35 LOST 3840.0 1436. 36 FIRED 3821.9 17~.1 37 FIRED 3804.0 277.5 38 FIRED 3744.9 359.7 39 FIRED 3716.0 294.7 40 FIRED 3682.0 177.1 41 FIRED 3672.9 194.~ 42 FIRED 3647.0 172.6 43 FIRED 3641.8 253.6 44 FIRED 3632.9 196.8 45 FIRED 3626.9 202.0 46 FIRED 3602.0 383.7 47 FIRED 3586.0 209.5 48 FIRED 3549.9 180.3 49 FIRED 3528.0 202.2 DEPTH UNITS : FEET DIT SIZE : 8.500 IM RING TYPE : LARG BULLET TYPE : CDMB PDWDER LOAD : 7.00 O POWDER TYPE : AHT COMPANY CONOCO-CHEVRON WELL MILNE POINT l,-I FIELD MIl. NE POIN'[ UNI:t COUNTY NORTH SI_OPE I IIII STATE ---' AI~ASKA SCHL. FR9475 SCHL. TD9475 DRLR. TD9500 Elev.' KB 56 DF 55 GL - STATE OF ALASKA ',~% ~J~.i~b_¢~_.~Y. ALASK~ OIL AND GAS CONSERVATION t MMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Conoco ]:nc. 84-5 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50-029-21068 4. Location of well at surface 9. Unit or Lease Name 158' FWL, 1970' FNL, Section 8; T13N, R10E, U.M. '~'~N Milne Point Unit At Top Producing Interval $ i 10. Well Number 102' FWL, 2258' FNL, SeCtion 8,,T13N, R10E, U.M. I VFRIFIED'sud._j~____:~ L No. 1 At Total Depth ' 11. Field and Pool 307' FEL, 2394' FNL, Section 7, T13N, R10E, U.M. JB.H._E__~_. Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB = 56'I ADL 25509 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 3/20/84 4/7/84 4/27/84I N/A feet MStI One 17. Total Depth (MD+TVD) :18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9500'MD(9421'TVD) 7434'MD (7398'TV[,)CESEX NOBI 2019.5 feetMD +1800 22. Type Electric or Other Logs Run DIL-SFL, BHC Sonic, FDC-CNL, NGT, HUT 23. CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3/8" 72 L-80 Surface +130' 17½" 9 5/8" 47 L-80 Surface 2483' 12~" So_o_ Attar_hmo_nt 7" 29 L-80 BTRS Surface 7523' 8~" No. IV -- 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3½", 9.2#/Ft L-80 7043' 6970' 7068' to 7128' MD (7040' to 7098' TVD) 7160' to 7180' MD (7129' to 7149' TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7186' to 7214' MD (7155' "co 7182' TVD) DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED · 6earhart 5" Scalloped Hollow Ca~-rier w/ See Attachment ~lo ]:V F:), ~. ,_, 12 JSPF. EHD : 0.63" =~. PRODUCT,ON T.ST AUG i 0 Date First Production ] Method of Operation (Flowing, gas lift, etc.) See Formation TestsI Alaska 0il & Gas Cons. Commission Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE' TEST PERIOD I~ 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. Core No.. i - 7166' to 7226', Recovered 55.6' (93%); the top 37' is predominately sandstone with an occasional-shale stringer and one 10' section of interlaminated sandstone and shale. the bottom 19' is interlaminated sandstone/siltstone and shale; the sandstone is fine grainl~ with dark oil staining, and fair to good visible porosity. Core No. 2 - 8964' to 9024', Recovered 58.8' (98%); the top 53' is sandstone with occasional Shale laminae; the bottom 6' is silty shale with no visible porosity or oil staining; the sandstone is v.f. grained, firm, with poor visual porosity, occasional fractures, and no ioil staining. d, Form 10-407 Submit in duplica;e Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME 29'. CONFIDENTIAL '!~- '?ORMATION Furnished By ~,~ .~:oco Inc, GEOLOGIC MARKERS Jpper Cretaceous MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS iKuparuk 6ag Ri ver -~hubl i k ~adlerochit Top NA OA OB LZ LK1 LK2 3527' 3797' 4054' 4224' 4312" 7068' 7160' 7186' 8958' 9022' 9126' 3527' 3796' 4053' 4223' 4311' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 7040' 7129' 7155' 8890.5' 8953' 9054' See Attachment No. III 31. LIST OF ATTACHMENTS .~- Directional Survey, II' Well History, III- Formation Test Re~ults~ IV' Cementing details 32. I hereby certify that the foregoing is true and correct to the best of my knowledge V' As-Bui 1 t Survey Signed ~, ~~¢:~ Title Manager-Eng. Date 7--~-'~ 7~<,~c' 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". Corm ', 0-407 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 August 10, 1984 Mr. H. W. Kugler Commissioner of Alaska Oil & Gas Conservation Commission 3001 Procupine Drive Anchorage, AK 99501 Dear Commissioner Kugler' Enclosed please find the "Well Completion Report and Log" (in duplicate) for Milne Point Unit Nos. N-l, N-lA, N-lB, M-l, M-lA, and L-1 as required by AOGCC Regulations. " ~ ... We regret the delays in getting this data to you. If you have any questions, please call me at 279-0611. Y~urs very truly, James B. Fox Engineering Technician tt cc: R. J. Francis Encl. RECE VE ) AUG 1 O A~aska Oil & Gas ConS. Commission Anchorage Interval Tested: Date of Test: Method of Operation: Hours Flow Tested: Wellhead Flowing TBG.. Pressure (PSIG): Gauge Depth (MDKB): Oil Produced (BBLS): Gas Produced (MSCF): Formation Water Produced (BBLS): GOR (MCF/~BL): Choke Size: ATTACHMENT NO. III MILNE POINT UNIT L NO. 1 FORMATION TEST RESULTS DST No. 1 DST No. 2 DST'No, 3 DST No. 4 7186'-7214' 7160'-7180' 7186'-7214' 4/14-15/84 DST -Flow 4/17/84 DST - Flow 10.5 12 0-74 5 to 220 7107' 7108' 7068'-7128' 4/20-21/84 DST - Flow 12 46 6962' 7068'-7128' 7160'-7180' 7186'-7214' 4/24-25/84 DST - Flow 25.7 30 7001' 84 217 298 260 NA 1120 1680 1800 NIL NIL NIL NIL NA 0. 228 26/64" to 2 x i" 1 32/64" 0,255 0.340 32/64" to 2" 2" Flowing Bottomhole Pressure * (PSIA): 2452 2030 2022 1960 Final Build-up Pressure * (PSIA): 3451 3443 3363 3394 Average Rates: BOPD 128 470 550 406 MSCFPD NA 107 140 138 BWPD NIL NIL NIL NIL Oil Gravity: 20.9° 21.7° 22.3° 21.2° · As recorded at gauge depth CONFIDENTIAL INFORMATION Furnished By Conoco Inc. RECEIVED AUG 1 019~ Alaska Oil & Gas Cons. Commission 4nchorage ATTACHMENT NO. IV MILNE POINT UNIT L NO. 1 PCimary Cemeqt 13 3/8" CSG: Cemented to surface 9 5/8" CSG: Cemented with 1000 sks. Coldset III cement followed by 750 sks. of Coldset II cement. 7" CSG: First stage - 750 sks. Class "G" w/l% D-31, 0.2% R-5, 0.2% D-6, and 5% KCL BWOW. Second stage - Open D.V. tool @ 4348' and pump 600 sks. of Class "G" w/2% CaC19, 1% D-31, and 0.2% D-6. Third stage - Downsqueeze 100 sks. of Coldset I followed by 50 BBLS. Arctic Pack. ACIDIZING DETAILS Interval Acidized: 7068' to 7128' 7160' to 7180' 7186' to 7214' Procedure: Squeeze away 62 BBLS diesel fuel followed by 1500 Gals. 7.5% HCL w/200 SCF/BBL Nitrogen 3000 Gals. 12% HCL and 3% HF and 1200 Gals. 7.5% HCI Allow to soak for three hours and flow back for DST No. 4 CONFIDENTIAL INFORMATION Furnished By Conoco Ine,. RECEIVED ' AUG 1 0 19B~ Alaska Oil & Gas Cons, Commission Anchorage WELL HISTORY MILNE POINT UNIT L NO. 1 ATTACHMENT II CONFIDENTIAL INFORMATION Furnished By Conoco In(~. 3-19 Mud complex, power complex, substructure in place, derrick raised. 3-20 R/U floor & misc. equip· N/U diverter. Mix spud mud. Caliper & M/U BHA. 3-21 M/U Kelly & BHA. Test surface lines to 4000 psi & diverter to 200 psi. Spud @ 0730 hrs. on 3-20-84. Drlg. f/95' to 1221' Pump pill & POOH. Change bits & TIH w/bit #2, no fill. Drlg. ~/1221' to 2500'. Circ. & cond. for logs. Make wiper trip. 3-22 Make wiper trip, no fill. Circ. S.L.M. POOH. Driller's T.D. - 2500. R/U Schlumberger & run DIL-SFL-BHC-GR f/2500' to 105'. R/D Schlumberger. L/D 8" collars & stabilizers. R/U casers & run 62 jts. 9-5/8" 47# L-80 csg. to 2483'. Circ. csg. Cmt. csg. w/1000 sx. Coldset III followed by 750 sx. Coldset II. Good cmt. returns, bumped plug w/2000 psi, floats held o.k. N/D divert,r, hang csg, cut off csg. Finish N/D diverter. Make final cut on csg. N/U csg. spool. 3-23 N/U csg. spool. N/U BOP stack. Hook-up choke line, change top rams to 5". Test BOP stack to 500 psi & 5000 psi. Test annular preventer to 350 and 3500 psi. Choke line ruptured while testing. Remove choke line. Pull test plug & set wear bushing. R/U & test Kelly. Change out lower Kelly valve. P/U & strap BHA. TIH w/HWDP. Install & test choke hose & manifold to 5000 psi. Thaw out pump discharge line. 3-24 Thaw out standpipe & repair kill line valve. TIH w/D.P. & break circ. Press. test csg. to 1500 psi 15 min., o.k. Drill out float collar, cmt. & float shoe & hole to 2510' Circ., P/U into csg. & perform leakoff test. Drill & survey 2516'-3980'. Survey: 2933' 1~° S33.5E, 3436' 3° S52.0E, 3691' 2¼° S50.5E. 3-25 Drill to 4050'. Level rig. Drill & survey 4050'-4963'. Survey: 4073' 2° S44.5E, 4549' 3° S49.5E, 4741' 2¼° S49.5E. 3-26 Dri].l & wireline survey 4963'-6008'. Install new Kelly valve. Test Kelly & safety valve to 5000 psi, pump pill. POOH w/D.P., still tripping @ report time. Survey: 5251' 2¼° S43.5E, 5761' 3° S5.5W, 5954' 3° S9.5W. 3-27 AUG 1 0 1984 Finish POOH; P/U Navi-drill, 1%° bent sub & Teleco, orient tools. Straighten BOP stack. Test Teleco'& Navidrill & TIH to csg. shoe. Slip & cut drlg line TIH to 5918' wash & ream to 6008' · · , · Navi-drill & Teleco survey 6008'-6492'. Survey s: Depth Angle Direction 6096' 5.3° S15.4W 6192' 7.6° S34.8W 6286' 10.6° S41.8W 6382' 13.3° S38.3W 6444' 14.9° S36.5W Alaska Oil & Gas Cons. Anchorage 3-28 CONFIDENTIAL iNFORI , rlON Furnished By Cono=o Inc. Survey & POOH. L/D Navi-drill. M/U bit & BHA. TIH to 6008'. Wash & ream f/6008'-6497'. Drill & Teleco survey f/6497'-6857'. Survey & POOH, L/D string RWP. TIH to shoe. Slip & cut drlg. line. TIH, no fill. Drill f/6857'-6915'. Surveys: Depth Angle Direction 6515' 16.2° S39.0W 6642' 15.5° S38.3W 6801' 14.2° S38.3W 3-29 Drill & Teleco survey 6915'-7166'. Circ. bottoms up. Drop single shot survey & pump pill. POOH, retrieve survey & L/D jars. L/D Teleco, P/U & service core barrel. TIH. Wash & ream 60' to bottom & space out. Coring f/7166'-7226'. Pump pill & POOH. L/D core, Surveys: Depth Angle Direction 6990' 13.1° S39.0W 7124' 12.2° S39.7W 3-30 Service core barrel. Core rec. 55.6' (93%). M/U BHA & TIH to 7166', break circ. Wash through core run 7166'-7226', 3' fill. Drill & Teleco survey 7226'-7416'. Survey, angle still dropping, pump pill. POOH & change BHA. Remove wear bushing, install test plug. Test BOP & TIH. Wash to bottom 7350'-7416', bridges @ 7085' & 7385'. Drill & Teleco survey 7416'-7615'. Surveys: Depth Angle Direction 7215'. 