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Home My WebLink About188-139 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Well Icr,5.aL D.S. 07 -03A JOj -1'I:fK-10B f1/;;-o!1 D.S. 02-15A Î'17*225- D.S. 18-13A Î ~.l'/{_G-12B :£_ ;¿z {--D.S. 05-26A ,; v'9 -', \ Lf-15-04A 7tf5-a3ð 18-02A "7"'/_O~I....t'18-04B n5;{>sØ L 1-01 ('j8-i':R-L5-17 /'.'') .,. /'1H-18 . !> ~ * -l' 2-62/0-17 1.8,. ~_/t8.'-L5-15 .~ L5-15 _~q; L5-15 \ L5-15 ¡'¡()-{)llfj 'E-17 ~tð- rYi - G-15A Job # 10715406 10715402 10715404 10715395 10715391 10715420 10715374 10621764 10708056 10913000 10900124 10703975 10900129 10708050 10563129 10672368 10913848 10703983 10679055 MCNL MCNL MCNL MCNL MCNL MCNL MCNL RST RST USIT USIT RST RST RST RST RST RST RST RST SCANNED JUN 1 7 2005 Log Description Date 06/03/04 05/16/04 05/18/04 04/16/04 03/21/04 08/19/04 01/14/04 02/23/04 03/05/04 12/25/04 11/30/04 02/17/04 12/24/04 02/07/04 11/15/03 04/16/04 09/26/04 04/09/04 02/02/04 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: .~v t ~ Blueline I '/'$ -- / 3 'T 02/28/05 NO. 3354 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints .-- CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ~/ ~' 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 J Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99Z03-238 . .. I ATIN: Beth - // J Receive~ dr4.-- Uð..ú.-..a-- rr U STATE OF ALASKA ALASK IL AND GAS CONSERVATION COMMSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑ OiI ❑ Gas ❑ Plugged El Abandoned ❑ Suspended ❑ WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 El Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WDSPL No. of Completions Zero Other ❑ Stratigraphic ❑ Service 2. Operator Name: 5. Date o p., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. ,2. it /2004 188 -139 304 -397 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519 -6612 01/08/1989 50- 029 - 21889 -00 -00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 01/23/1989 PBU L5 - 1823' NSL, 155' WEL, SEC. 02, T11N, R15E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2016' NSL, 5015' WEL, SEC. 02, T11N, R15E, UM 55' Prudhoe Bay Field / Lisburne Pool Total Depth: 9. Plug Back Depth (MD +TVD) 2014' NSL, 45' WEL, SEC. 03, T11N, R15E, UM 11050 + 9184 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x- 71727__ 1 y- 5974950 Zone- ASP4 11142 + 9224 Ft ADL 028320 SSSV set 17. Land Use Permit: 11. Depth where SS TPI: x- 712408 y- 5975004 Zone- ASP4 p N/A MD Total Depth: x- 712098 Y 5974994 Zone- ASP4 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey ❑ Yes ® No N/A MSL 1900' (Approx.) 21. Logs Run: DIL / NGT / SP, LBT / CNL / GR, GCT, CL / GR / CNL / CBT / CET 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H -40 Surface 115' Surface 115' 30" 2150# Poleset 10 -3/4" 45.5# _ J -55 Surface 4250' Surface 4089' 13-1/2" 1600 sx AS III, 350 sx 'G', Top Job: 150 sx AS I 7 -5/8" 29.7# L -80 Surface 10480' Surface 8688' 9 -7/8" 325 sx Class 'G' 5 -1/2" 17# L -80 10293' 11140' 8546' ' 9223' 6 -3/4" 150 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none "): SIZE DEPTH SET (MD) PACKER SET (MD) None None MD TVD MD TVD 25. ACID, FRACTURE, CEMENT'SOUEEZE, ETC. WY,: t` L „4,•.� J DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10817' P &A w/ 9 Bbls Class 'G', Followed by 20 more Bbls 10765' Set 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 GAS -OIL RATIO TEST PERIOD 4 Flow Tubing Casing Pressure CALCULATED OIL -BBL GAS-MCF WATER -BBL OIL GRAVITY -API (CORR) Press. 