11.9° S40.8W 7278' 11.8° S41.5W 7374' 11.4° S43.2W 7469' 11.6° S45.0W 7564' 11.8° S46.4W 3-31 Drill & Teleco survey 7615'-7753'. Drop single shot survey & pump pill. POOH, tight @ 7385'. Retrieve survey & change bit. TIH to csg. shoe. Cut & slip drlg. line. TIH, wash & ream 38' to bottom. Drill & Teleco survey 7753'-7940'. Surveys: Depth Angle Direction 7660~ 11.0° S47.1W 7720' 10.5° S49.2W 7819' 9.1° S52.4W 4-1 Drill & Teleco survey 7940'-7998'. POOH (tight spot @ 7340') & P/U Navi-drill. TIH, no fill.. Navi-drill & Teleco survey 7998'-8124'. Drop single shot survey & POOH. Surveys: Depth Angle Direction 8000' 7.8° S62.5W 4-2 Finish POOH, retrieve survey & L/D Navi-drill. M/U BHA & TIH to 7998'. Wash & ream thru Navi-drill run 7998'-8124'. Drill & Teleco survey 8124'-8388'. POOH. Change bit & BHA. TIH to csg. shoe, slip & cut drlg. line. Surveys: Depth Angle Direction 8137' 12.7° S65.7W 8233' 13.4° S68.2W 8328' 13.7° S75.2W 4-3 CONFIDENTIAL INFORMATION Furnished By Conoco Inc, TIH, fill pipe & break circ. Wash & ream to bottom 6' hard fill. Drill & Teleco survey 8388'-8562'. Drop single shot survey, pump pill & POOH. L/D Teleco tool & change bit. TIH, bridge @ 7293'. Wash & ream to bottom, 8' fill. Drill 8562'-8650'. Surveys: Depth Angle Direction 8420' 13.8° S77.7W 8504' 13.2° S79.1W 4-4 Drill f/8650'-8964'. Circ. samples up for Geologist. Drop single shot survey. POOH & retrieve survey. P/U core bit, 60' core bbl. Start TIH. Surveys: Dept~ Angle Direction 8903' 12.7° S83.5W 4-5 Continue TIH. Break circ. Work through bridge @ 8463' & 8748', 12' fill. Circ. hole & increase mud weight to 10.8. Drop ball & core f/8963'-9024'. POOH. Tight spots @ 7478'-6906' & 6810'. L/D core & core barrel. M/U BHA & TIH to csg. shoe. Slip & cut drlg. line. Continue TIH. 4-6 Finish TIH w/bit #12, no bridges, 3' fill. Drill f/9024' to 9209'. Drop survey, POOH. Tight spot @ 6911'. 4-7 POOH, test BOPE to 500 psi & 5000 psi, annular preventer to 500 & 3500. TIH, wash through bridges @ 9134' & 9170', 3' fill. Drill f/9209' to 9374'. Drop survey & POOH. Tight @ 81J8', 6974', 6904' & 6784'. TIH w/bit #14. Survey: 9305', 11-3/4 , N76~W. 4-8 Spot wash f/9326'-9374'. Drill f/9374'-9500'. Circ. bottoms up. POOH, tight @ 8373' & 6975'. TIH to 9304'. Spot wash f/9304'- 9500', 2' fill. Circ. & cond. hole, pump high visc. sweep. Drop survey, POOH for logs. 4-9 POOH, SLM, no change. R/U Schlumberger & log. Run DIL-SFL w/GR & SP, FDC-CNL-NGT, dipmeter. L/D dipmeter & prepare to run velocity survey. 4-10 R/U & run velocity survey & sidewall core guns, rec. 39 of 49 shots. R/D Schlumberger. TIH to csg. shoe. Cut & slip drlg. line. Continue TIH, break circulation @ csg. shoe, 6000' & 9000'. Wash & ream f/9476' to 9500'. Circ. & cond. mud. Short trip 30 stds. Wash & ream 26' to bottom & circ. Drop multi-shot & POOH. 4-11 POH, retrieve multi-shot survey. Lay down monels & stabilizers. Lay down HWDP. RIH open-ended w/drill pipe to 8934. Circulate. Plug back w/225 sks. "G" w/.25% D-31, .5% R-5, .2% D-6 8934 to calculated top of 8684. Pull 10 stands. Circulate and condition mud and hole to run casing. POH laying down drill pipe. 4-12 Lay down drill pipe, break kelly, pull wear bushing, change pipe rams. Rig up casers and run 7" 29# L-80 casing, lost returns at 4342, circulate (3~ hours) at 4342, 6036, and 7540. Pump 20 bbl 12.5 ppg mud flush, test lines to 3000 psi, mix and pump 750 sx "G" w/l% D-31, .2% R-5, .2% D-6, 5% KCL BWOW, lost partial returns CONFIDENTIAL INFORMAT,,,,N Furnished By Conoco 4-12 136 bbls into displacement - regained full returns 160 bbls into displacement - lost a total of 20 bbl, pipe stuck @ 7523 while reciprocating. Drop bomb, open D.V. tool, circulate. Cement 2nd stage w/600 sx "G" w/2% CaC1, 1% D-31, 2% D-6. Lost complete returns 135 bbl into displacement - lost 22 bbl total, close D.V. Nipple down and lift BOP stack, hang casing w/160,000#. Down- squeeze 200 bbl H20, 100 sx, Coldset I, 50 bbl Arctic pack. Nipple down. 4-13 Nipple up BOP stack, change pipe rams. Change kellys. Test BOPE. RIH picking up BHA and tubing. Test casing to 3000 psi - ok. Drill out D.V. Circulate and test casing to 3000 psi. 4-14 Finish testing csg. after drill O.V. to 3000 psi, o.k. P/U tbg. & TIH to 7450, tagged cmt. Circ. & cond. mud to even 10.5 ppg. & POOH. R/U Gearhart & Eastman & run gyro survey. R/D Gearhart & Eastman. P/U assembly for DST #1 & TIH. Fill pipe w/1000' of diesel (8 bbl.). R/U Gearhart & run gamma ray correlation log. R/D Gearhart, space out tbg. 4-15 R/U & test testing tree & manifold to 1000 psi. Drop bar & perforate f/7186'-7214 w/12 spf Vann guns. 20 min. initial flow period, 60-min. initial shut-in period, final flow period - 11~ hrs. 4-16 Final shut-in period 23 hrs. total. Reverse out. Total produced fluids - 85 bbls. Average rate - 156 BPD. Cut - 98.4% oil, 1.6% B.S., gravity - 21.2 @ 65°F. R/D test tree & manifold. POOH, redress test tools & TIH f/DST #2. Filled pipe w/1000' diesel cushion. 4-17 TIH for DST #2. R/U Gearhart & run CCL-GR correlation log. R/U & test surface equip. Dropped bar, no indication @ surface that guns detonated. Wait on wireline truck. R/U Otis & TIH w/1.91 overshot to locate detonating bars. Reached 6913' inside 4-3/4" d.c. & could not pass through. POOH w/1.91 overshot. Attempt to rev. out w/LOC closed bypass, would not function. TIH w/detonating bar retrieving tool & retrieve bar. Tattletale on detonating bar not marked by firing pin. Rev. out; circ. & condition mud. POOH. Change out & service test tools. Found a pin at of unknown origin lodged crossways a few inches above firing pin. 4-18 W.O. new tbg. release, finish M/U test assembly & TIH. Set pkr. & R/U test tree & manifold. Open LPR valve, drop bars & perforate. DST #2 20 min. I.F.P., 60 min. ISIP, 10~ hrs. FFP, 6 hrs. into FSIP. Stabilized flow rate - 480 bpd, GOR - 201.6. Grind out: 99% oil, trace water & BS. 4-19 FSIP (21 hrs. total). TIH w/Schlumberger w/downhole sampler. H.P. gauge failed, POOH. Change out tools & TIH again. Catch 2 samples. Omitted on 4-18 report: Gravity - 22.2 @ 60°, total fluid produced - 220 bbls. 4-20 CONFIDENTIAL iNFORMATI ,,N Furnished By R/D Schlumberger. Open circ. valve, rev. out tbg. Release pkr. POOH. L/D DST tools. GeoVann guns left in hole. 5" Acme thread backed out of top of guns, left in hole 22.31' - 5" O.D. P/U Howco model "N" bridge plug. TIH, set @ 7150'. Test plug to 1500 psi, 15 min. POOH, install test plug, test BOPE. Cut & slip drlg. line. P/U Van guns & DST tools for DST #3. TIH w/1000' tbg., fill tbg. w/diesel. 4-21 Finish fill 1000' of tbg. w/diesel. Continue TIH w/tbg. R/U Schlumberger. Run gamma ray & CCL for correlation. R/D Schlumberger. Space out, set pkr. Pressure test annulus to 1500 psi, open LPR valve. Drop bar, detonate guns & perf. f/7068'- 7128' 12 jspf 5" guns. 20 min. initial flow period. 1 hr. initial shut-in period, 12-hr. flow period. Stabilized flow rate = 528-552 BOPD/meter reading last 6 hrs. GOR = 245. Grindout = Emulsion-.4%, o±1-98.6%, water-l.%, Gravity 22.7 @ 60°. Total fluid recovered/Tank measurement - 257.4 bbls. Closed LPR valve for 24-hr. final shut-in. PSI @ Sep. = 40, psi @ floor = 125. 4-22 Finish final shut-in for BHP buildup. 24 hrs. total shut-in time. R/U Schlumberger. Open LPR valve. 923 psi @ surface after opening valve. TIH w/Gradio-H.P, gauge & temp. gauge for sample #1. 4-23 Take bottomhole sample #1 & POOH. Change out sample catchers. TIH & take bottomhole sample #2 & POOH. R/D Schlumberger. Shear-out APR "A" circ., sub & 2900 psi. Circ. out oil in tbg. Circ. & cond. mud. R/D Howco test tree & manifold. Release pkr. & POOH. L/D Howco DST tools, Sperry Sun recorders & GeoVann guns. TIH w/Howco pkr. plucker & tbg. P/U Kelly, circ. out sand & latch onto bridge plug. Release bridge plug & pull out of hole 25' (5,000# drag over string weight). Bridge plug hung-up @ 7129'. Pulled 40,000# overstring weight. Release from bridge plug. Set back down & latch onto bridge plug. Circ. high visc. pill. Recover several pieces of packing elements. Work bridge plug, still would not release. Release pkr. plucker from bridge plug. POOH & P/U bumper subs, 6 4-3/4" D.C. 4-24 TIH w/tbg. Jar down on bridge plug; bridge plug moved down 10'; tried coming up w/bridge plug. 40,000# overstring weight would not move. Push bridge plug to 9390'. Release from bridge plug. POOH. L/D bumper subs & 4-3/4" D.C. P/U & tally 6 jts. 3~" tail joints, pkr; TIH. Set top of pkr. @ 7001'. End of tailpipe @ 7204'. Test annulus to 500 psi; install test tree & manifold. R/U Dowell, test surface lines to 4000 psi. Open bypass, spot acid to perfs, close bypass. Pump acid into perfs. 1500 gal 7.5% HC1, 3000 gal 12% HC1 - 3% HF, 1200 gal 7.5% HC1, 200 SCF nitrogen/bbl acid. Displaced w/62 bbls. diesel. Beginning pressure 2300 psi ~ bpm, final pressure 3,000 psi 2 bpm 10 min. SI 2550 psi. Shut-in well 1190 psi after 1 hr. R/D Dowell. Open well for DST #4, flow back 30 bbls., 8 psi full open choke. 4-25 CONFIDENTIAL INFOP A Furnl ed By Cono Contine flow test of DST #4 w/LK1, LK & lam. zones comingled. Turn into separator @ 1800 hrs. TI~w/Otis H.P. gauge, gauge in place at 2230 hrs. Depth 6990', BHP 2014 psi, Temp 177.6°F. Final flowing BHP @ 0500 - 1984 psi. Stabilized flow rate = 337 BPD average; GOR = 326; grindout = 97.4% oil, 1% water, 1.6% emulsion; gravity = 21.2 @ 60°. Total fluid produced = 350 bbls. Shut-in for BHP buildup. 4-26 Continue BHP buildup. Monitoring pressure with H.P. gauge. 3387 psi @ report time. 4-27 Continue monitoring BHP pressure buildup. Shut down @ 0700 hrs. Final pressure 3394 psi. POOH w/H.P, gauge & R/D Otis. Open bypass on pkr. Rev. out oil in tbg. POOH, L/D pkr. & tail jts. TIH w/156 stds. 3~" tbg. ?/U SSSV, R/U control line & test. TIH w/66 jts, 3~" tbg. P/U hanger & land tbg. N/D BOP's. Install tree & test. Circ. out 10.2# drilling mud w/diesel. 4-28 Continue reversing out mud w/diesel. Total volume 240 bbls. R/U Otis while displacing w/diesel. Drop "PX" prong & TIH w/slick- line. Chase prong to "XN" nipple. Jar prong into PXN plug & POOH. Pressure test tbg. to 2500 psi, set Baker "SAB" pkr. @ 6980', test annulus to 1500 psi pkr. holding. R/D Otis. Close TRDP valve & install Cameron 3~" BPV. ~Clean mud pits. " i : ~ ~i ~ ATTACHMENT NO. I I'I]:L. NE F'~'. UNIT., t.,JEI_L. NO: L-...1 '.Z;IE;N~-~5;YFd3 ,JOB NO= ~o, OZl.:34Z02~i~4 ., I IU R" '.5; L_O x '- 'H F'E -.~z :', - 'i..--' ~q '" ¥ - I~Pl'.3, '7.UlZ~ .... ?z~.21 I'tD, SURVEY BY SF'ERRY SUN, DATE RUN: ].O.....AI:'R-:]~:4 ::::; I ':~I¥1F] ':'.(")('> N.O~ ~:-'2'7 ... F.'F'.OI:~',E .NE!' ............. ~ - .......... ~ ~ ~.. ~..~ ........................................................................................................................................................................................................................................................... F:OI::~E'E;Ii::;I'-IT: N7'7 041E CONFIDENTIAL INFORMATION ............................................................................................................................................................................................................................................................ Furnished By ~no ,c~... Inc., /- ,- ,.: '.:'r'H nL. OONFIDE I INFORMATION ~ t~ ~I < ' CIF'IZ ...... Furnished By Inc. . IvlE'i~:tlF,'EED ~;~F'{II::T DRIFT C:CII.IFCE;E VERTIE:AL VER'T;[Cf.~L '.~;L.IE*:'.~;E~F{ E C T r.~ N DEF'TI..I ¢tlqGLE I)I RI]CT I ON LENOTH DEPTH SEC"I' ........ I ON TVD E: r"l ~"'~ R D :1: I,,I ~ "F E S D I ST(:,~IqCIE D I REEE:'I' ]: r"~l',l. ........ ::::: I::: w I:::: R: _ ]'. T' .,::.""5(:)(') ........ ......... (') :::7 :=_; :]-.'::::: 1"-". I:E.lOC) , 24'.--.*'.--.,' , ':"/':' 0 ':::'/',:: ..... 2/4.4.'.-;' '.:'.;:F: :2:,, 1'-"" F.; 1 , /_-,2 E '":'.,-. ,, 72..: '.3 :":':/", .,::....,'-':" E (-). ,, :;.':7 ___-.,' &(.) !J ............. L ......... ~. :"':; :'::"-'" _I, ::L E :t(')("),.. '.':"~'":'--,' '?7 0 :":':0 254-?, ';;'7 :2: '-'"'-' S '":' :""='- 4.. :_:.:7 'l 0 ,.., ._,.:, E :2::I. ::; /4. E /4.'? :270('), 1 0,_,c' :--:2 1:-.: E 2 :---: 00 1 :~,: S 4 .~ "".":' ~ 7-!.-'::--' ..... . .-,:, E :i.O(") :277.~'~ '.-.-~/4- :L ~'~ ,?Zl. /-, :2/-,S ,.~ /~':' E -7 :.:.::2 ::."j; :3/-, 47 I: ,:".,~ 1-.7 . u _ ~ '-- ii -- u .- · ~:,,.-~c) C) 1 ':2 '_:',_~- '=' zl.'*-~ *E__ 1 (')(') ~ ';' '=''--~'~ , .-¢.,'2 _:L~/" .~ 2 :*-': 4-';~ ¢~ '.-" 7 /-('~ '::; /-, ('):~': E '-7.,, 7 o :; 9,:._-.: 2 ~ E ~"~ ]./.'.:. ..... ~ ~ .~.~ ............... _~ ~.. ~._. ~,.,~ ...... ~ .....: ....... ~,. ',I,::,RTH '.i!:;L",F'E:', ..... nLnSl.:::n { NFIDI NTIAL INFO I A i i4 `1. o: ::r:f.~ Fu~nJshe By,,Oon~, .Inc · I"'IEA'.~]~;I...IRE:[) [)I::~IFrT I]RIFT CCII,..IFCE;E VERTICAL VERTICAL. '.E;I..IB'.~;EA I::~ E C "[' A N G U L. DEPTH ANGI...E DIF:~EETION I_.ENGTH DEPTH SECTION TVE C (] 0 R D I N A T E S DISTANCE DIRE:':"I"I:'N SEVERi-I' ........ FEET .... I] M ..... D .... N FLEET FEET ......................... FEIE]': FEET E%ET, ...... ..... . ........ ~ .......... : ............. :,~"~ ,:::5 E: J;,60 f)., :.2 ',3~.S .5.1 ....... 5C.~...E., ................ 1..F~D ............... 3557..57.,.5/-] :.::::. 1 ..... ;3;':_::;35::1:.?., 5...<.1 ................. ' ") ':"": ':' ":'/ ":'/'' '":: ':' '::' ':' ~*') '5:3...~ ........ i ........... : _ :..,.;!: ..... ,,., ....... 1 ~1 :,'fl-.; .............. ~ ........ , :3.7 () 0 1 :" ..... :':~ .- "::"~'~ .q 0 ':""~'::' · ,,'", :::, 2 4:2 E .1. 0 () ::ii: .6'? 9 4. E: 1 /- ": :36 4 9 4 ':' '"'"" ..... .................. ,,..,:.~ 12 ',iii: .-..,"7 i9 E:' ('~r:'; '::i: E ('~ :1./ .............. ""'-'" ""., , ..: .... :.,,:,,, 4.~., :i::; :'/.'; C) !'"] :-..: E.-:. c), ::::.-.-: c) C) :1. '= '7:i'.'.; 4 9 2 () E 10 (') ::3'7':.'.;'? .4 2 .... 1 ',}.':,:} .::, ,' 4 ::~ 4 2 2 4. 2 6 '.-.' 2':.'~ :.3,.1- lie '.-"':' ' ':=' .... :::::9.00. ":' ................ i,O,O .............. 3~[:?.9.,..,..35 .-.:::.1 ....... 6/.;.':t ""'"" '"' '"'' ~'' "" ........ ................... . ::,,:,¢: : :: .... ~.,>,,,z.:'.!:L J::? ::~ :::,.A:il E ..... ¢:5:,'.., .,(L:~! ........ Ei,, U.CL. ::! (!. ti-'.":. ;"~ :;:',':~ 4 Fi,:") C) 2 ::3 2 '::' .,..1. :.::: '":":' ........... : ..... E 4 :!:::,, .,:...I. E :3 .... ,7 5.'.1. 4 8. 15 7.0/::. 5 5 4-8.0:3 :5 7 00. 5:E:O0. 5900. " ' I ' I ......... ~'I' ' -"'" CONFIDENTIAL INFORMATION ' ':"" ,IORTH SL. OF~'E~., ~I....A.:,,...A 1. O: '.2'i;'~ :: .,1...., :::.'::3.-,,~F:'FR-..',3.q Furnished By Cono... .Irtc, ¢ "" ,'"' ~,1 .... i ...... · '~' II:::./-~.::,I...IF.E. ll Df':;,'IF'"I" DF~.'[F'T c:r"ll.ll':;~'.i::.:t.--:i Vt{..RlIl"i:~l .... 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'~ 4 '= ........ : ..... :: ..... , 74:26 ,, 6'7 ",':~'":, '= '='-', I,,~ '-,' ,::/ ,' "-, ........... t S l:l.f'~ .... ,.~: .... ,, · ...... :,c ...... I...::, S 1. '7 24 ~,-J 1 2 :t. '761o, 1 'i lr~ S 46 ?,0 W '::~/. 7570,,7z~. '::":~'~ '::'= .... 520,7,~ .... = 9:3 24., .................................. ,..., / ..... :, ¢:'. ...... S 1 17 W :3',36 ,; 4. :2 S; 1 '2, 45 W 67 ..... " ........... ~ ..... :: · · ~.,6, q. ().~ .:,/..: ,.I. ~ ) ·/-, ~ .,.~ ( ~ '.,-*,, ,.-,, l ", -.- L · 7 .- 7 ~Zu~ ~ $ ( ~ .. ().-, ~. 7 ..:( ~ I.~ '~'::' '~ ..... , "" .......... '~ ..... , .... ~,-, ' - , ......... , ............... ,-- ........ ~ .............. ~ ....... , .................. ~...~.. ~ ........ · ............... 780] , 9 3() S 49:30 W 'F'~-,, 775',B. 57 :2,'2,'?, 96 770'2,,, 57 :'2,:~;::9~ :20 S 14 9,76 W 4 !7, '7:39 ~-, :~: :3~"~ S ~":' :30 M '7~ ' ""':'"" "-, ............ = .... 7,.~ ........ ~ ............ 40 zI.C)Z~, z 2 7',:30:~: .4.0 ':::'T~F:: ,, ..,'=5, '.3 ~ ~, t , :3 ~ t.,~ Zl.:~:9, '?3 S :22 .,:: W .1 ...... ::, ;'"IEAF'i;I...IIREI') ~)R]:FT i]RIFT CF~i..IRSI::!: VERTICAL. '~ '-' ' "' ' ' ...... '""~ ..... :..,::ii'!~R r'~EF:'TH i...,Nbl...I-:. DIRECTI:'~N L. ENGTH DF:I:'TH F.';I:'.!:C]"IOI',I TV!:) C ~:~ 0 R D I N A T E S I:)I?'-!;T,..~I,IL.[:- DIl..,,,:::....1 ION SI?J: I'T' F."E E.T' D I'i D ....M ......... E'E ET. ............... I!::iE E'[ ................... 1:![ EI[U[ F.E: E ]': [:!:i ! I?!' . ....................... ~:i.r:[ l:,iil T ....... D I','t 1} ('.:~ .,,'. it. O 0 F D I S "r' A N C 1:.::': ",, /...., .,..":' 1 ,, ,..'::",..,:' F-Iii:' ti:." 'l" iPT "~ SL ~465. Suggested form to ke inserted in each "Active" well folder to d~,eck for timely compliance with our regulations. '- rator, Well Nan~ and Number Reports and Materials to be received by: ~ ~--- ~ Date Required Date Received Remarks Ccmpletion Report Yes Well History Yes - :/ ~re ~ips -' ~~ · Registered S~ey Plat ¢<~ Inclina~on S~ey ~: STRATIGRAPHIC HIGH RESOLUTION DIP METER LOCATED IN THE APPENDIX , . N 0 R T H I AS-BUILT PAD L SECTION 8, TI:3N, RIOE, UMIAT MERIDIAN L 18 16 U.M. VICINITY MAP LOCATION IN SECTION WELL i FROM NORTH LINE i FROM WEST LINE I 1970' 158' . · STATE PLANE COORDINATES WELL i NORTHINGS : EASTINGS I ~ 6,031, 499.2 { 544,758.7 i : = ZONE 4 CERTIFICATE Of SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY ~I~I~N~I~:~, I I REGISTERED AND LICENSED tO PRACTICE LAND ~, ~ - 'A%- ii SURVEYING IN THE STATE OF ALASKA ~D tHAT ~ ;~ ~J/ 2~N II ;'~ THIS PLAT REPRESENTS A LOCATION SURVEY ~ ~ ~___' "~.'~ II II MADE BY ME OR UNDER MY SUPERVISION. AND ~ ~N ' .0'''''~0.i~O$ ~. II ~ II THAT ALL DIMENSIONS AND OTHER DETAILS ~,' ~ II I _ ~ ~ '~/J ~ ' ' · · ~, ~' .~m- ~ /I ......................... ~ ~_ ~ ........ ~ ~ Il To ' noco Inc. of Shipment of ~_2~.;:n;'~:'_-~; ~-e.g.'~-_,~ Confidential Information Date O ~--'/7/~...~9 [] Under Separate CoVer . E~nclo'~ed Via ~J¢/g::} f'~::;) [-[~_( ~./'Ct~.~ . Quantity Contents Transmittal Approved By THE ¢'o~ L ooo; ~(_l~ ~-BEPTH mo ~ Instructions: Please acknowledge receigt promptly J;W signing and returning carbon copy. ,:leceived By Date ~emarks MAY 1 7 ~.984 Transmittal Copy Only To Alaska Oil & 6a3 Cons. Commission 13-98 PCX1 7-79 ARCh,qr2,q~. RICK OKLA. CITY .... ~PRINTED IN U.S.A. To ~ fC~,~,~,~__2~ ?¢-~onoco Inc. T~ecord of Shipment of ~ va =v~] ~ '~:;Geophysical Section Confidential Information Date ~/~'~~ ~ [] Under Separate Cover . [] Enclosed Via H~/q ~ -'~ (~----(--( ~'m~--~ Quantity Contents B ,l ,1 Transmittal Approved i/i/l/k.V-,(i Date Instructions: ~lease ack led§e receipt promptly by si~ning and reAurnin~ ca~on cooy. Received By Date Rema~s ...... e~IIIIII~ID[ Transmittal COpy Only To 1 3-98PCX~1, 7-79 NORICK OKLA. CITY PRINTED IN U.S.A. STATE OF ALASKA ALASK )IL AND GAS CONSERVATION~ MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Conoco Inc. 3. Address 2525 C Street, Suite 100, Anchoraqe, Alaska 99503 4. Location of Well 158' FWL, 1970' FNL, Section 8, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 56' (KB) 6. Lease Designation and Serial No. ADL 25509 7. Permit No. 84-5 8. APl Number 50- 029-21068 9. Unit or Lease Name Milne Point Unit 10. Well Number L-1 11. Field and Pool Kuparuk River 12. (Submit in Triplicate) Perforate )~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). L-1 was drilled to a total depth of 9500' (9419' TVD) on April 7, 1984, The Kuparuk, Sag River and Saddlerochit formations were encountered. After logs were run it was decided to run 7" casing thru the Kuparuk formation. A cement plug was set @ 8934' to 8684' to abandon the Sag River and Saddlerochit formations on April 4, 1984. 7" casing was set at 7523' on April 11, 1984. The intention is to now perforate and individually test the three intervals listed below using tubing conveyed perforating guns and a standard DST tool string. Each test will last about one day. Following the third test, a permanent packer will be set above the top interval, and the wellbore displaced with diesel. The well will be suspended by setting a positive plug below the packer, closing the SSSV and installing a BPV in the wellhead. Test I 7186' - 7214' Test 2 7160' - 7180' Test 3 7068' - 7128' RECEIVED APR 2 519(14 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Senior Drillinq Foreman The space beqow for Commission use Date April 13, 1984 Conditions of Approval, if any: Approved by ............. ~ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate THE ANALYSTS 702 WEST 32ND. AVE. ANCHORAGE, ALASKA 99503 (907) 272-5114 TELEX: 090-25382 April 13,1984 Received from the Analysts, In¢ the Blue line copies of the Mudlog, IDEA Log and The Pressure Evaluation Profile (PEP) Log and sepias of the same logs~from the following .well: 1 Set Blueline 1 Set Sepias OONOCO/CHEVRON Milne Point #L-1 Sec.8, T-13N, R-10E North Slope,Alaska Bill VanAlen Alaska Oil and Gas Commission f MEMORANDUM ALAS~L~'~OIL~AI~ GAS CONSERVATION CO~,~ISSION TO: C. V/~/~/terton DATE: March 28, Chai~fa~l_/ .~ ~?/' FILE NO: 21.5 CO~S ~ ~o~er TELEPHONE NO: THRU: State of Alaska 1984 FROM: Harold R. Hawkins ~.//~y SUSOECT: Petroleum Inspector// Witness BOPE Test and Check Diverter System on Conoco Well No. L-i Sec. 8, T13N, RiOE, UI-I, Permit No. 84-5. Wednesday, March 21, 1984: I left Sohio's X Pad, subject of another repOr-~,~ t° Check several well's at the Kuparuk, also subject of other reports. I then proceeded to Conoco's drill site ~t Milne Point, and checked out the diverter system, .which I found to be set up correctly, and function tested ok. Thurs,_ay, March 22, 1984: Witnessing test's of the BOPE equipment ~s started. ~ .... Friday, March 23, 1984: The BOPE tests were completed. There were ~W0 ~ai!u~s, the 10W~r kelly and the flex choke line hose. i filled out an A.O.G.C.C. report which is attached. In summmry, The BOPE .test's on Nabors Rig 27E was satisfactory. The BOPE equipment that failed was replaced and tested to 5000 psig. Attachment O&G # 4 4/80 STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COHMISSION B.O.P.E. Inspection Report Inspector Operator ~D /c~ ~'"~f) well ~ -2 ~.ocation: Sec f T/7~ R/~U ~ Drilling Contractor ///~ ~f~_q Date. Well Representative Ps rmi t ~ Rig ~ ~7~Representativ~ Location, General ~/~ Well Sign . ~/: General Housekeeping ~/f Reserve pit (~ /~ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve ACCUHULATOR S'YS TEI.1 Full Charge Pressure ~ .~P ~ ps.ig ' Pressure After Closure /~d~ psig 200 psig Above Precharge Attained: ----min/~ sec Full Charge Pressure Attained: / _minnie-sec N2 ~,~, ~6~.2~, 2 ~2'~, ~3~ / ' _ j -. ~ Controls: Haster Remote ~( Blinds switch cov~r Kelly and Floor Safety Valves ' Upper Kelly Test Pressure ~ Lower Kelly Test Pressure 6-~(3 Ball Type Test Pressure ~:-' Inside BOP Test Pressure -~. Choke Manifold Test Pressure ~:o. Valves } 7 No. 'flanges 2 / '' Adjustable Chokes 7-~/~ /4~ /~/~ f ~/~ Ilydrauically operated choke Test Time Test Re sults: Fa ilures _ '~ - 6~) ~ Repair or Replacement of failed equipment to be made within days and Inspector/Com,"~ission office notified. Remarks: 7/~ / Distribution cc - Operator :.