24 -HOUR RAT 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach e ft \iy Dary). Submit core chips; if none, state "none ". �� L. None JAN 1 8 2005 RBDMS FEB 15 20.1"'F'41- Alaska oil & Gas Cons. Commission Anchorage 6F- Form 10 -407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. ) GEOLOGIC MARKERS 29. ') FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Wahoo Zone 6 10603' 8783' None Top Wahoo Zone 5 Top Wahoo Zone 4 10759' 8908' 10877' 9003' Top Wahoo Zone 3 11105' 9193' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Tenie Hubble ~AAiR ~ Title Technical Assistant Date 0 ( . [7 ..f1 C; PBU L5-17 188-139 304-397 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Ted Stagg, 564-4694 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 1a: 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. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits {ex: 50-029-20123-00-00}. ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: 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 12/2003 Submit Original Only ') ') Well: Field: API: Permit: L5-17 A Prudhoe Bay Field 50-029-21889-01-00 204-223 Accept: Spud: Release: Rig: 11/22/04 12/05/04 12/15/04 Nordic #2 PRE-RIG WORK 11/13/04 PERFORM WEEKLY BOP TEST. MU 1.75 BDJSN. BURP IA AND LIQUID PACK IA. KILL WELL W/5 BBLS 60/60,175 BBLS 1% KCL. FOLLOW KCL W/CRUDE TO GAIN POSITIVE WHP WHILE RIH. 11/14/04 TAG TD AT 10910' AND CORRECT TO 10924'. CHECK WELLHEAD PRESSURES, CORRECT FOR FLUID DENSITIES, AND BACKSIDE APPEARS TO HAVE SOME GAS IN IT. CIRC BOTTOMS UP AND GET SOME GAS BACK TO TANKS. SD AND CHECK PRESSURES, STILL HAVE UNBALANCE BETWEEN WHP AND CT PRESSURE. CHECK ALL GAUGES AND PUMP FINAL KILL DOWN COIL AND BACKSIDE SIMULTANEOUSLY. SD AND MONITOR WELL. ALL GAS IS OUT OF WELL AND WHP IS BALANCED WITH CT PRESSURE. HOWEVER RESERVOIR APPEARS TO BE CHARGED UP. RIH TO FLAG AND PERFORM INJECTIVITY TEST. HAD POSITIVE WHP BUT DID NOT SEE SIGNIFICANT INCREASE IN SIWHP TO PERMIT A SQUEEZE. LOAD BACKSIDE W/CRUDE AND REPEAT. PUMP 5 BBLS 15.8 CLASS G AND 4 BBLS 15.8 WI 12 PPB AGGREGATE, DID NOT ACHIEVE BUMP IN WHP THROUGH SEVERAL HESITATIONS. RIH AND TAG TD AT 10873'. MIX UP SECOND BATCH OF CEMENT. WEATHER DETERIORATING. WINDS TO 58 MPH, PHASE 2 CONDITIONS. POOH AND SECURE WELL UNTIL WEATHER DIES DOWN. MADE FINAL WIND READING - STEADY 50 MPH, GUSTS PEGGING METER OUT (70+ MPH). 11/16/04 RIH AND CORRECT TO PREVIOUS BLUE FLAG AT 10864'. CIRCULATE BOTTOMS UP WITH 1% XSLK KCL. PUMP 53 BBL DEAD CRUDE TO UNDERBALANCE. LAY IN 4 BBLS 15.8 PPG CLASS "G" CEMENT AND 4 BBLS 15.8 CLASS "G" CEMENT WITH 12 PPB AGGREGRATE. ESTIMATE 2.5 BBL BEHIND PIPE. HESTITATE SQUEEZE. AFTER SEVERAL BUMPS WERE ABLE TO HOLD 485 PSI OVER INITIAL STARTING PRESSURE. RBIH TO 10449' TO ENSURE TT WAS CLEAR. DID NOT RIH TO TAG CEMENT. FP COIL AND POOH WHILE FREEZE PROTECTING TUBING DOWN BACKSIDE W/24 BBLS 60/40 METH. AT SURFACE, RAMP UP TO 1150 PSI. LOST 23 PSI IN 10 MINUTES. BLEED DOWN AND TRAP 850 PSI ON WELL, HOLDING TIGHT. ESTIMATED TOC IS 10,675'. START RIGGING DOWN. CONTACT OPERATOR AND EOC WITH WELL STATUS, MAKE UP FREEZE PROTECT TAG FOR TREE. 11/19/04 RAN 1.90 CENT,TEL,S.B. SAT DOWN @ 10,201 SLM. REC. CEMENT. BAILED WITH 1.75 BAILER FROM 10,201 SLM TO 10288 SLM. 11/21/04 CONTINUED BAILING CEMENT FROM CATCHER SUB. 11/22/04 MADE ONE TRIP WITH 1.75 PUMP BAILER TO 10139 SLM. RAN 3.5 GR TO 10152 SLM LATCHED AND PULLED WHIDDON CATCHER SUB. ') ') Page 1 ~ BP Operations Summary Report I RREL from 1 D-11 @ 2100 hrs I Move off well and set down parallel to well row. Do final II cleanup and checks. Warm up moving system Safety mtg re: rig move i Drive down 1 D Pad and enter Spine at 2330 hrs. Begin move i to Lisburne I Standby at MPU turnoff while WO GPB Security I Move from MPU turnoff to just past the East Security I Checkpoint with stops for crew changes at Z -Pad and DS 14 ! Move from East Security Checkpoint to L5 Pad and set down Ion Pad I WO well and Pad prep. Spot camp. Little Red displaced IA ! and tbg to kcl water. ! Remove well house & flow line. Inspect pad with DSO. I WO TS to shoot grade and level Pad' I Phz 1 PRE Jack up rig and move down Pad and level up over well DECaMP I Accept rig for operations at 2100 hrs 11/22/04 I Prespud/operations mtg re: scope, status, pitfallls DECaMP I Rig up to circ. Load pits wI 290 bbls hot SW I Spot cuttings box, TL shack, power to camp I DSM open SSV, then pull BPV DECaMP I RDMO DSM I Fill mud pumps and lines wI SW and PT (did extensive maint i on move) DECaMP I Revese circ IA to tubing wI SW and taking diesel FP outside. Pump at initial 8 bpm w/ both pumps, but had problem wI belt guard on #1 and had to SD to fix. Rev circ at 5 bpm/500 psi DSM RU tiger tank and hardline DECaMP Circ down tbg wI returns thru IA with hot SW wI both pumps 8 bpm/400 psi while wo FMC SD pump, check for balance Install two way check. FMC hand on location to assist. Hold PJSM. NO tree. Remove from cellar. Hold PJSM. NU 13-5/S" BOPS on wellhead. Crew chg. Hold PJSM and continue to N/U 13-5/8" BOP stack. Install riser. Hook-up choke/killlines and hyd control lines. DECaMP Finish NU 13-5/8" BOP stack. DECaMP Notify AOGCC. Pressure test BOP stack 350psi low 3500psi high. Load pipe shed with 15.5# DP DECOMP Finished BOP test Held PJSM with creww on way forward Checked annulus, Pressure was seen. DECaMP Blow down surface lines and install 31 ft landing jt with 9" LH acme threads. RU to circulate long way through BPV. DECaMP Circulate at 1.5 bpm 1S0 psi through BPV. Vp = 315 bbl Loaded pipe shed with 110 jts DP and prep. 153 jts in pipe shed DECaMP SO pumps, checked flow, OK, SI casing valve, rig up and PT choke line to 3500 psi. DECaMP PU Lubricator and RU to pull BPV Pull BPV and layout tools DECOMP Screwed into hanger, PU, pulled out hanger at SOk and pulled Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-17 WORKOVER NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 11/20/2004 21 :00 - 23:00 2.00 MOB P 23:00 - 23: 15 0.25 MOB P 23: 15 - 00:00 0.75 MOB P 11/21/2004 00:00 - 01 :00 1.00 MOB P 01 :00 - 00:00 23.00 MOB P 11/22/2004 00:00 - 05:30 5.50 MOB P 05:30 - 13:00 7.50 MOB P 13:00 - 16:00 3.00 MOB P 16:00 - 20:00 4.00 MOB P 20:00 - 21 :00 1.00 MOB P 21 :00 - 21 :30 0.50 WHSUR P 21 :30 - 00:00 2.50 WHSUR P 11/23/2004 00:00 - 01 :45 1.75 WHSUR P 01 :45 - 03:30 1.75 WHSUR P PRE PRE PRE PRE PRE PRE PRE PRE PRE 03:30 - 05:50 2.33 WHSUR P 05:50 - 06:30 0.67 WHSUR P 06:30 - 07:30 1.00 WHSUR P 07:30 - 09:30 2.00 WHSUR P 09:30 . 18:00 8.50 WHSUR P 18:00 - 00:00 6.00 WHSUR P 11/24/2004 00:00 - 00: 15 0.25 WHSUR P 00:15 - 06:00 5.75 WHSUR P 06:00 - 07:00 1.00 WHSUR P 07:00 - 08:00 1.00 WHSUR P Os:oo - 11 :30 3.50 WHSUR P 11 :30 - 13:00 1.50 WHSUR P 13:00 - 14:30 1.50 WHSUR P 14:30 - 15:30 1.00 PULL P DECOMP DECOMP DECOMP DECaMP DECaMP Start: 11/22/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/5/2005 Description of Operations Printed: 12/1612004 4:01:31 PM ) ') BP Operations Summary Report Page 2. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-1 7 L5-1 7 WORKOVER NORDIC CALISTA NORDIC 2 Start: 11/22/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/5/2005 Date From - To Hours Task Code NPT Phase Description of Operations ---~- 11/24/2004 114:30 - 15:30 I 1.00 PULL P DECOMP up to 140k, no movement Pulled up to 140-145 k 6 times with no movement. FP at 9418 ft, close to GLM # 4, where we are circulating I through 115:30 - 18:00 2.50 PULL P DECOMP Wait on Eline unit to chem cut 3-1/2" tubing. Circulating and 118:00 - 18:50 loading pipe shed with more DP 0.83 PULL P DECOMP MIRU SLB Eline 118:50 - 19:10 0.33 PULL P DECOMP PJSM with all crews. Review plan forward for handling SLB cutting tools. ¡ 19:10 - 20:00 0.83 PULL P DECOMP RU E-line sheave, entry sub and pack-off. Pull to 120k and set 120:00 - 00:00 I slips. P/U 2-12gr string shot charges. 