-- .' . :' ..-~J: .: cc - Supervisor Inspector :- ~ ~' ~: :,/-'-%~.~-.--~/~-'. '- ' .... March 6, 1984 Mr. J. W. Fritsch Senior Drilling Foreman C~noco Inc, 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re-. Mllne Point Unit No. L-1 Conoco Inc. Permit Mo, 84-5 Sur. Loc. 158'FWL, 1970'FML, Sec. 8, T13N, R10E, UM. Btmho!e Loc. 450', 2650FNL, See. 7, T13N, R10E, Ri. Dear }.ir,. Fritach: Enclosed is the approved revised application for permit to drill the above referenced wel!. The provisions of the cover letter, dated January I1, 1984, accompanying the original approved permit are in effect for this revision. Very truly yours Harry W. Kugler' Co~IsSioner of Alaska Oil and Gas Conservation.Commission be Enclosure cc: Department of Fish & Game, Habitat Section w/n enc!. ~epa~tment of Envfronme~ta! Conservation w/o 0nci. ,~-'- STATE OF ALASKA ALASKA ~,,b AND GAS CONSERVATION CC ..,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL i~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L~ SINGLE ZONE [~ MULTIPLE ZONE [] 2. Name of operator Conoco Inc. 3. Address 2525 C Street, Suite 100, Anchoraqe, Alaska 99503 4. Location of well at surface 158' FWL, 1970' FNL, Section 8, T13N, R10E, U.M. At top of proposed producing interval 25' FWL, 2120' FNL, Section 8, T13N, R10E, U.M. At total depth 450' FEL, 2650' FNL, Section 7, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. 56' (KB - est.) I ADL 25509 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 13. Distance and direction from nearest town I 14. Distance to nearest property or lease line Northwest 37 miles I ' 5300 feet 16. Proposed depth (MD & TV•) 17. N-~]mber of acres in lease 9. Unit or lease name Milne Point Unit 10. Well number L-1 11. Field and pool Kuparuk River Amount $200,000.00 Ii~. Distance ,to nearest drilling or completed ~ mps~q.~2L~_°°n 13,000 feet 8. Appro~<imate spud date March 12, 1984 9550' TVD (9672' MD) fe~.t 2555 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 8~0 psig@ Surface KICK OFF POINT 6000feet. MAXIMUM HOLE ANGLE 15.7t51qsee 20 AAC 25.035 (c) (2) 4500 . psig@ 0~0 ft. TD (TV•) I Proposed Casing, Liner and Cementing Program SIZE CASING AND LtNER SETTING DEPTH QUANTITY OF CEMENT Hole ! Casing Weight I Grade Coupling Length MD TOP TVD MD BOTTOMTVD (include stage data) 24' 13 3/8q 72# K-55 BTRS 80' 0' 0' 80", 80' Cement to Surface 12¼" 9 5/8" 47# L-80 BTRS 2500' 0' 0' 2500" ' . . ' i 2500 1500+_ sks (2 staqes 8½"i /" zg# i L-80 BTRS 9672' 0' 0' 9672'1 9550' 1400+ sks. (3 sta_qes) I . i I 22. Describe proposed program: ¢ The proposed L-1 Well is to be drilled to a total depth of 9550' (TVD) to encounter the Kuparuk, Sag River and Saddlerochit Formations. The Sag River and Saddlerochit Formations will be tested then isolated, then the well is to completed in the Kuparuk Formation. Refer to the attached supplemental data sheets. 23. I hereby certify that the f~regoing is true and correct to the best of my knowledge S,GNED .~...5;'~.~ T'TkESenior Drilling Foreman The space below fo~mmission use CONDITIONS OF APPROVAL Samples required ! Mud Icg required ~¥ES ~NO i ~¥ES [:]NO I ~' Permit number DATE March 5, 1984 APPROVED BY Form 10-401 Directional Survey required I APl number [~ES •NO I 50- ¢'?'"~'- SEE COVER LETTER FOR OTHER REQUIREMENTS March 1984 ,COMMISSIONER DATE u, by order of the Commission Submit in triplicate Rev. 7-1-80 Ie CEMENTING PROGRAM SUPPLF~fENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. L-1 Conoco Inc. 2525 "C" Street, Suite 100 Anchorage, Alaska 99503 m~ The 13 3/8" conductor will be set at 80' below the surface l15'-K. B., then cemented to the surface with high yield permafrost cement. Be The 9 5/8" surface casing will be cemented with 1000± sacks of high yield cement followed by 700 sacks of standard permafrost cement. This cement volume provides 100± bbls. excess, based on as AHS of 16". Ce The 7" production casing will be cemented in three stages. The first two stages will cdnsist of 700± sacks of high yield followed by 700 sacks of class "G" cement pumped around the casing shoe (estimated 4500±' of annular cement, assuming an AHS=iI"). The secondary cement job will consist of 100± sacks of permafrost type "C" cement, followed by 50± barrels of Arctic Pack, pumped down the 7" x 9-5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4000' Surface conglomerates, silt and sand sequences. Estimated based of permafrost at 1700±. 4000' - TD Predominately shale until the Kuparuk sands - expected at 7000± TVD. III. FORM~ATION EVALUATION · A. Dual Induction and BHC Sonic logs will be run across the surface hole. Be Standard mud logging equipment to be used below the surface pipe with a IDEL Plotted. Ce De 'Ninety feet of core will be taken in the Kuparuk Formation and 30' from the Sag River. Sidewall cores to be taken as determined by onsight geologist. Wireline logs for the 8~" hole from T.D. to the 9 5/8" shoe will include: Dual induction laterolog; borehole compensated sonic; formation compensated density with CNL and caliper, Dipmeter. E. Velocity Survey will also be run before running casing. IV. DRILLING FLUID A high viscosity gel-fresh water mud system Low solids non-dispersed mud system Low solids dispersed mud system 0' - 2500' (9.0-9.$ ppg) 2500' - 6500' (9.4-9.6 ppg) 6500' - TD (9.6-10.2 ppg) V. DIRECTIONAL PROGRAM The L-1 will be a slant hole with a proposed KOP of 6000'. Angle will be built in a south 41.8° west direction to a maximum angle of 15.75°. This well is the only well on the "L" pad so there is no danger of drilling into an existing well. A Teleco tool is to be run while drilling below the KOP for directional control. ..... ~ .... CONOco.- -I Nc: ........... ~ MILNE PT UNIT. WELL NO: L-1 REVISED PROPOSAL NORTH SLOPE. ALASKA _ ~ i .... L ................................. ~ ....... ~: ....... i ..... ... EASTMAN WHIPSTOCK. INCi 2000 __ ' I 3000 _ i . . ~ .4000__ ._ L__~ ooo. 2000 :WEST-EAST · _ ._ _ __5000 .... ' ' 1000 ~ .. TARO~T i .... i ~ - -TVD,.955ol - - - : ........ ~ - · · - ~Tl"tD,-~?2i ' - - t ' ~ ' - ' f ' ---DEP=912 ; : - SOUTH 680 ,; - : t,~:ST 608 ~ - ........ -':;.''7~h..i-:~ '~!.. ...... ~'i i~ .... --~-_'z:.S _41 i' DEO -48 !H [ N. W ._ 10000_ , -: ' i 2000 ._ ZO"O./2 DIVERTER S-FAC/{ - /FL 0 A~/_ I/,/~: F'I~ L. Ut~ I I1¢~~'~"" ' At41V t.]LA t~ ttYBt~AULIC CONTROL SYSTEM FOt~ T1413 STACK TO IECLUD~ CO~T~O~ ~A~I~O~D O~IG F~O0~ W/T~ ~000 PSI COAlOCO, , ~ o/- 141L/,IE l~O/~ ST~CK FO~ COldOCO IIJC. . 1358" .5000 PSl CO~I~UCTO~ ldo T~ ' /FL O~I F.- (/.) ~) I , PR.= 3500 .} TST. PR. =5000 ~) CHOKE A/VD E/IL ~E?A/~A TEl- ~' TO /VlG£ 5td /CE4~UIA'EtdEiLI T~, CONOCO~ et ~/ -/vlIL~H ?OltYT z~ O P~=' FO~ !~-~- '/ 7 " CA31HG L N'rDRAULIC CC.'tiROL $I'$7[U FOR BOP STACI~ B CNOI~' a~:FOLO TO I~CLUDE (5~ STAT~ CONTROL-MANIF~ L~AT[O REgOT[LY ~ITH 3~0 PSI ACCUMULATOR ~T~L TO BE ~CAT~O 'ON RIG FLOOR. Z K~L 8 C~G~ ~ANIFOLDS ~ ~ ~NIF~D SIZE-RATIN~ ~ C~O~E MANIFO~ SIZE .~. ~ _ i ii i ~ FRO~ ~UD PUb. KILL MANtFOLD FROM REMOTE XIGX___ ~~~ R~OTE PRESSURE GAGE SENS~ PRESSURE PUgP ' ~ DRILLING ~ ~DR~ULIC ~NTROLLED R~OTE OP~gTED REMOTE PRESSURE GAG~ SENSOR ADJU.,,q"A BLE CttOKE CHOKE ADJUSTABL~ UANIFOLD CHOKE -- VARIABLE CHOKE CONTROL, TO SNALE SHAKER t BLEED LINE TO PIT 1 TO ATMOSPHERIC MUD/GAS SEPARATOR ....... ~ ~:7 ;: ;~,-~.,,~ ~-~, C)~-r CHOKE 8 KILL MANIFOLDS FOR cis/8'~ 8 7" OD CASING BOP STACK BOP HANIFOLD LAYOUT - CONOCO, INC. GRND. TYPICAL Ill ll~lllII ~e tall SECTION ' '~' ~ "~ L PAD coNsTRUcTION DETAILS ~~~~-,~~ 21 ._. g,~% ~B. Mal~n .~ S7 6 S6, TI3N, RIOE, U. ~, ALASKA-KUPARUK FI~U ~ C[-~8 .'~ ,,~.. .~ OCTO~R 12, 1985 I ~ ,- ~ ~-- OFESS~ _~ FI~= E~VEN-I D~G. NO' L-8)-O01 J~u~ry 11, 198t Mr. Don Girdler Production Engineer Conoco inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Mi!nc'Point Unit No. L-1 COnoco Inc. Permit No. 84-5 Sur. Loc. i58'F%U~, 1970'FNL, Sec. 8, T13N, R10E, Btm/~ole Loc. 750'FE3~, 3000'FNL, Sec. 7, T13N, R10E, Dear Mr. Girdler: EnClosed is the approved aPplication for permit to drill the above referenced well,, If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are required. A continuous ~lrecttona! survey is required as per ~.~ AAC .050(b)(5). ~ available, a tape containing the ~igitized log info~tion ~halI be submitted on all log~ for copying except experimental iog~, velocity survev~ and dfpmeter Many rivers tn Alaska and their drainage systems have been c!amsifled as important for the spa~ing or migration of anadro~us fish. ~erattons tn these areas are subject to AS 16.05.870 and the re~lations pro~lgated thereunder (~,~t!e 5 Alaska Administrative Code). Prior to co~encing operations you ~y be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Artiete 7 and the re~lations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of EnVironmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing in~tal!ation of the blowout prevention equipment so that a representative of the Commission may be present to witness te~ting o£ the equipment before the ~.urfaee Don Girdler M!Ine Point Unft ~.. L-1 -2- January easing shoe is drilled. !~"aere a diverter system is required, please also notify this office 24 hours prior to commencing equtp~nt in~tallat~.on so that the Co~mission may witness testing before drilling below the shoe of the conductor ~ipe. In the event of ~u~pension or abandonment, p!e~se give this office adequate advance notification so that we may have ~ witness pre,ant. VerM t~Iy yours, Chai~an of Alaska O~1 and Gas Conse~at~on Co~isston b~ Enclos~e cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. la. Type of work. STATE OF ALASKA ALASKA (j,L AND GAS CONSERVATION CO,...~vllSSION PERMIT TO DRILL DRILL ~ SERVICE [] REDRILL~ SINGLE ZONE [] DEEPEN [] MULTIPLb STRATIGRAPHIC ?O AAC 25.005 "~-I~D.-~l-ype-OT'well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] 2. Name of operator Conoco Inc. 3. Address 2525 C Street, Suite 100, Anchorage, Alaska 99503 4. Location of well at surface 158' FWL, 1970' FNL, Section 8, T13N, R10E, U.M. At top of proposed producing interval 113' FEL, 2277' FNL, Section 7, T13N, R10E, U.M. At total depth 750' FEL, 3000' FNL, Section 7, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF etc.) / 6. Lease designation and serial no. 56' (KB - est.) I ADL 25509 9. Unit or lease name Milne Point Unit 10. Well number L-1 11. Field and pool Kuparuk River 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 Amount $200,000.00 13. Distance and direction from nearest town Northwest 37 miles 16. Proposed depth (MD & TVD) 9550' TVD (9792' MD) i 19. If deviated (see 20 AAC 25.050) ; KICK OFF POINT 5500 'feet. 121 SIZE Hole Casing Weight 13 3/8 9 5/8" 11 72# 47# 29# 14. Distance to nearest property or lease line 5300' feet 17. Number of acres in lease feet 2555 20. Anticipated pressures MAXIMUM HOLE ANGLE 21 o (see 20 AAC 25.035 (c) (2) 24" 12¼" 8½" Proposed Casing, Liner and Cementing Program CASING AND LINER Grade Coupling I K-55 BTRSI I - L-80 Length 80' 2500' SETTING DEPTH MD TOP TVD I 9792' 0' ~ 0' 5iDistance tonearest drilling or completed mpson Laaoon we~32- I4 13,000 'feet 18. Approximate spud date February 1, 1984 800 psig@ Surface 4500 psig@ 9550 ft. TD (TVD) MD BOTTOM TVD g0'I 80 2500'~ 2500' 9792'~ 9550' I I I QUANTITY OF CEMENT (include stage data) Cmt_- to surf, 1500+ sks. (2 stages' 1400+ sks. (3 stages] 22. Describe proposed program: The Proposed L-1 well is to be drilled to a total depth of 9550' (TVD) to encounter the Kuparuk, Sag River and Saddlerochit Formations. The Sag River and Saddlerochit Formation~ will be tested then isolated, then the well is to be completed Refer to the attached supplemental data sheets. -23. I herebq~r-tg~hatthe foregoing is true and cQcr, ect to the best of my knowledge SIGNED '~;::~ f.