4.00 PULL P DECOMP RIH with string shot tag at 10040' area. Attempt again after tie-in at GLM #4. Tag at 10050'. TOH unable to work past I SSSV at 2124'. Pump at 5bpm to keep SSSV open and pull I I through with string shot after numerous attempts. UD SS and P/U chemical cutter. 11/25/2004 00:00 - 03:30 3.50 PULL P DECOMP RIH with chemical cutter. Still unable to get past 10050' and cut ! at our 1st choise depth at +/- 10228' just seal assembly. Pull up to middle of 1 st full tbg joint above GLM #4. Make cut at 9484'. I Good indication at surface that cut was made. TOH. RD SWS i 03:30 - 06:00 2.50 PULL P DECOMP Pull tbg hanger assembly to surface and UD. Start UD of I 3-1/2" tbg. I 106:00 - 15:30 9.50 PULL P DECOMP LD 3-1/2" Tubing and misc jewerly I Unloaded 4-3/4" DC ad fishing tools I Lay down 45 jts and then unloading pipe shed Recovered 296 jts tubing 1-17.13 ft cut off pup 1 SSSV and CIM 3-Merla GLM with 10ft PJ's 74 band and all control lines Cutoff jt is 17.03 ft 15:30 - 18:20 2.83 PULL P DECOMP Cleaned floor, brought in 124-3/4" DC and 103-1/2. HWDP Tailed and 00 & 10 cleaned out. Loaded pipe shed with BOT fishing tools 18:20 - 18:30 0.17 PULL P DECOMP PJSM review BHA handling precautions. 18:30 - 21:45 3.25 PULL P DECOMP P/U BHA #1 (708.05') 21 :45 - 00:00 2.25 PULL P DECOMP Bring remaining 3-1/2" 13.3# DP into pipe shed and tally. Make-up kelly. 11/26/2004 00:00 - 01 :30 1.50 PULL P DECOMP Continue loading pipe shed with remaining 13.3# DP. 01 :30 - 06:00 4.50 PULL P DECOMP P/U 3-1/2" 13.3# and 15.5# S-135 DP 06:00 - 06:15 0.25 PULL P DECOMP TL meeting in Doghouse 06: 15 - 08:00 1.75 PULL P DECOMP PU 3-1/2" DP 13.3 15.5 #/ft 08:00 - 09:00 1.00 PULL P DECOMP SO. PJSM on removing spools and choke panel with Crane 09:00 - 11 :50 2.83 PULL P DECOMP PU 3-1/2" 15.5 #/ft S-135 DP 11 :50 - 13:00 1.17 PULL P DECOMP PU kelly and circulated bottoms up. 323 bbls 13:00 - 13:30 0.50 PULL P DECOMP RIH with rotary and tagged top of fish at 9484 ft, 38.5 ft kelly in on jts # 288 Set OS, PU to 190k ,60 k over. No movement. PU 4 time without jarring from 60k to 90 k over string wt, no movement PU and jarred twice and came free, PUH, have 9k extra drag. 13:30 - 15:15 1.75 PULL P DECOMP PUH to 9448 ft and circulated bottoms up. Qp = 5 pbm at 1040 psi Vp =323 bbl's Printed: 12/1612004 4:01:31 PM ) ) BP Operations Summary Report Page 3" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-17 WORKOVER NORDIC CALISTA NORDIC 2 Start: 11/22/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/5/2005 Date From - To Hours Task Code NPT Phase Description of Operations 11/26/2004 15:15 - 18:00 2.75 PULL P DECOMP POOH with fish. running trip sheet 118:00 - 18:20 0.33 PULL P DECOMP TL meeting after crew change 18:20 - 20:00 1.67 PULL P DECOMP POOH to overshot w/fish. 20:00 - 23:20 3.33 PULL P DECOMP Back-off overshot and and lId cut-off jt. GLM #4 is just below cut-off jt. This GLM is the one we have been circulating through whenever pumping fluids in the well bore. Below this mandrel the string is wet and we are also seeing gas perculating to surface. Change elevators. Known obstruction is 17 jts below GLM. 23:20 - 00:00 0.67 PULL P DECOMP Drift and confirm there's no obstruction in GLM#4 assembly. UD same. M/U TIW valve, close annular, open choke line to gas buster. Try to circulate out trapped gas. Pressured tbg up to 1000psi and pressure held. Must have a good plug somewhere. 11/27/2004 00:00 - 02:45 I 2.75 PULL N DPRB DECOMP R/U 2" drift on 70' of wireline. Drift 2jts at a time and UD 16jts. Found obstruction 10' into 17th jt continue to have gas perculating out. 02:45 - 06:00 3.25 PULL N DPRB DECOMP R/U 3-1/2" "Hot-Tap" just above next connection. Drill 3/4" hole. Bleed off 7 gal green cement. UD jt. Still have trapped pressure. PU and hot tap above next connection. Bleed-off 6gal cement. Hot tap next connection. 06:00 - 06:20 0.33 PULL N DPRB DECOMP TL meeting in Doghouse and way forward concerning HOT tapping tubing and jewerly 06:20 - 09:05 2.75 PULL N DPRB DECOMP HOT tapping all tubulars, solid cement from XO above GLM # 5 down 09:05 - 09:30 0.42 PULL N DPRB DECOMP OOH, HOT tap jt#1 above Seal assy, Seall assy not plugged Recovered all of seal assy fish. Top of retrievable packer fish at 10244 ft 09:30 - 10:30 1.00 PULL P DECOMP Clean up floor, remove tubing from pipe shed, RU to PU BHA #2 10:30 - 10:50 0.33 PULL P DECOMP PJSM on PU BHA#2 10:50 - 13:00 2.17 PULL P DECOMP Install wear bushing and PU BHA#2 13:00 - 17:00 4.00 PULL P DECOMP RIH, out of derrick, with BHA# 2 ITCO Spear 17:00-18:10 1.17 PULL P DECOMP PU 25 jts off rack 18:10 - 18:25 0.25 PULL P DECOMP TL Meeting in dog house 18:25 - 19:25 1.00 PULL P DECOMP PIU kelly on jt #312 break circulation 2bpm 1050psi check wts. 142k up 102k dwn. RIH to 10227'. Make connection. RIH tag packer at 10253'. Engage spear. P/U several times to 240k. Cock jars pull to 200k jarred packer loose. PU good indication packer free and dragging a little. 19:25 - 20:35 1.17 PULL P DECOMP Circulate 3 bottoms-up. 4.5bpm 3450psi. 20:35 - 00:00 3.42 PULL P DECOMP Stand back and blowdown kelly. TOH. Tight in places first 6 stds. 11/28/2004 00:00 - 06:15 6.25 PULL P DECOMP TOH with packer assembly. LD accelerator and 1 DC 06: 15 - 06:30 0.25 PULL P DECOMP TL Meeting in Doghouse, Topic, LD 1 DC, handling fish using HOT tap 06:30 - 07:00 0.50 PULL P DECOMP Service Rig 07:00 - 08:30 1.50 PULL P DECOMP POOH LD 11 DC. 08:30 - 09:00 0.50 PULL P DECOMP LD Pkr assy Recoverd PBR, PKR (with all elements) and tail pipe assy. Note tail pipe not plugged. 09:00 - 13:30 4.50 CLEAN P DECOMP Load out fish and 4-3/4" DC and fishing tools Load 2-7/8" DP and 3-1/8" DC in Pipe shed, Prep. CDL Change out tongs to run work string Printed: 12/1612004 4:01:31 PM ) BP Operations Summary Report Page 4 .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-1 7 L5-1 7 WORKOVER NORDIC CALISTA NORDIC 2 Start: 11/22/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/5/2005 Date From - To Hours Task Code NPT Phase Description of Operations -..---------- 11/28/2004 13:30 - 15:30 2.00 CLEAN P DECOMP PU and RIH, 4 3-1/8" DC and 27 jts 2-7/8" DP 15:30 - 19:00 3.50 CLEAN P DECOMP RIH with 3-1/2" DP out of derrick. Phase II driving conditions called at 1750 hrs. Crews still inbound at 1845 hrs. 19:00 - 19:20 0.33 CLEAN P DECOMP Crew change and TL meeting. 19:20 - 22:30 3.17 CLEAN P DECOMP Continue RIH with 4-3/4" mill. Tagged cement at 10297'. 22:30 - 00:00 1.50 CLEAN P DECOMP P/U kelly. Start milling cement. 5.0 bpm, 1290psi, 60rpm, 200amps, up wt 134k, dwn wt 115k, rot wt 122k Pumping hi-vis sweep on each connection. Drilled to 10405' 11/29/2004 00:00 - 06:30 6.50 CLEAN P DECOMP Continue drilling hard cement fl 10405' to 10569' Qp = 252 gpm Pp =1700psi RPM = 60rpm @ 340 amps WOB = 2-3k Av = 176 I 394 fpm. Pumping BIO sweeps Loading pipe shed with 4-1/2' tubing and prep-ing 06:30 - 14:20 7.83 CLEAN P DECOMP Drilling moderate to hard cement 10,569 ft to 10,817 ft Qp = 252 gpm; Pp = 900 psi; RPM = 66 rpm Torque = 350 amps WOB = 2-3 k AV = 176 I 394 Vp = 274 bbl. ROP = 30 to 80 fph Pumping 30 bbl 2 ppb BIO sweepsl connection. 14:20 - 19:30 5.17 CLEAN P DECOMP Cir bottoms up while working kelly. 