~,,,_ ~ C~'~'~,~._~ T,TLE Producti on Enqineer The space below fi - ;o~nmission use -~ - CONDITIONS OF APPROVAL Samples required I Mud log required I Directional Survey required I J~,Y-ES []NO ~'YES []NO []NO Permit number ---' -, ~ I Approval date Form 1 DATE January 5: 19F JAPI nu~ r / 5o- o z 'z.i o SEE COVER LETTER FOR OTHER REQUIREMENTS ' ,COMMISSIONER DATE January ]1: by order of the Commission Submit in triplicate SUPPLEMENTAL DATA SHEET ~ ~. j.~ ... APPLICATION FOR PERMIT TO DRILL Conoco et al - M±lne Po±nt No. L--i~':~'::.,-"~4'~¥ ~" "~.'~';'~'~ 2525 "C" Street, Suite 100 Anchorage, Alaska 99503 I. CEMENTING PROGRAM Ae The 13 3/8" conductor will be set at 80' below the surface 115' K. B., then cemented to the surface with high yield permafrost cement. Bo The 9 5/8" surface casing will be cemented with 1000± sacks of high yield cement followed by 700 sacks of standard permafrost cement. This cement volume provides 100± bbls. excess, based on as AHS of 16". Ce The 7" production casing will be cemented in three stages. The first two stages will consist of 700± sacks of high yield followed by 700 sacks of class "G" cement pumped around the casing shoe (estimated 4500±' of annular cement, assuming an AHS=ll"). The secondary cement job will consist of 100± sacks of permafrost type "C" cement followed by 50± barrels of Arctic Pack, pumped down the 7" x 9-5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4000' Surface conglomerates, silt and sand sequences. Estimated based of permafrost at 1700±. 4000' - TD Predominately shale until the Kuparuk sands - expected at 7000± TVD. III. FORMATION EVALUATION A. Dual Induction and BHC Sonic logs will be run across the surface hole. Be Standard mud logging equipment to be used below the surface pipe with a IDEL Plotted. Ce Ninety feet of core will be taken in the Kuparuk Formation and 30' from the Sag River. Sidewall cores to be taken as determined by onsight geologist. De Wireline logs for the 8~" hole from T.D. to the 9 5/8" shoe will include: Dual induction laterolog; borehole compensated sonic; formation compensated density with CNL and caliper, Dipmeter; NGT. E. Velocity Survey will also be run before running casing. IV. DRILLING FLUID A high viscosity gel-fresh water mud system Low solids non-dispersed mud system Low solids dispersed mud system 0' - 2500' (9.0-9.8 ppg) 2500' - 6500' (9.4-9.6 ppg) 6500' - TD (9.6-10.2 ppg) Ye DIRECTIONAL PROGRAM The L-1 will be a slant hole with a proposed KOP of 5500'. Angle will be built in a south 41.5° west direction to a maximum angle of 21©. This well is the only well on the "L" pad so there is no danger of drilling into an existing well. A teleco tool is to be run while drilling below the KOP for directional control. i . -'.----4." · · -. .... 500L . ~.~-, - --~.__ ~ : : __L' '. · -: ~ -'i - -- : '-~...~-- :., :' -i-;-~ - :-:--~---- · :4-- ~ .... -I ..... ; ....... i .......... ~ ........... ~ ........i ......... ~ ..... ~ . ~-, ~ _KOP T_VD~.5500~PID~-5_5002_DEP~OJ~.' ~ _ t , - :-__--: ............ 4- ...... : . ~ .... :~. --. ,~~-BUILD 2 /2 DE: ¥.. 'L': ::-~__ ~ ' : : ] ' 17': ] ' Y l '.'"~-'".':'_-:-_-~._:-'7: ........... 10'-J-~-~' :-- ~ ......... --6000~JJ,:L¥__ ~_~O0_F'__T~ ~. : ! ...... ! . ~ ..... . !. . ~.~ ;--~ .-'~--~- :--:--~'-':-- t5~± ........ . _4F_.. :_._i. ~ __.~, ..... j -'--.___J.. :... ........ ~ ~ ; .....A--~ .... '~' ' : ...... 4 ..................... t :i ........... '~ ~ ........... I ..... :-- !" .... --~ .......~ ........... : ..................' ......... -~-~---J ' ' ? ........ 1 ........~, ....... -~ ......... : ........ ~ ...... .... 4--:-:--J-~--aO -EOB4----TVD--6~11--~TMD=6329 DEP=l--48 - :~---~--- 1- - \ .... :____~_,L_ ............ _____4 ..... : -~-:i--- 4 ..... m __4 ........ ~, .......i ..... l .......... : .......... i--- - ' : -1 ~- ! -:-~! : I ~ i . ' · J ' ' J i : i - : i i . . i . : - ' - · : --. ,., ,., ,.,~ - ] - ..... \- !--- MTI~I"~I ~' :I~'IIDADHV{--- ' : ' -.-i .......: ........ ~J ~ ...... J'- : .... ! ; : ' i ', J ' __-~uuu-.~- -:-~~.~_~--~,~:~,~.,,~_ _: -- - -- : ................................. ~ .... ....... : - -~~:-:-q: V, D=70~O0-:-TMD=7066- ' D, EP= 409 .... ._:-:-_:-::~ ~-::-::-':--~-:: ..... ::L :-'::i:__:::-:~-'-_::::'::-:_::---~_:-:':':',:'-,_:_"~ : .' ~ : ,. ~ -. ....... ~ ...... ¥--- ~ ~ ~ ..... ~ '-- ~ -.~.' ~ ' ~ ' - ---4 ........... .-' ....................... ! ................... ~. .... ....... I ......... ~ \ ........ ~; .......... : ....... : ...... 4.--:-:--:1 ........~ ...... i-, ..... i .... - ~ ....... i ................. i- ~ _: __.__.~.i .... ~ : .... ! -: ..... .~:d .......... i ~ ' " ' ' : ...... I .... ~ ..... :__~-~:..\::: ....,., ........ AVERAGE. ANGLE ....... ,~ ..... : .............. ~ ..... !-..~ . -~-- ~- -~ , eooo:_ '--~ :"._~__ ,_ _-~-~.,,~,,.-_~.~_,.,,,~ .................... - ~ . : i ' ~ - i ' : ' ' ' ' ' I ...................... -: - ~. .............. : .................... : ......... l ........... i ......... 1. .......j ...... 1 ..... J .... + ..... I' '- ~. ....... ~ ..... :":..-::::-i:::_-:\_~: ........ ~ ....... !__- ..... ~ ..... :::~ ..... ~ : .... ~' ......... , ......... : ....... ~... l ....... :..~ ........ ~ .... : ................... :--: ........ ,-~ , ? :-'-t-~-:--:-:-:--:--J ....... :, 7::-'-~ ....... ? ........... , ~ '" t ! - _:_:: ::::..:_-_::::-;::,: .,- , .............................. ..... ..... , ..... ..... ,.:..-, .........., ........ , ........... ............... ...... : .... n-:---'---j -'- :'~, .... gooo--_. ' _ _ :__, ___---------__-__---------~----- .... ~. .-- __ -__ _ --_ . j ~_ _} _ _~ _ ~ : . i . : . ! : . : . : I . - I ................ - -::---:-:;--':-- : ..... : :/:- :- -:: !- \::: SADLEROCHIT :. TVD=9250 TMD=9471 DEP=1260 i ......... : -:: -_-' - ::::v i::-:-:::L:._ ...... i_ .' ' ':.'_ i i' !--'-:-*-:~: .... TAROET:(TD)--i-TVD=9550 TMD=9792.- DEP=I 373 ........... : ' ....... :, . ._ - : ! , : .... -10000- , -: ' ' , , I ! , . :':.' '. b - - : - . looo 2000: : ........ ~ - _ . :--VERTICAL SECTION ..... :. ............ ' ........... : ......... i ................................... : ............................ ~ : ~.~ - . - ' i : ' !:'~' :~' · '~';'' ' - ' ..... ............................................................... ' ........... i '- ' ....- OlVERT ER ST,4c~K - ( , I ~~~ I II ~.., ... · . _ ,.~.%..~.;.~... { .... . ... :.......- . .- . ~ . . ~ . . ... · ~..,,, , ~ ,_ ~'.~.-~ ~.~ -~: ~-: ttYDRAUI..IC COtV~'ROl_ ,~'YST£t4 FOB 77-115 STACIC TO /tU'CL. UDE ~-.' lBO GALLOiV CAPACIT'Y' ACCUMUL~TOi~ AtLID i~ESEi~'V'OII~ COMTi~O~. t, qAIIIFO~D OiLI~I~ ~00~ WITI-I 3000 PSi WO~KIAi~ BOTH /VFDt~A UI_i¢ P~t/Et~ITE~' CtO,~E,~ TAIEN E/TI-t~i~ OAI~' OF Ti-t~ VALVES MAY COAIOCO, e ~ ,~/ - I¥1LAIE F~21AI7 STACK FO~ COIUOCO B.O.H STACK SIZE t~A~'IM~ I~EET$ t~ 58 ~' A rs~ P~ = ~oo co~T~o~ ~ANIFO~ L OCA T~ ~OT~ 5000 PSI ~ ~: WIT~ I~0 GA&&'O~ ACdU~&A~O~ A~ ~ ': TST. PR.=5~ ~ ~ O~ ONE ~T OF ~LIMD ~A~S AMD T~O - ~u. ~000 __ (~ ~HOKE AMD Ki~ ~A~IFOLDS ~0~ OUTLETS ~EPA~ATELY TO M~ET APl ~P S3 CLA~ 1358" ~000 PSI ' ~ ]5~'~ 5 ~0 X 13~ '~ 5000 ~ ~ ~ ~ CASING ~00~. 1 ~ E~- 5000 ~/OE OUTLET3 { VA~VE~ TS~ PR.= 5000 C~SIM~ ...... ~ ~~ ~o: ~ ~ooo ~ I~~ c~q ~/T~ ~00~ _ . ......... ...... ~~ - .. . .......... :: :,,; . .' , .. . ~'"~ o.~. "~' "' COM¢UCTON CONOCO~ ~, ~ ,=/ - ,MILNN POINT L~ O F'K' FOB/~' ~ 7 " CA31H~ KILL MANIFOLD FROM REMOTE HIGH PRESSURE PUMP NOTE: L H~RAULIC CONTraiL SYSTE. FOR eo~ STACZ a CHO~ ~A~IFOLD TO I~CLUDE {5)$TAT~ CONTR~ ~ANIF~ L~ATEO RE~OT~Y WnX 3~0 PS~ ACCUMULATOR i~ G~. RESE~R 8 AUX. ENERGY SOURCE. ST~ ~ROL MA~IF~ ~US ~RIA~ CHO~ ~NT~L TO BE ~TED ~ RIG FLOOR. Z K~L 8 CHO~ MANIFO~S ~ 5~ S~. 3. ~L gANIF~D S~E- RATING ( C~E MANIFO~ S~E - RA~NG ADJUSTABLE CHOKE t BLEED LINE TO PiT I FRO~ MUD PUMP ~ ~ REMOTE PRESSURE GAGE SENSOR CONTROLLED PERATEO ._i). LIC CONTROLLED " OPIATED REMOTE PRESSURE GAGE SENSOR __ VARIABLE CHOKE REMOTE CONTROL CHOKE ADJUSTABLE MANIFOLD CHOKE 1 TO ATMOSPHERIC MUD/GAS SEPARATOR .. TO SHALE SHAKER CHOKE 8 KILL MANIFOLDS FOR: el'S/St' 8 7" OD CASING BOP STACK BOP MANIFOLD LAYOUT - CONOCO, INC. : Lon~rac~ ,~UJU Const. ~pec. ~z _ '.'~ ,~.- .~_~ .... _.-:~ ~, , I i, ,m · Proposed N-1 Location EXISTG 6RNO. TYPICAL SECT!ON N PAD CONSTRUCTION DETAILS $~)o, TI3N, RIOE, U.M.', ALASKA- KUPARUK FIELD OCTOBER 12, 1983 FILE NO: ELEVEN-I OV/G. NO.'., N-83-001 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee (2) Loc · thru 8) (3) Admi____~n ~ (~, thru 11) (10 and 11) (4) #,.r,,q ' (i2 thru ,20) Company (21 thru 24) 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. ! 3. Is well located proper distance from property line ................. .~ 4. Is well located proper distance from other wells ................... ~__ 5. Is sufficient undedicated acreage available in this pool ............ ~ 6. Is well to be deviated and is well bore plat included ............... { 7. Is operator the only affected party ................................. f 8. Can permit be approved before ten-day wait .......................... (.. , e 10. 11. · : , Lease & Well No. YES NO L-/ REMARKS 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Does operator have a bond in force .' ................................ ~.~ Is a conservation order needed ...................................... Is administrative approval needed ................................... . , , ,, . Is conductor string provided ...................................... Is enough cement used to circulate on conductor and surface . . Will cement tie in surface and ,intermediate or production strings .. Will cement cover all known productive horizons ................ ' ' Will surface casing protect fresh water zones ...................... Will all casing give adequate safety in collapse, tension and burst'. Is this well to be kicked off from an existing wellbore ............ Is old wellbore abandonment procedure included on 10-403 ........... Is adequate~ell bore separation proposed .......................... Is a diverter system required ..................... ................ Are necessary diagrams of diverter and BOP equipment attached ..... Does BOPE have,sufficient pressure rating - Test to ~'Z~ psig Does the choke manifOld comply w/API RP-53 (Feb.78) ................ #2// · · (6) Add: f~l~ -?-3'"-~ ? 25. Additional requirements ............................................. Additional Remarks: Geology: E,ngineerihs: HWK LCS BEW WVA ~JH H~ JAL ~. rev: 12/08/83 INITIAL I GEO'. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, , CHECK LIST FOR NEW WELL PERMITS Company ~ ~Le~'e & Well No. ITEM APPROVE DATE (I) Fee (2) Loc _ (3) Admin ' / r ~ -~ ('9z thru 11) ...... (10 and 11) (4) ..C.asg ..~r~ / _j _jry (12 thru 20) (5) BOPE ,~;~,~" / _bz...~ (21 thru 24) YES NO 1. Is the permit fee attached ......................................... .~Z~-~. 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 suff±cient unded±cated acreage available ±n this pool ............ 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... 9. Does operator have a bond in force .................................. 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ............................ ......... 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. REMARKS Is conductor string provided ............................ , ........... Is enough cement used to circulate on conductor a~d surface Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate.well bore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) ' Additional requirements ............................................. Additional Remarks: o Geo logy: Engine~i.i _n.g: WVA~ JK~ HJH ~---~ JAL'<"_,~M~ ~. rev: 12/08/83 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE i Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effod has been made to chronologically organize this category of information. FIELD ~ 2~99.8 3.6 81 0.~ 1~4 12.6 · 25tI. t 1.8 135 0.6 148 11-3 V 2513.7 ~3 CORR 0.5 1t0 11-3 ~ 2~.~ ~o co~ ~.~ ~ Ii.2 2525.7 3.~ 293 0.5 157 11.2- 2537.5 4.2 19 0.3 119 t 25B9.6 NO CO~R 0.4 ~t t1.i 2~41.~ 6.7 3 0.4 13~ Z5~5.5 13.& 138 0.~ 138 12.1 2$~g.a 12.~ ~Z 0.4 138 zs~l.s ~.s 92 o.~ ~6 25~5. t 9.8 ~oz o.~ ~37 zss9.6 3.s lzo 0.3 ~9 2561. S 16.0 a9 0.3 142 11.4 2S6~. 5 12.8 ~8 0.~ 1~3 t1,2 2~6~. ~ ?.O 9~ ~.~ 1~2 !1.2 ts~?.~ 3.t ?t o.3 z~2 ~ 2573.5 2.6 79 0.3 143 257?° 5 2581.5 2609.~ 2617.~ 2621.~ 2623.3 2627.3 2533.3 253~. 2~37. 2645. 2653. ~P DIP OE~ O~V OZ~ ~.2 116 2.3 1~3 11.2 10.1 5.5 133 0.3 143 11.4 6.6 110 O. 5 147 11,3 7.2 lZ7 0.5 1~8 II.2 5.6 1~2 O. 5 143 10.9 .9.t~. . 6.5 100 0.5 131 lO.~- t. 1 ~7 O. 5 136 10.6 8.0 73 O. 5 li3 10.3 2.~ 128 O. 5 140 10.2 6.~ 27Z 0.6 x3-9 10.3 3 5 ~I0 0 6 139 t0.~ 2.3 33 0.? 139 10.~ ~.9 2t~ 0.7 138 11'2 4.2 21,~ 0.8 1~0 11-5 3.1 176 0.8 142 11.8 3.0 176 0.8 1~3 !1.9 N,3 CORR 0.8 I13 ii,6 Z.~ 2~2 o.~ 1~3 11.5 i.~ 257 0.9 lls I1.2 I0-'.2- 7.1 156 0.9 Ill 11,3 '*****%, Z ~6 ~. l ¢. 8 81 O. 9 1 2567.1 NO CCRR 0.8 2673-! 3.0 319 0.8 II1 2675.1 Z.9 355 O. 8 Z577.1 NO C~i 0.8 146 2681.1 NO COR~ 0.8 2683. t 10.0 6 0.8 2~8~.1 8.1 16 0.~ 148 26~7.1 a.9 28 ~.8 2689.1 NO CORR 0.6 151 2691.0 5.0 117 0.~ 192 2693.0 3.~ 28 0.~ 152 26~5. O 2.9 ~8 0.8 152 2699.0 14.0 357 0.8 153 2t01.0 5.6 332 0.8 154 ~703.0 2.0 196 0.8 2~05.3 4.3 ZZ 0.8 2109.0 3.2 313 0.9 2711.0 3.8 192 0.9 t59 2713.0 4.0 192 0.9 160 2714.9 2.7 270 0.9 160 2716. ~ 2.4 2~0 0.9 2720.9 7.7 1T 0.9 160 2T22.9 13.7 304 0.9 160 2724.9 17.7 360 0.9 160 2726.9 29.5 179 0.9 160 2728.9 17.5 198 2730.9 2Z.5 29 11.2 lO.t I1.,1 10,3- 11-0 Ii.~ i~' 10.8 10.7 t0.Z- 10.6 10,1 . 10.3- 10.3 lO..Z 10.3 10.4 10.2 10.3 ~.a 9. s ~.-a- 9.2 ~.o ~.i. 9.0 9-.~ %0- ~.! 273~. ~ 11.~ 2746.3 1772.7 lO.O 2771. ? 12.5 Z78~. 7 I 2786 7 '27.9 Z?aa.Z /r~O.6 NO Co~ ZIgZ.6 z~.5 1806.6 2.6 2806.6 zao~.s 2B10.5 2822o~ 2~Z8.5 2830.~ Z~3Z. 5 2838.5 2~4Z. ~ Z~70.3 2~7Z.3 287~. 3 2876.3 2878. ~ 2~82.3 23.6 257 1.1 1 3.1 293 1.1 8.¢ 292 1.1 6.9 265 1.1 ~.6 15 1,,1 3.9 2_5 t,.1 8.1 36 1.1 5.5 70 1.1 ~.5 72 1.1 6.7 82 5~ ~2 t.2 6.4 137 3.~ 291 5.5 2~5 1.2 13.a 3S~ 1.2 ta.3 2~0 8.3 157 6.0 2~2 1.2 6.6 351 5.3 344 1.2 7.3 347 8.0 3~8 1.2 ~.I 355 1.3 B4 3.5 56 3.6 ~2 1.2 6.0 26 6.1 30 6.5 3 3.3 31 NO COR~ 1.2 326 336 113 152 152 153 155 15.3 152 ~ !52 2~e~.~ s.s i~ 1.2 ~so ~o-.7 292Z.5 I0.~ 8 1.2 147 2)2m. ~ 8.6 133 i. ~ t47 2940.5 6.5 285 1.2 1~t 2~2.5 6.2 281 1.2 1~1 19~6. S 17.8 11~ I.l I~1 10~ Z ~,0 ~ ~.l Z~O i.2 !~I ~.~ ~.~ ?~ 1.~ l(~ 2960.6 I0.9 72 I.2 !40 2962. S 4. S 58 1.2 141 IiZg' -tiZ]"- 29~4.6 2.6 48 l.Z 142 2966.5 2.9 92 t.Z t43 t2.5 2968.6 ND C~RR 1.2 !43 2970. ~ ~. 5 41 1.Z I~3 12'2 -_ 0 ~0 CO~ NO CO~ Z.8 278 N~ CO~ 1. ~.8 ~10 1.2 NO CORR 1.2 NO COR~ NO CO~R t. 2 NO CORR Z.O 171 3.8 2~1 138 f;~ CORR 1 3.5 252 ll.Z 305 8.~ 265 18.9 247 Z3.~ 264 7.~ 250 1.2 5.4 2~7 2.5 203 1.2 5.0 1~3 6.9 149 2978o 7 2. g80o 7 2982,.7 2990.7 2992.~ 2994.7 2~96.7 3000.7 3010.8 301Z.8 3016. a 30ZO. 8 3028.8 3030.8 3036.9 3038.9 3040.9 3046.9 3048.9 3052. 139 1 39 138 137 137 137 137 ].37 136 136 13'I' 138 139 I¢0 13~' i37 12 2 11.6'- : - ---' --'- -' '' - la.Z- tt.6- -- C--- -' - · IZ.Z "ii'-s -' - - ~ 12.t- .11..,$-- -_ C- - -- _- - _ ~ ' '12.0 II.0 .... A- --:-- - - - - - l~.~ io.7. ' -= ' -" - -- , - ' I - - - ~ 11 5 10-6 __ .i_ - - ~.z -lO"s--- - -'-- ---- -- -- - - , . ~.O-~o,-c'-' '-- ~.- -'-- - - -- . 1 , 1.0 !O.O--.- A -- - ~ I1.I I0~i"---'- - '~ - : -- -- - 11.2 -10.2-, - - _ .... . 11,2 -i0';4-- -_-> _ _ - -_ _ - _ ~ ' tl.5 lQ.T: - _- - - . ~1.9 1!-1 - --- _a ~ _ . 136. ' 11.3. !0-7_ _-- !)6 1!o? 1:36 it.,9~ -I-i~z -- - 136 1Z.!__ 1t6 t 1-'~-- 1i-~i 135 IZ..1 t1..i._ . -B .... _.- - _- .... ~ . l~ iz,o 138 12.,,,.5 ,' , 139 12.1- 137 11.3 1t6 I1'8'-- 136 !.,,? 11~.~__ _ : -C = ~- _ .... ~ ' 136 tl.i` _ 136 la.O 136 12.1 135 I1,.$.- 1~ ti"6 ii-~i_ - 9 2.$ 13t 1.2 135 11.,6- ,.,..,.,, **,,, *** ~, **~,'" ,~..,. ,.,..,. ,.., ******...,. 6°9 ~I 1.2 136 5o2 2~7 Io 2 136 ~o7 2~6 1.Z 136 6.7 18 l.Z 135 ~0 CORR )40 CD~R 2.~ 9 1.2 133 Z.9 36 1.3 133 3.5 45 1.3 t33 6.~ 358 1.3 13~ NO CO~ 1.3 136 8.0 319 1.3 136 ~.6 63 7.5 67 t.3 ~36 1Z.? 0 19. B 3~9 1 3.9 3~I 1.3 i3~ 3.9 138 1.3 134 2.9 153 1.3 133 1.6 40 1.3 132 0.9 t~8 1.~ 132 9.5 ~4 1.3 132 10.5 266 1.) 132 3.0 31 t. 3 132 Z.6 30 1.3 132 9.3 55 ~.3 131 9.9 49 1.3 131 8.5 ~71 30.6 148 1. 30.2 148 1.3 !31 1.2 72 1.3 3.1 336 1.3 133 10.9 131 1.) 133 3054.,9 3058.~ 3069.~ 3071.3 3073.0 3075.0 3077.0 3081.0 t091.1 3093.1 3097.[ 3099. I 3101.1 3103.1 3105. [ 3107.1 3109.~ 3117.~ 3119.1 3121.1 3123. Z 3125.~ 3127.2 31Zg. Z 3131.Z 3133.2 10oC 133 1.3 133. 11,,5 !!.? ti.4 1t.2 io.e t 0 - 9 11.2 10.5 lo.7 i o. 10.8 . _ l , CON~Cu-~cVRuM ~-.-~ ~PU L'! 1-60 253 214 !.2 135 !'~ !I~ 11,6 11-7' 1-2 132 13-I !'2 133 13.3' 'II.3 i.a 132 14.1.. 1-I lis 14.6 13.1. I.t 1~4 1.1 I~ _-!3-8 13.2 I.I 129 i3.2; I1.7 I.I 127 1~-2 11.1 1._t 127 13.1- 11.1 104 i.. ! 126 11.$ 9.9- 37 1.1 IMS- II.~ ' 9.T 133 1.1 !25 ti.4 9.7. 3~03. ~ 5-6 3Z05.~ 1~.5 3211.5 ~. ~ 357 I. 1 t t.I 1. 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T 13! I1.3 12.I 3~ - 2.7 ~36.3 . 2=8 233 2.1 t33 1G. 8 1!.7 ~: ~ ~40.:~ ::3~:.i 14 2-8 !~:: 10-4;;: !I-3- ~ { , ::3)~.I ~.3 31 3-0 i3~::: I:0~:6=~= :t1~6 ~ } .... :=.~7~1 ~ Z.~ 9~ 3. v: t3:~: ::10-7 :11~, 8 . . . ~Z5.9 l.Z 37 2.9 136 38 1~8 8.9 lO.O 40~9.~ 3.9 2.9 .. · .031.~ ~.9 ~9 t.9 ' 4 U.33. ~ 9.2 ~t9 2.9 1-36 4941.9 0.7 313 2.8 135 tO~.~ 1.6 lit Z.8 135 9-5- 10-8- 4~45. i I.~ ~ 2. a I~-5 ~ i. ~ N~ gOeR 2. S .~4 4B~. 8 2.8 13 .~ 136 4~89.7 0.6 ~ 2.7 13~ 9.2 9.'~.' * _ 4113'5 lO.O 3.11 ~"133.5 · ~.0 4t3S. S i.6 _ 4151.S Z.a '-~t~5. t ~.'~ ~-- ' 4!73. ~ 2.5 1 1.3 27 1.6 117 2-6 2°6 2.6 2°6 137 9.1 135 · 8.6 135 8.T 8.6 _ 137 8.7 ~ ~'~ ~- . - Z ~ . ,~ !39= : ~.~ 149 2.6 3.9 4 2.6 5.5 34 2.6 1.7 29 2.6 2.3 60 13'9 139 10.-4 I$0 10.5 141 9.9 1~2- 10.0 I12 lO.O 10.~ I0~0 9.9- C C C , Io$ 1.4 !.~ 33 z.a Z. 9 ' !. 5 144 tt.O 9.0 !4A lI.Z 9.1 16t lt.g a.? ' Itl !I.! ' 8'9~ 2.5 _ 2.5 ~0 i44 11.0 144 10.9 I44, t0o ii 1~3 144 1t.8. 11.2.. II.2 ~.7 · 145 ! 4-5 11. ! 1i,1 - _ ti~ 11.3 tt+? 8.7' 8.,,,,.'I 8,.,8 8.7 147 !2.:T: ::~ C ******************************--************* i ***************************************************************************** i~.a 2z~ 2.~ ~6 t7.0 l~l 2.7 i~2 -- 12.~ ~.~ ~ z-~ i~- ~z-. ~ ce~ ~.~ ~ ~.z'z _ i'I. T 35-0 2.7 1~t 12.4 0-~ 356. Z.7 t~t 12.3 8.8 92 2.7 t3~ - ~O COR~ 2 · 13~ 11-8 $. 9 8~ ~. ~ !36 4592.9 - .. 4517.0 5.5 2Z.9 6.~ 256 8.7 297 ~ 2 2~2 1.3 ~ COR~ 5.4 272 t2 2.9 2.9 2..9 2.9 2. 9 2.9 2.9 2.9 2.9 3.0 3.0 2.9 2.9 4,633.! ~0 gOeR _ _ ~ ~ . 4643.1 ~ t.~ 29 . ~ 4~4~ ~ i. 5 :3 3.0 ~ ~: ~551=1 2.4 19 134 11.6 9.1 134 11.5 8.9 C 134 11.8 10.0 B 135 12.0 10.I 1= ' it-.5 8.9 115 11.7 9. t- t~4 t1'0 9.! 133 11.1 8.9 IB2 I1.1 13! t!-~ i~Z 1!.4- 132 11.5 9.3 _ !32 Il.! 9.0' _ I~i 1i.5 9.1 131 I1.6 131 11.5 8.7 13i 1t,5 8.6. 139 11.~ 3.0 t30 11.4 129 tl.4 tZ9 11.4 t29 11.,5 129 11.6 129 tl.6 129 t. 29 11.3- 12'9 !30 11.4 -45$5. Z ~ 2.~ 1 ~.9 la7 11-.3 4703.3 4. a 18 Z.8 127 il.3- 4~07.~ i4. o 132 z. 9 i28 ~l.z 4~.t~.3 zI.5 i~3 z.9 ]2~ 11'3 <4717.] II.7 302 Z.~ !a~- 11.4' i~2i't - 11.0 129 2.8 I2~ 11.~' 4727. 3.2 104 2.9 !28 11.0 ~ ~- ~3.5 NO CO~R g.7 126 !0-5 9.0 ~ ~ _-4781.5 3.1 61 i. 5 itl 1~-t ~ :i 47~T.& - 3-I 15 2. i i-2i 10 i~- ~--~-B6i.5 ' 1.0 7I Z'4 123:~ ?---*- ~-~;~ ].i z-s~.~ t~ le~~-- -s.~-- ~ * ~ ~ .... ~4alI.-7 2..a 9 2.3 125 ~'- ~---4-8i3-.~ 2.5 il l.t Ii4-- {_ .. 481~.7 2.~ 31 2.4 i24 .10-4 8.~- i ~- - _' ~--_ _-_ ;[. - ' _ -_ - _ - DIP O~Y D~Y · _ ~ _. 1'04 2.4 I2~ 10.8 I17 2.3 i2~ 10~ i.3 124 2¢6 2.3 123 i0~5 _ . 1!2 2.~ 125 55 2.3 123IO.~ II1. 2.3 tZ3_. 10.6 ~ ~ .. 100 Z-3 125 IO'.D ********************************************************************* 1 ~.Q 7 2.3 6.0 352 a.3 13-0 ~.3 1 tO.i 3t8 2.3 -ts.~ ~l ~.~ 15.13!9~ 2.3 IgT-- 10.6 6.2 33~ 2.2 las--10-2- t~.l 352 2.3- t27 16.2 355 2.~ ~.~ ~ z,~ _ . . - - ~ ~ __5000..1 6-8 344 -2-1 Ii6 8.6. ~ ~ :.5~18-.I 11.7 30Z Z.I 1lO. : _ .-_ )--, .so46.1 i~.o z~' ~.i i'z~- ~.~-: ~. .~- 5056.1 13.8 310 2.1 123 . .... -. ~u,Z..l 5.1 14 1.9 !IT - 8-5.- lO.b- ~.--s,iz.~ ~.~ o l.~ ii~ ~.s_ ii.i. {~-.-'~:'Sl30. 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CN ~ COUOCO At, AS~ WN : ~ILN~ FN : MILNE POINT UNIT RANG: ~0~ TOWN: SECT: COI~N: N.SL~PE ST~T: CTRY: USa COMMENTS ** 000 000 016 065 .. 000 ·'000 004 065': 000 000 004 065 .... 000 000 002 065 000 000 0~8 0~5 000 000 006 065 000 000 004 065 LVP 010.~02 VERIFICATION bT,TING ' ' '"" .... '"PAGE t."' . ~' ' ' " ' ' ~: ' ' %': f ....... , SCHLLi~BERG~R , ALASKA CO~PUTING.CENTER ~ '-" . '" "~" *****************-*H*** j~B IS A ~ERGED PRODUCT OF RUNS 1 AND 2 ************************************************************** COMPANY = CONOCO CHEVRON WELL = MILNE PT. b-1 FIELD = MIbNE POINT UNIT COUNTY = NORTH SLOPE BOROUGH STATE = ALASKA JOB NU~BER AT ACC: 69127 RUN #2, DATE LOGGED: 8-APR-84 LDPI HGH CASING = 9 625" @ 2480' TYPE FLUID = D~SPERSED DENSITY = 10.~ LB~G VISCOSITY = 38.0 S PH ='10,0 FLUID LOSS =.:~,'.4.6'C3.'.:hi~.,; ~' BIT SIZE = 8.5" TO 0500' R~ = 1 490 ~ 70,0 DF R~F ~'~ = 1.~300 ~ 70,O.DF R~C : I 540 ~ 70.0 DF ~ RM AT BHT.:'!