1 st pill unloaded lots of cement Cir 2 pill aroud along with 20 sxs citric acid to neutralize the fluids 19:30 - 00:00 4.50 CLEAN P DECOMP TOH standback 10 stds putting bit into 7-5/8" csg. Mix and pump 30 bbl weighted brine pill. Continue TOH laying down drillpipe 11/30/2004 00:00 - 06:00 6.00 CLEAN P DECOMP Lay down drill pipe. 06:00 - 06:20 0.33 CLEAN P DECOMP TL meeting in the doghouse, talked about drill pipe handling 06:20 - 06:50 0.50 CLEAN P DECOMP Unloading pipe shed, conduct crews walk around. 06:50 - 12:45 5.92 CLEAN P DECOMP POOH LD DP, well taking some fluid, will investiagate once OOH 12:45 - 13:00 0.25 BOPSUE P DECOMP Pull wear bushing. 13:00 - 14:00 1.00 CLEAN P DECOMP Clear floor of misc BHA tools and handling equipment. 14:00 - 15:30 1.50 EVAL C DECOMP Install 7" lubricator in BOP stack and close annular. R/U SWS. 15:30 - 17:00 1.50 EVAL C DECOMP RIH with USIT log to 10293'. 17:00 - 18:10 1.17 EVAL C DECOMP Start up pass running 6000'/hr 18:10 - 18:30 0.33 EVAL C DECOMP Pre tour safety meeting while running e-line logs. 18:30 - 20:15 1.75 EVAL C DECOMP Email USIT main logging pass to town engineers while logging a repeat section over cretatious interval. Discuss log with town. Log showed no internal or external casing corrosion. The pipe looked brand new. POOH with US IT log. 20:15 - 21 :30 1.25 EVAL C DECOMP Lay down SWS US IT logging tool string. Rehead SWS eline for running PDS multi finger caliper tool. PU PDS MFCT. 21:30 - 00:00 2.50 EV AL P DECOMP RIH, Log PDS MFCT from top of cement at 10817' to top of 5-1/2- liner at 10293'. POOH. Continue to load pipe shed with 4-1/2- tubing while running logs. 1211/2004 00:00 - 01 :00 i 1.00 EVAL P DECOMP Finish MFC log. 01 :00 - 02:00 1.00 EVAL P DECOMP Tag up at surface, check for good MFC data. RD Schlumberger and PDS eq. 02:00 - 03:00 1.00 RUNCOM=> PDS hand reports that raw MFC caliper data looks like good pipe for setting whipstock 10750'-10770'. He will prepare final data and deliver to the rig later today. RUNCMP PU elevators. air slips. Change dies in air slips. Printed: 12/1612004 4:01 :31 PM ) ) Page 5 .. BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-17 WORKOVER NORDIC CALISTA NORDIC 2 Date I From - To Hours Task Code NPT Phase ---- 12/1/2004 1.00 RUNCOrvP 0.50 RUNCOrvP 14.00 RUNCOrvP 02:00 - 03:00 03:00 - 03:30 03:30 - 17:30 RUNCMP RUNCMP RUNCMP 17:30 - 18:00 0.50 i RUNCOWP RUNCMP 18:00 - 18:30 0.50 I RUNCOrvP RUNCMP ! 18:30 - 20:00 1.50 RUNCOfvP RUNCMP 20:00 - 23:00 3.00 RUNCOMP RUNCMP 23:00 - 00:00 1.00 RUNCOfvP RUNCMP 12/2/2004 00:00 - 01 :00 1.00 RUNCOfvP RUNCMP 01 :00 - 01 :55 0.92 RUNCOfvP RUNCMP 01 :55 - 02:45 0.83 RUNCOfvP RUNCMP 02:45 - 03:00 0.25 WHSUR P RUNCMP 03:00 - 06:00 3.00 WHSUR P RUNCMP 06:00 - 06:20 0.33 WHSUR P RUNCMP 06:20 - 08:00 1.67 WHSUR P RUNCMP 08:00 - 11 :00 3.00 WHSUR P RUNCMP 11 :00 - 12:30 1.50 WHSUR P RUNCMP 12:30 - 18:00 5.50 BOPSUP P RUNCMP 18:00 - 18:30 0.50 BOPSUP P RUNCMP 18:30 - 19:40 1.17 BOPSURP RUNCMP 19:40 - 20:30 0.83 BOPSUR P RUNCMP 20:30 - 20:45 0.25 RUNCOfvP RUNCMP Start: 11/22/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/5/2005 Description of Operations ----- Prepare/check liner tally. Safety meeting prior to running completion. Begin running 4-1/2" completion as per procedure. All connections below packer are bakerlocked. All tbg connections torqued to 3500 ftllbs. MU and test SSSV for 15/min - ok. Continue p/u 4-1/2" tbg tag top of 5-1/2" liner with no-go. UD 2 jt and p/u space-out pups. P/U 1 full jt and tbg hanger MU connection from SSSV to tbg hanger and test. PJSM with all rig hands, Baker, FMC, HES discussing plan forward, hazards, and mitigations to hazards. Land tubing hanger. PT control lines. Run in lockdown screws. MU hose from IA to rig choke system and test. Hook up hose to TIW valve on top of landing joint. Pump 290 bbls of 2% KCL with 2 bbls of EC1124A corrosion inhibiter. Pumping down the tubing followed by 170 bls of straight 2% KCL. Taking returns from fA. Pump at 3.0 bpm max as per Baker hand. Initial pump pressure was 908 psi, then dropped down to 180 psi. Note, at 240 bbls away, we got a considerable amount of mouesey material back over the shakers. The material had a PH of 9.5, did not have a cement odor, and did not feel like particulate material when touched. Fluid in place. Break off TIW valve. Drop ball and rod. MU TIW valve. Pressure up to 3000 Ibs on tubing to set packer. Pressure held like a rock. Continue with tubing pressure test. Got good test. Initial pressure = 3250 psi. Final pressure after 1/2 hour = 3200 psi. Bleed pressure on tubing to 1500 psi. PT IA to 3000 psi for 1/2 hour. Good test. Initial pressure = 3170 psi, final pressure = 3150 psi. Bleed tubing pressure to 0, got good indication of shear at OCK shear valve in upper GLM (#1). Pump 2 bbls both ways to ensure valve has sheared completely. Pump 1.5 bpm at 175 psi. Good shear. Rig down landing joint. Set TWC. PT ok. Hold safety meeting Re: NO 13-5/8" stack. NO 13-5/8" stack and clean pits. Crew change PJSM review plan forward. Finsih NO 13-5/8" BOP stack NU 11" X 4" adapter and make SSSV tie-in. Test to 5K. Also PU 7-1/16. BOP stack and change out 3" rams to 2-3/8 combi's. NU 4-1/8. production tree and test to 5K. NU 7-1/6. TOT BOP stack. Alerted AOGCC for BOP test. Chuck Scheve wavied witnessing test. Body test on BOP's passed ok. PJSM with rig crew to discuss plan forward for night tour. RU lubricator and pull TWC. Pressure up SSV, remove shipping cap and install fuseable cap. RU Little Red. Pump 60 bbls of diesel down the lA, thru the OHC valve in the upper GLM, and back from the tubing. Safety meeting with SL crews and rig crew prior to starting SL Printed: 12/1612004 4:01:31 PM -) ) Page 6 ~ BP Operations Summary RepQrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-17 WORKOVER NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 12/2/2004 20:30 - 20:45 0.25 RUNCOrvP RUNCMP 20:45 - 22:05 1.33 RUNCOrvP RUNCMP 22:05 - 00:00 1.92 RUNCOrvP RUNCMP 12/3/2004 00:00 - 00:20 0.33 RUNCOrvP RUNCMP 00:20 - 01 :10 0.83 RUNCOrvP RUNCMP 01:10 - 01:50 0.67 RUNCOrvP RUNCMP 01 :50 - 03:40 1.83 RUNCOrvP RUNCMP 03:40 - 05:45 2.08 RUNCOrvP RUNCMP 05:45 - 06:15 0.50 RUNCOIVP RUNCMP 06: 15 - 06:30 0.25 BOPSUP P WEXIT 06:30 - 11 :00 4.50 BOPSUR P WEXIT 11 :00 - 11 :45 0.75 STWHIP P WEXIT 11 :45 - 12:00 0.25 STWHIPP WEXIT 12:00 - 13:00 1.00 STWHIP! P WEXIT 13:00 - 15:45 2.75 STWHIP P WEXIT 15:45 - 17:10 1.42 STWHIP P WEXIT 17:10 - 17:30 0.33 STWHIP P WEXIT 17:30 - 18:00 0.50 STWHIP P WEXIT 18:00 - 18:30 0.50 STWHIP P WEXIT 18:30 - 20:00 1.50 STWHIP P WEXIT 20:00 - 23:00 3.00 STWHIP P WEXIT 23:00 - 00:00 1.00 STWHIP P WEXIT 12/4/2004 00:00 - 01:15 1.25 STWHIP P WEXIT 01 :15 - 03:30 2.25 STWHIP P WEXIT 03:30 - 04: 15 0.75 STWHIP P WEXIT 04:15 - 06:30 2.25 STWHIP P WEXIT 06:30 - 07:00 0.50 STWHIP P WEXIT 07:00 - 08:00 1.00 STWHIP P WEXIT Start: 11/22/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/5/2005 Description of Operations ------------ work. Rig up SWS slickline unit. SL Run #1, retrieve ball and rod.7 Lay down BHA #1, recovered ball and rod. Filled hole. Took 5 bbls of KCL to fill. Run SL BHA #2, recover DKC valve from upper GLM. Took 5 bbls to fill well. Well appears to be drinking a little. Run SL BHA #3, set dummy GL V in upper station. Set dummy ok. Filled well while swapping BHA's, and the well took 10 bbls. Definitely drinking. Run SL BHA #4, fish RHC plug from lower X nipple. Retrieved plug and all seals ok. Filled well while swapping BHA's, and the well took 5 bbls. Run SL BHA #5, drift run for whipstock. Running 3.70" x 10' drift. Made it