~;:'v'JI:',:i: ': ='0~585:':'~,':'189.0'.DF MATRIX SANDSTONE ******************************************************************************** ,)OB NUMBER AT ACC~ 69069 JVP 010,H02 VERIFICATION LISTING ~UM.#1., ~ATE LOGGED{ 21-MAR'1984 .,DP: S, MARSHALh 3ASING = 13,375" g 105" tYPE FLUID = GEL-BENEX )ENSITY : 9 5$bB/G ]ISCOSITY 56 :H = 10 ~L{.1ID LOSS = lq , . BIT SIZE ~ 12 25" TO 2500 ~ .'-" '?,' ~. RM ': RMF RMC RM AiT BHT ~ATRTX SANDSTONE ******************************************************************************** .."j'..,: ... ** D~T~ FO~M.AT RECOR~ ~NTRY BLOCKS TYPE SIZE ¢ 9 4 0 1 ,F,.P~ cnoz ~,T,~ CONFIDENTIAL INFORMATION 7] 60 Furnished By Conoco Inc. 66 0 ..... ,"!;Li.:',:.:r .....:: ,.. :,i~"' '. :.<": .:,. .' ' :':.' ;,':':'i':'> :":":J':: ':i~;.:':, "/.:~';'!,.'.!'.:~'.J.' :' :: ~NE~ S~VICE SERVICE UNIT API ~P~ APl ~PI:FZ[,E;.::.,SIZE..:"~ROCESS SA"PLE'. REPR'..":,"/...',::' ":' ":":"" DEPT / FTO 0 0'<':'""~ :.0 ' ',/.'. 0 .:',' ;~" ~.':',,: 4 .:~" ,.':<::" ..?,: "'0', :. '~ 1 '68 ' SFLU OIL/ OHMM 7 0 0 0 0 4 0 1 68 :: .'~:...:...'4 ."~':',:~;: :>:.'~.~'~ :~j ':' 0 .' ~.:"~ ?' .. ,:, 1 ':' "'<';~ .6~,',':~.::.~:~;.'~ 4 ' 0 .... . ~ ' 68 0 :: :"~'0 0 4 0 ~ 6 LVP '010.H02 URAN NGT POTA POTA VOL CGR NGT SGR NGT OEPT SP SP NCNb ~NRA POTA VERIFICATION LISTING'.=?!:: PpM 0 0 PPMi 0 0 PU 0 0 PU 0 0 ~API 0 0 GAPI 0 0 9507.0000 SFLU -68.0000 GR " -68.00n0 NPHI -999o2500 FCNL -999,250,0 SGR -999.2500 POTA DEPT 9500 0000 SFLU SP -79:~500 SP -79.2500 NPHI NCNL -11504 0000 FCNL ~NRA 9. i1836 SGR OTA -3 7598 POTA 9400 -9] 4375 3472.0000 1,6465 1..8066 9300.0000 -101.5000 -101.5000 3082.0000 1.0678 2.1973 9200.0000 -31.o000 -31.o000 3868.O0OO ? 7402 2:8809 ,. '2500 . soo ..99~2500 -999.2500 -999.2500 13.3359 88.2500 19,9219 '526fl,0000 oo ,0000 DEPT SP SP NCNL ~NDA DOTA OEPT SP NCNL RNRA DOTA DEDT NCNL RNDA POTA DEPT SP NCNb DNRA POTA DEPT ':~ :,~', SFt, U GR ,' ,1 ,~..:':' NPHI 13, FCNL:::;.':,::'..' .,',i:i':2.'I 08. SGR 65. 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' :": '.t ':,,/:::'.."::~..::.:~ ;.:.~...;::.:.:jj~.C...: <.. : ;..:" 1 5234 IbM 1,5859 90 RHOB 4512 81. 6250 GR 8 g: 8203': ': URAN'~",.:'~: l 9375 SGR 94 ,3828'.!'Jr'. ,9375 5 40':":!.,:~,::!/.>:::':/!:.i: ~';::;': ./':'" 4 '~ ':?;.:':.~:?<'.J:! 8 5O 2539 .5'/42 5059 i1611. 8125 ,9111 ,1250 ,4395 .6914 ,8066 ,5000 1738 I[,~ 2 9:6875 aR ,:. 8o 0.0713 RHOB 2 10.g219 NRAT "'~:'"~",' " 2 10 7969 URAN 84~1250 ~G~ 93 1.9668 IbM 1 103.3125 GR. 92 0.1040 RHOB 2 12.1406 NRAT 3 10,6719 UR~N 2 84.0625 SGR 107 LVP DEPT SP SP NCNb RNRA POTA DE. PT SP NCNb RNRA POTA DEPT SP SP NCNb RNRA POTA DEPT 8P NCNb RNRA POTA DEPT NCNL RNRA POTA DEPT SP SP NCNb POTA DEPT SP SP NCNb RNRA POTA OlO,H02 VERIFICATION" 8200.0000 SFbU -58.2500 ~R -58.2500 uPHI 2290 0000 NCNb 2~4297 SGR 2.4414 POTA 8100 0000 SFLU 26 : soo CR 3.2695 SGR 2,1.9.73 POTA 2,66~0 74,5625 24,1.699 DRHO 942,0000 CALl'""' 89,8125 THOR 0,0000 CGR lb,D.... ....... 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NCNb 2690.0000 FCNL RNRA 3.1289 SGR POTA 2.4902 POTA DEPT 5600 0000 ~P -45:7500 ~P -45 7500 NCN~ 2g04~0000 POTA 2, DEPT 550O 0000 sp 4~2oooo sp 24~.oooo NCNb 2~6~.0oo0 POTA 2.0508 DEDT 5400.no00 SP -65 2500: RNRA 4,0664 POTA 2.~367 DEPT 5300.~000 SP -66.0000 SP -66 0000 NCNb 2.446!0000 POTA DEPT 5200.00~0 SP -57.5000 SP -57.5000 ~{CNL 2602.~000 RNRA ~.3730 POTA 2.0996 '~' 2,2734 IbD IbM 91,3125 DT GR 34.8145 DRH0 RHOB ,59 00 CALI NRAT., , 115:~75 THOR URAN;:;'.?.',,i' 0.0000 CGR SGR ~02.5625 DT 97,4375 GR 35,~398 DRH0 .... 0,0479 RHOB 748.0000 CALl 10,5625 NRAT 118,5625 THOR ~""8.9766' URAN- 0,0000 CGR 91,J250 SGR 2.4551 ILO 2 4414 IbM 86,4375 DT 94:3750 GR ..... 34.619! DRHO 0,0073 RHOB 875,5000 CAb! q,7109 NRAT 95 8750 T~OR 9,0156 []RAN 0:0000 CGR 78,]i~5 SGR 2.2559 96 7500 0~0254 9 95.1250 10~,5625 .4590 · 3 ".:,' 118. . 2. ':'-86. 2, 9s~ 3 2676 2910 5625 SFLU 2,2363 Y'LD 2.1445 IbM 2 ~.~PHI , 500 DRHO , 234 RHOB FC~!L": .'( :.'<'":.: 6~0. 5000 CABI. :.?"i'ii::':'.?!i';:::?.:': 11.~ 703 NRAT "" " 3 SG~ 95.6250 THOR 8,35X6 bRaN POTA .... :: 0,0000 CGR -75,4~75 ~ SGR 95 SF[,,U" ' 1.8135 IbD '~ 1.7920 IBM ~R 8~.0625 DT . ~06.1875 GR NPHI ]6.9~4! DRHO'"" 0.0190 RHOB FCNB 692 0000 CALI ~.95~! NRAT SGR 92~7500 THOR 1~,0625 {.IRAN POTA 0.0000 CGR 75,9375 SG~ SF[,U 2 1270 ILO 2,1387 IbM GR 88:~250 DT 10~,'31~5 GR NPHI 37.7441 DRH0 0,0225 RHOB FCNL 771.0000 CALI 10,8437 NRAT SGR ].05,3125 THOR 11,4141 URAN POTA " 0,0000 CGR 78.81~5 SGR 4063 4375 ...',~ " 3691 1309' 1035 8750 2793 '" 125 945~ 4375 6953 3477; ....... 2969 ..... 1250 5000 4]75 7324: ' 4919 .6250 1,7783 89,0625 .3262 · .3691 2,0156 92,7500 2 0879 88:1250 2,3359 3,3867 105, 25 t,V P OlO.'H'02 VERIFICA TION LISTING PAGE 10 DEPT SP SP NCNb RNRA DOTA DEPT SP SP NCNb RNRA POTA 'DEPT SP SP NCNb ~NRA POTA OEPT Sp SP NCN[, RNRA DOTA DEPT SP NCNb RNRA POTA DEPT SP SP NCNb RNRA POTA SP SP NCNb' RNRA POTA DEPT SP SP NCNb' 5100.0000 -52.5000 -52.5000 2626.0000 3.1758 1.7578 5~00 0000 67:0000 -67.0000 2490.0000 3.0605 2.1484 ~4900.0000 -57 50O0 -57 5000 2340 0000 .] 6758 2,3926 4~00.0000 .54.2500 54.2500 2262.0000 3.8359 1.7578 4700.0000 -5J 5000 . -51.,5000 3, 4 2,44~4 4~00,o0o0 54.25o0 54. 2500 2 6 :oooo, 4,2187 2.1973 4500.00n0 -39.25o0 -39.2500 2210.0000 4.0859 1.5625 4400.0000 -42.00~0 -4~.0000 2428.0000 SFLU GR NPHI FCNL SGR POTA SFLU ~R NPHI NCNb SGR POTA GR NPHI FCNb SGR POTA SFLU GR NPHI FCND SGR POTA SFLU NPHI ~CNL SGR POTA SFLU GR NPHI FCNL SGR P(]TA SFLU GR NPHI FCNb SGR POmA SFLU C,R MPHI FCNL 2.3477 93.0625 32.8125 826.5000 93.1875 0.0000 3.0332 85.7500 34,912! 813.5000 100.9375 0.0000 1.9316 91.3750 39.5508 636 50O0 g4:]125 0.0000 °6°5 , 5625 2832 ', g: ooo 86.7500 0.0000 2.0313 84.6875 40.1855 6~2,5000 ~.9375 0.0000 1831.1 67:6875 46 8750 584~5000 87.4375 0.0000 1.fl896 69 3125 42:6270 540.5000 81,3125 0.0000 3.0352 94 4375 37i98~3 657 5000 ILO DT DRHO CAT, I THOR CGR ILO DT' DRHO CALl THOR CGR IbD '"' DT DRHO CALl THOR CGR ILO DT DRHO CALI THOR CGR ILO DT D R Fl 0 CALl THOR CGR T LD DT DRHO CALl THOR CGR DT DRHO CAbl THOR CGR DT DRHO CAt,, I 2 !02 0 10 11 77 2 100 0 8 .... 10 '75 1 108 0 10 8 73 2 111 0 1 77 2 115 0 11 q 78 ,6074 .8125 i0161 ,7500 ,6953 ,1250 ~.. .7246 .7500 ,0342 .8359 ,1562 ,0000 .9023 .0625 .0283 .5469 .9766 ,7500 .8740 .4375 0508 ~5469 .6563 .1250 .1035 ,8750 .0210 ,6094 .0078 ,0625 ,0547 .2500 ,0225 .3750 ,7500 .5625 2.1074 105.8125 0.0098 14.1953 9,8359 70,1875 ,, 3.1992 108.6875 0.0630 11.3984 IbM GR RHOB NRAT URAN SGR IBM GR RHOB NRAT URAN SGR GR RHOB NRAT URAN SGR ILM GR RHOB NRAT IIRAN SGR IbM GR RHOB NRAT URAN SGR IbM GR RHO8 NRAT URAN SGR I[,M GR RHOB NRAT URAN SGR IbM GR RHOB NRAT 2 93 2 3 1 93 2 .... .:' 85 2 · . ! 91 3 -.,. 94 85 2 0 86 2 84 2 3 1 92 1 67 2 ! 87 69 3 ! 81 3 "' 94 2 4082 :0625 ,3262 ,1113 ,g24B ,1875 ,7148 ,7500 ,2930 .0762 ,1113 ,g375 8008 ~3750 3262 ,462 ,3125 :~672 625 787 : 5oo .0430 .6875 .3242 .5391 .8984 ,9375 64 2422 ,9004 ~0 35 4175 .0117 3125 '2949 . ,7422 ,3330 ,3125 .0039 ,4375 .3770 ,4141 LVP 010.,H02 RNRA POTA VERIFICATION Sp NCNL ~N~A POTA 3.691.4 SGR 2.4902 POTA nEPT Sp NCNL POTA 4300.0000 SFI,U -42.2500 GR -42.~500 NPHI 210fl 0000 FCNL 4!0703 2 2949 POTA DEPT SP NCNL POTA 42O -3 -3 213 DEPT SP SP NCNL POTA 4100 -47 -47 2134 2 DEPT SP SP NCNL POTA 400 '4 DEPT SP NCNt, RNRA POTA DEPT SP SP RNRA POTA 3!oo 9] 93 155~ 1 1 OEPT SP 370 7 205 360 -10 LTSTING PAGE 11 .0000 SFLU 5000 OR .'5000 NPHI .0000 rCNG 8066 SGR '0996 POTA m 0000 SFLU ~0000 GR ~0000 ~!PHI 0000 FCNL i7324 SGR 0090 POTA 0000 SFLU :9500 GR :~00 NPHI O0 FCNb 1.84 SGR 102.2500 THOR 0.0000 CGR 2.2051 90 8750 DT 4424336 DRHO 517.5000 CALl 94.5695 THOR 0.0000 CGR 2.8145 77.9500 DT 42.8223 DRHO 560.5000 CALI 85.9375 THOR 0.0000 CGR ~.4297 ILD 6~ 3 DT 5 875 THOR 0 0000.: CGR . 5313 IGD. 8 .6875 DT . 8 554, '~CASI 8~,1250 THOR · .0000 CGR 9.6875 81.6250 2.3164 11~.2500 0.0342 10.5781 7.9531 .70.6875 .o6Os 112.8750 0.0503 "9.9687 ~ 875 2.0313 8125 11· '0405 3906 1 ~0156~ 60,8437 IIRAN SGR. 2.4727 I02,2500 .... 2.2090 .... ' " 90,8750 2,2734 ''' ...... 8613 .5625 -. ~ ,. 2.8672 77 2500 3 2 0078 85 9375 2 0508 ' ' ',.RHOB '.~ NRAT URAN ' ':"'~ ' IbM 'GA RHOB NRAT {.IRAN SGR IbM GR RHOB NRAT URAN SGR ,25~ 2,1855 GR.'.: '84. 0,0264 RHOB~ i875027 1 · 3594 ,.i.'NRAT/::!/':?;?':"::: ~ .... 410 8.~266 {.IRAN ',.'84 ~564 3. 875:V::SGR·~:!:i/' ...... ':/iC 1250 · 1543 DRHO 0000 FC~L 3{3,2500 CAL! 9531' ~G ;'!:/'! 46,0938'::...'THOR'.?..! 3184 POTA, :: . 0.0000 CGR nO00 $F[,U 3.638,7 It, D 5000 CR 46.'8125",DT ~000 ~PHI ~.8~11 DRHO 000 FCB]L 5 ..5 O0 ClI, I ~457 SGR 58.5938 THOR 2207 POTA 0.0000 0000 SFI.,U 2.4883 7500 GR 1,875 7500 NPHI ~1:9687 n000 FCNL 535 5000 8301 SGR ..... 77~2500 6602 POTA 0.0000 oooo r[,u 0000 C~R 47~ 5625 116.0386. RHOBL ' 16.8750 BIRAT "..I"4',902.3,.i URAN: 40,968~7 'SGR 2.0313 IbM : .:,125i6875 'O.OOlO RHOB 2 12.8203 NRAT 3 6 5820 {IRAN 46:0625 SGR '0430 :' .:,::':", '~':" ::~. 6602 2480 81'25"', 504 7188 ': 5039 58.5938 DRHO O.0146 ~HOB 2:25S9 CALl 12.5313 NRAT ~' .7168 THOR .... 7.1328-URAN ':~::' 2.5234 CGR 56.2187 SGR 77,2500 IUD 1.1260 TLM 1 5244 DT ............... 125.1875 GR ............ 47~5625 it;Vp, 010.-H02 SP ~NRA ~OTA ~P ~:~L "OTA O£PT Sp' RNRA.~. PO?A,; ~EPT SP ~P ~CNL POTA SP SP RNRA POTA DEPT SP SP NCNL RNRA POTA, DEPT SP SP NCNL RNRA DEPT SP SP KI C M [, RNDA DOTA. VERIFICATION· . b I S T :1: N G'"::::"i' ',?F:' ' ' ..... ;546. 3.q648 1 .0254 3500.0000 -74.25n0 -74.2500 276R.ooo0 3.4277 1.4160. 3400.0000 -5o.25oo ,5o,25o0 197o.ooo0 3,~828 1~7090 3100 0000 -49.2500 254~.0000 ' 4.0781 1.7090 3200 0000 '56i7500 -56 7500 2464 0000 3 3477 ~7090 3100.0000 i< -57.7500 -57.7500:' 2fi3~ 0000 ~..7090 . ., ,. NPHI, 40 ':" '!FCNL '":~":'"' ":" 642 SGR 53 POTA .... 0 GR NPHI. FCN6 POTA 4 42 35 807 51 0 .1855 .0000 ,75OO .0000 .3047 .5938 .5469 .5000 .7500 .0000 DRHO CALI THOR CGR' ! [,D DT DRHO CALI THOR CGR SFLU 2.6426 ~R ' 64.1875 DT . NPHI 45.3613 DRHO FCML''' ~ ":' 507,2500 CALI SGR 65 2500 THOR POTA ' ' ' 0~0000 CGR SFLU 5'7773 GR 58.8125 ,,PHI 44 9219 SG ' "6 8437 POTA, 0.0000 7.1719 52.0625 34 5703 .. 3 2ooOo 63.1562 0,0000 7.0078 5~.5938 391.1602 666 5000 ', 6'2:4375 . 0.000.0 8.1016 5~.4688 40.5273 649.5000 63.3438 0.0000 8.8047 56 4375 44~4824 587.5000 69.4375 0,0000 3ooo.oono -52.5ooo -52.5ooo 25o~.oooo 3.~516 1.8555 SFLU GR' . NPHI FCNL SGR POTA SFLU NPHI ~CNL POTA NPHI , WCN5 POTA SFI,U GR NPHI FCNb SGR POTA DT , DRHO CAI, I THOR CGR . . I bD DT THOR 'CGR ILD'. DT DRHO CA[,I THOR CGR I LD nT DRHO CALl THOR CGR II,D D T DRH0 CAI.I THOR CGR .60! 4,8398 34,4375 '3.4336 109,3125 -0.0098 11,7578 5.1523 43.5000 2.9238 113.5000 '-0.0049 12,8906 · 5,7266 52.6875 9 0234 115:06~5 -0.0049 484 56 078 ~ 000 9.4297 ,',123,4375 ,0020 ~7109 4.9648 52,5000 .9,~406 121,1250 -0.0039 10.8047 5,9922 .53.5625 9,7188 ~19.8750 -0,0029 11.0859 4.7656 51.0000 9,5156 ~36,5000 0.0654 10.5234 6.8047 64.3125 2900.0000 i55 7500 5s:vsoo 2350.0000 4.0000 1.8066 RHbB. '". ~ ,~ ,T N R A T "...:':" ,. {.IRAN SGR 5 ILM GR RHOB NRAT IJRAN SGR '12 2.1035 3.5391 2.~125 3. 500 42,5938 2,2246 3.2910 0.9878 51.7500 2'.78~3 64.1875 2.1406 3.8574 1,5088 65,2500' 8.0625 58 8125 2 1621 3 8125 1 2402 61 8437 7,9687 52,0625 2.1289 3,2363 1.2793 63.1'562 7,9727 5~,5938 2,1035 3.4629 1,0645 62,4375 8 6406 58i4688 2 0918 3.5449 1,4795 63,3438 8.1.250 56 4375 2!1.680 3 7363 0,6113 69,4375 ILM GR. PHOB NRAT URAN SGR 'IbM GR RHOB NRAT URAN' SGR: RHOB NRAT IIRAN SGR · IbM~ GR RHOB MRAT URAN SGR IbM RHOB NRAT ' URAN IbM GR RHOB NRAT URAN SGR LVP SP SP N£Nb RNRA POTA DEPT SP SP POTA SP SP NCNb RNRA POTA DEPT SP $P NCNb PC1TA DEPT SP $P RNRA POTA $P SP NCNb RNRA POTA 010.H02 VERIFICATION LISTING 2RO0 0000 SFI.U 6 -63.:7500 GR 66 -63.7500 NPHI 48 2170.0000 ~CNL 506 4,~813 SGR 74 2,4414 POTA 0 2700.0000 SFLU 4 -59,0000 GR 71 -59.0000 NPHI 51 1948.0000 FCNL 475 4.0977 SGR 74 1.5137 POTA 0 2600 2234 1 250~. 5~ 1670. 2400 -49 -71 1461. 4 1. 2~00. 4 9O -090 0000 SFLU. 6. 2500 ~R 44. 2500 NPHI 45. 0000 FCNL 523 ~695 ~207 ~OTA 0000 SFLU 5000 ~R 62: 5000 0000 FCN5 ....... 4~1. 0742 SGR '::",..' 72, 6602 POTA O, nooo SFLU 0000 GR ':':,<,::': 64 0000 NPHI 0000 0000 $FLU:..:.:::~':' 15 5000 GR 5J 2500 NPHI .": :~:':""999 P500 ~CNb -999 ~500 SGR -999 2500 POTA -999 DEPT 2~00 0000 srbu 14 p -99o ~500 ~PHI -q9q ~CNL -99~:2500 FCNL -~9~ RNRA -o9o. P5n0 SGR - ogq POTA -q99.2500 POTA '999 21.00 -42 -q99 -099 -q99 DEPT SP SP NCNb ~NRA OOOO SFI.,U 12 nooo ~R 53 ~500 NPHI -999 ~500 FCNL -99q 2500 SGR -999 .6133 .9375 DT 4375 DRHO 7500 CALl 5000 THOR 0000 CGR .9414 ILO ,~500 DT .3184 DRHO .0000 CALl .1875 ?HOR .0000 CGR 9531 lbo 7813 DT ~496 DRH0 0000 CAbI 313 THOR 000 CGR 6094 ~D 500 DT 254 "DRHO 0:' THOR 0000 CGR ,4063 ,0000 9375 2500 2500 2500 .2500 0234 3750 2500 .2500 2500 ~2500 2656 6250 ~500 2500 25O0 8.4688 138.0000 0.0049 10,4922 7,0547 70,5000 RHOB NRAT ....... URAN SGR'." 6,19t4 'IBM- "' ..' 146,2500 GR '" · 0;0547 ..... RHOB 1~.8750 NRAT ~7422 URAN 58.8125 SGR 9375 ..... :.,,:".' -.. 2,1543 3,9492:.,.,-...,.?,:,,.~,.., .. .0,4756 ~,:74.5000 .... - .... · "5 2969 · ,1816. 74.1875 :IL3 0879 8320 9.9219 ILM 7 144.8750 GR. ''.~.'."':::::'"44 ': 9297 NR~T' ":'' ~ 4 ~992 URAN 38:437 SGR 47 8.0391.' :IbM 1~ 664~ 53,5938 5GR 72 250 D~:'. :.~",.141..1875 DR~O ~HOS CALl ::":.'::::::,' :'8'8594 NR T' ::::::::::::::::::::::::::::: 3 TBOR 6,0156 UR~N 0 42.,875 '$GB ..,0 ::':',':::",44 ILD :.': 14,8750.:::::':I5M :':':: ..'14' 070] DT :.,~,141,12509 ~R 519375 DRHO 99,2500':'..:RHOB ...... .:'~9992500 CALl NRAT -999 2500 999,~500 THOR 2999.2500 URAN -999 ~500 CGR -999,2500 SGR -999 500 ~LD 16.7344 IbM 15,9609 DT " ~53.0000 GR 25,3750 DRHD -q99,2500 EHOB -999,2500 CALI -999,2500 NRAT -999,2500 THDR 999 2500 ,.IRAN -999 2500 CGR 2999;2500 SGR -999~2500 IbD' 17,8437 ILM 15 ~750 DT 146,7500 GR 53:-250 DRHO 999~2500 RHOB cAI, I :999.~500 NRAT -999.~500 THOR ''999,2500 URAN ......... <:'999, 500' 1, . '::': .?. ".. ::-~'.', i":" ':' .'.' ..' :. '.i<,:;77 "": :t:(: :>':%".':~'";. : ..': ': ~A -999 2500 POTA -999,2500 CGR -999,2500~. 8~G~ , '~, ~,' -~9,~500 2:000 , oo ,,,,., ,o 50 ~A -q99,2500 POTA. 500':' '" ......... . .. ' &i' :.'.' ~T ~00 0000 ,SFhU ' 24.9844 .IGD 3~.,'.20~ 9.2500 '' ~ P ~ I ~ :::: ~:::::~ .' '- 999 ~ 2500 ' D R ~10 :~,: 'b 999 ;' :,250"0::'/,:::~':¢~.'..: R'H '0 ~:::~;:~J~g~::':~:9:9' 9' :'::'~'~;::::'~'~ ~:: :~: :~:i:'~.~:;~ ',:~ '.:~'.~ <:~:;,¢: ~, ~'~: :. ~.:. ' ~'~. :~,: ..':,":. :....': ~' ""., ~ ',..,, ~.. ~L 999.2500 . FCNh -999..2500 CALl ,-999.2500 , NRAT . .~999 ,2.500..,~.~.,~,.¢~:,~t~,.~..:,.,,~.,~.,..~,~, .............. ...... ~ ......... :,.,., ,+ ,,, : ',: ,: u.,:;:',<,.,:,:.,j'::r~: ?;<;:s,~".3:<~/~'; ~x~..~.:...~.k.;...v~.~:..~5~.[;5~%~?~i:~¢::~)¢;.:~%::~x:`.~;*~. ?,~,' ,,",' ,, -)7 0000 GR . 67:).875 .8~1406 GIbM ...... , ','~.~ ,' 287 1.406 ~ ~ ........ . 099,2500 )IPRI · -99q., 2500.. DRHO ~999,2500 RHOB -999 ~[, - 999. 2500 FCNL. -999 ~' 2500'':~ :CALl .9' 9.9 i '25 0 .... 0:' N R "~;':': '~:*:'A.T. :~' *?~ ,,::,,.,,~')i~,~ '""*'~'~"'~'"' ":.~,,,~;:.:~ > '.. 999 RA '999.2500. SGR '999,2500 THOR '099,2500 'URAN '999 .." ~A '990,2500 POTA ' ~999:,,~ "' :':.:'~ . , , . , : .~ ~¢"~ .', ', .... ~,~¢~ ~,"",~ ~7% ,;, ~' "~,~ ':%',", ~," ~ ~,,rxt~,' '~ ..... ~ 't7',~,' ',,*.'~, '~',' , '~ ..... ' .....'. ' r '~" ' -39 0938 GR , 61,~8~ DT , ~35,3750. GR. 61,~875.,' gL -99~.2500 FCNL -999.2500 CALI -999,2500 NRAT ' -999.2500 , ' ' . . T H O R: 999,250 .U R A 999:.,~ 25:0:0 gA -99~.2500 SGR -999',2500 ' ' ' " :" ':"~'~"": ' ..... ""' ......:"" '~ '" ~A -999 2500 POTA -999.2500 CGR -999,2500 SGR -999,'259~9 . , ,~ ,, ' , ~ ...... '" ":'. :' ;:::~',~,t:~: .',,,.~ ~ ',.~ ~;.~, 2",~:<~'~ ,,~:~:i:, : ' '. ": ~':'?' .~:)~;:':'~3~{'~¢i¢~(::;~;~;?;~:¢)::4;77~i:??~,:': '. "('~: .'": .~: ~.~:;~:~f`::~;:~;~:.~;~.:~.~:~;i~.;:~..:~:~:`}.`~"~;~:.:`~;~:~i~ PT 1600.0000 SF~,U 10,2344 II,D li.8984 IbM .'~ ~ 1.. 4609 -44.5938 .OR 66.0000 ~ ...... ' "~ ..... ' -~99 2500 ~.IPHI e~ 2500 DRHO -999.~500 , RHOB , ' -999,2500 ' ~ [, - 99 ~ 2500 F C N h. '20 ~ 2500 C ~ 51 .... - g 99.2500 ~?:~':SN R A 999 i'~ 50:0 ;:'. ': ..... :~' ..... '" PA -099.2500 SGR -999.2500 THOR -q99.2500 URAN -999.,2500 rh -O99.2500 POTA' ~::." ;'.: '-999 2500 CGR.. -9.99. '999.250 ....... '~; :':'"' ~' ' PT 1500 0000 SFLU' 1039.0000 ILD'~ 2000,00'00";:~'~.'I ..... ~'""~'"*" ~ n""? ..... '"'"":~ ...... ~ ........... -59.5938. ~R 43 ~437 DT 81,1250 GR · 43.~ -099 ~500 ~IPHI -09q~2500 DRHO -999' 2500" R}IOB ...:::;'.::':~ -999 250~ : Nb -09q.2500 FCNL -999.~500 CAY, I -999~2500 NRAT ,:, -999~250 RA -999.2500 SGR -999,2500 THOR -999,2500 · IJRAN..;};~!'~:~:]~.]".,.-999~ 2500 : '" ":'..' TA -999,2500 POTA -99 .9,2500 CGR -999,2500 SGR '. ' -999,2500 . · PT 1-41'5938 GR 88.9375 DT 142 8750' GR ..... 8 9375 ...... ' -99q,2500 NPHI -999.2500 DRHO -999:2500 RHOB -999u: 2500 ~IL -999.~500 FCNL -99q..~500. CALI -999,2500 NRAT -999,2500 :,r. ,.- ~A -990.2500 SGR -999.2500 THOR -999,2500 [IRAN '999,2500 TA -999. 2500 POTA -999,2500 CGR -999,2500 SGR -999,2500 '" PT 1100,0000 SFLU 41,5625 iDB 44,7813 ILM ' ~'36,7188 '" .... .'. -45.2500 GR 76.5625 DT ~16.2500 GR 76.5625 -999,2500 NPNI -999.2500 DRHO -999.2500 RHOB .... :"'-999,2500 , ', ' . ; VP 010,H02 VERIFICATION.'~BIBTING CNL -999.~500 FCN5 NRA -999,, 500 SGR OTA -999.2500 POTA EPT 1200 P -45 p -999 CN5 -999 NRA -999 OTA -999 EPT P P CN L NRA OTA EPT P P CNL NRA OTA EPT P P C~b NRA 'OTA ,EPT ;P ~CNI, 'OTA )EPT ;P ;P ~'CNL ~NRA ~OTA ~EPT ~P ~CNL ~NRA 3OTA )EPT 2500 CAI, I o99.~:2500 THOR oooo o , 00'DT ~50~ NPHI , :990.2500 DRHO .,50' FCNB~':" ''i 999.2500 CALl -099,2500 .NR~T -999,2500 SGR -999, 87 ~375 ILM 41 94 ~ o250 ':: i: GR ' .: ' :.' /<':;<;: ": 44 -999,~500 RHOB -gog '999, :500 '::NRAT :" :'J'-999 2999,]500 URA" 2999 :i999. 50rO ':SGR'.:' '~' '999 ".,"?,/'..':.J/'!?'::,.': .: '~:';.!'?~.(~%:;~:!.;.::i~: ::}:.~.i:,:,:...:<" ,:.;.',:.' <:'.':~"'. '.'.: '!, :." :" ' ~:' :~..': ?/'. >.:~:'~:,:~;~ :::;'~P A G E':' .'.'7%15 ~:;~.~;...: ....~',....'.. ,< .... .... ~,,.~....... .... 500 500 ........... 2500 9687 5000 ° 1100,0000 SFLU 35 6250 ~LD: :':!:;:'"?.:;.?:?/ '41,9375 ISM 28 . ,1250 GR '60 ~. ~R ' 63:3750 DT . .,18 6~ ,2500' RHOB ' 99 -099.., NPHI : .'"" -999.2500 CALI .999.2500 NRAT 999 DRHO :. i'~999 9 2999:2500 -099,2500 POTA -999,2500 CG~ -999.2500 SGR -999 .., ,~500 RHOB -999 ~500 -090 2500 NPH[ :999,2500 DRHO -999 500.).IRAT ,999 2500 -099.2500 .FCNb ~.999.2500 -999,~500 ~GR -99~,2500 THOR -999,2500 URAN -999 2500 -999,2500''~/POTA ,..--999 2500 900.0000 :"'"' 4,656'3 8 5 -77..,56~5 UR 58, 7 DT . 151 3750 GR 58,1815 -099.2500 NPHI ' :.:'999r, 500 :'DRHO .' '999:2500 -999.2500 SGR '"999,. 00: THOR .... i'""999. 500 URAN':.;:i/'/? 9 ,25.00' . .9 , 5o0 . 75 DT -P99.2500 DRHO -999.2500 CALl -099.~500 THOR -999.2500 CGR 13.1016 TLD 32.3750 DT -999.2500 DRHO -O99.~500 CALI -999.2500 THOR -999.2500 CGR 3.8516 ILO 57.9687 DT -999.~500 DRHO -999.~500 CALl -999.2500 THOR -999.~500 CGR 30.8750 ILO 800.00o0 SFLU -87.5000 UR -090.~500 NPHI -999.2500 FCNB -090.2500 SGR -090.2500 P(3TA 700.0000 KFLU -83.ob25 GR -090.~500 NPNI -o99.2500 FCNL -99g.2500 SGR -099.2500 POTA 37 IBM 99.2500 NRAT -09g,2500 URAN '999~500 375 '999 2500 '999 2500 '999 2500 '999 ~500 14.3047 IBM 9 110.8750 GR 32 -999.2500 RHOB -999 -999.2500 N~AT -999 -999.2500 IIRAN - -999 -999.2500 SGR -999 5.3633 ILN 140.8750 GR -999.2500 PHOB -999.2500 NRAT -q99.2500 URAN -999.~500 SGR '~'.' 52.6875 IbM 4219 ~5 2500 250O 5078 3750 2500 2500 2500 2500 4.0430 57'9687 ]999.2500 999,2500 -999,2500 -999,~500' 60o.00n0 SFLU -60.5675 GR -990.2500 NP~I -o90.2500 FCNB -o90.2500 SGR -~90.2500 POTA 500.0000 SFLU 23,0000 LVP 010.H02 VERIFICATION LISTING SP SP NCNL DEPT SP SP NCNL ~NRA POTA DEPT SP SP NCNL RNRA POTA DEPT SP SP RNRA POTA DEPT Sp SP PNRA POTA OEPT q ~'~ . .. RNRA POTA -9 -9 -9 -9 -9 -9 -9 -9 -9 -9 ,,9 -9 -q -9 -q 85.5000 GR 99.2500 NPHI 99.2500 FC~L 99.2500' SGR 99.2500 POTA O0 00o0 SFhU 80i4375 GR 99 ~500 HPHI 99.2500 FCNL 99.2500 SGR 99,2500 POTA 00.0000 SFBU 92.O000 (JR 90.~500 NPHI 99.2500 FCND 99.2500 8GR 99.2500 POTA oo oooo SF[,U 06:5625 99.2500 NPHI 99.2500 FCNL 99.2500 99.2500 POTA 00 0000 8FI.U 2~[7188 QR 99.2500 NPHI 99.2500 FCML 99.2500 SGR 99.2500 POTA 79.5000 SFI.U 21.1875 GR 99.~500 NPHI 99.2500 FCNL 99.2500 99.2500 POTA 31,~500 -999,2500 -999,2500 -999,2500 -999.2500 12',~875 41.4375 -999.2500 -999.2500 -999.2500 -999.2500 62.9062 ~3.7969 -999.2500 -999.~5o0 -999.~500 -99q.2500 8 5625 ' '45:06~5 -999.7500 -999.~500 -999.2500 1.6084 14.~953 -999.2500 -999.2500 -999.~500 -999.~500 1.6143 2o.q531 -999.~500 -999.2500 -999.~500 -999.2500 DT DRHO CALl THOR CGR DT DRNO CALI THOR CGR ILD DT DRHO CALl T H 0 R CGR I PT DRHO CALl THOR CGR D T DRHO CALl THOR CGR DT DRNO CALI THnR CGR .001 ln24 105.8750 -999.~500 -999,2500 -999,2500 -999.~500 , 18.0938 '114.5000 -999.2500 -999.2500 -999.2500 -999.2500 , ,, R H OB, "T'':''~ NRAT UR AN ":: SGR I LN GR RHOB NRAT URAN SGR 75.8125 66.8750 GR -999.2500 RHOB -999,2500 ~RAT -999.~500 URAN -999.2500 10.9062 117.6250 GR -999.2500 RHOB -999.2500 NRAT -999.2500 URAN -999.2500 SGR 2000.0(:)00 TLM 56.9375 GR -999.2500 RHOB -999.2500 ~IRAT -999,2500 URAN -999,2500 SGR 78.6875 56.8125 GR -999.2500 RHOB -999.2500 ~RAT -999.~500 URAN -999.2500 SGR 1.6 31 2500 -999:2500 999 2500 - . '999,.2500 ":, :::" 10,6484 ,~. 41 4375 -999:2500 -999.2500 -999.2500 -999.2500 28,71~8 23,7969 -999.2500 -999,2500 -999,2500 -999,2500 8.1172 45,0625 -999,2500 '-999.2500 :999 2500 999:2500 24.3281 14,~953 -999,2500 -999,2500 -999,2500 -999,2500 22.~562 20,953! -999,2500 -999.2500 -999.2500 -999.2500 ,VP OI'O.H0~ VERIFICATIOM LISTIMG ~ERVICF. MA~E :EDIT ~ATE :~4/04/23 ~RIGIN :0000 ~ "~ ~APE NAME , :91~7 IEXT TAPE.MA~E ~ :OMMENTS :LIBRA Y 'TAPE REEL TRAIE.,ER ** ;ERVICE [)AME :EDIT tATE :84104123 )RIGTN : ~EEL NI~ME :REEL ID, . . ~0MT~NUATIOM # ~EXT REEf, ~.~A~E ~ ~OMMENTS :LIMRARY TAPE ********** EOF'********** ********** EOF:"*.*********