to 10822' SLM, TO from cleanout run was 10817'. Looks good. POOH. OOH well took 6bbls to fill. RD slickliners. Crew change and PJSMfTL meeting. Review plan forward. Pressure test 7-1/16" BOP stack, choke manifold and floor valves at 300psi low 3500psi high. Test accumulator. Open well. Took 6 bbls to fill. Bring BTT and SWS tools to rig floor. PJSM review plan forward. Installation of RA tags and picking up tools. Install 3 RA tags in BTT whipstock 8.90' from the TOWS. MU SWS sheave. MU SWS tools to BTT WS. RIH 85'/min make tie-in pass useing CET log 28 Jan 89. Make several passes to align WS tray to HS. Get on depth putting TOWS at 10765' with 0 TF. Fire setting tool - good indication after 35 sees. PU make another tie-in RIH tag TOWS at 10765'. Log gr/CCL back to 10000'. TOH. UD tools. G/CCL confirms WLEG is at 10284'. WLEG is 4' inside of top of 5-1/2" liner hanger. P/U injector. PJSM with all crews. Discuss activities forward for night tour, hazards and mitigations to hazards. Pull end of coil oft of reel and stab into injector. Filled the hole at 19:45, the well took 5 bbls of seawater. Cut 1500' of coil with hydraulic cutter. Filled hole at 20:20, and it took 4 bbls. Fill hole, took 3 bbls. Prepare end of coil for pumping slack management. Fill coil with 2% KCL. Pump slack management. Attach CTC, build upper QC. Make up BHA #4. 3.80. WM, 3.80 go, 3.79" no-go string mill. Baker TT straight motor. 1 Joint of PH6, BHI MWD BHA. RIH with BHA #4, to begin window milling. Pumping new mud at minimum rate down the coil thru an open EDC. Stop at 10630'. Log tie-in -13' correction. Close EDC RIH tag whipstock pinch-point at 10766' BHi tools quit. Swapping fluids in well from 8.5ppg KCL to 8.75ppg Flo-Pro Printed: 12/16/2004 4:01:31 PM ) ) BP Operations Summary RepQrt Page7~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L5-17 L5-17 WORKOVER NORDIC CALISTA NORDIC 2 Start: 11/22/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/5/2005 Date Task Code NPT Phase Description of Operations 12/4/2004 07:00 - 08:00 1.00 STWHIP P WEXIT mud. Mud at bit rates = 2.60 in 2.35 out. Mud at surface rates = I 2.60 in 2.10 out. Out rate increased to 2.20 prior to TOH for BHi tool change out. 08:00 - 10:30 2.50 STWHIP N DFAL WEXIT TOH 10:30 - 12:00 1.50 STWHIP N DFAL WEXIT Diagnose problem. Found bad Flow-Sub and replaced. All other tools tested good. 12:00 - 14:00 2.00 STWHIPjN DFAL WEXIT RIH. Tagged on whipstock pu to flag corrected to flag. PU start pump 2760fs creep in hole got to pinch point and motor stalled (normal) and BHi tool comms failed again. On the bright side returns are close to 1:1 14:00 - 16:45 2.75 STWHIP N DFAL WEXIT TOH 16:45 - 18:00 1.25 STWHIP N DFAL WEXIT Coil e-line tests fine. Again the problem is the Flo-Sub. Both of the failed subs have recently been serviced at the DH shop but are the old style subs with a major portion of the electrical pin connector is made of ceramic. They test fine until you wiggle them hard and then there's continuity. The new style pins have more metal on the threaded portion where the coil wire attaches. We discussed completely reheading but the obvious problem is the flo-subs. MU new sub and BHA. 18:00 - 18:30 0.50 STWHIP N DFAL WEXIT Pre tour safety meeting. Discuss plan forward for night tour. 18:30 - 19:00 0.50 STWHIP N DFAL WEXIT Make up BHA #6 to mill window. D0261 gauges 3.80". String mill gauges 3.80 go, 3.79" no go. 19:00 - 20:45 1.75 STWHIP N DFAL WEXIT Shallow hole check ok. RIH with BHA #6 to mill window. 20:45 - 22:00 1.25 STWHIP P WEXIT Shut EDC. Dry tag top of WS with pumps down. Make -21' correction. PU, kick on pumps. RIH. Free spin=2660 psi at 2.55 bpm. Pit volume=288 bbls. Tag WS at 10766'. Milling at 2.56/2.26/2700 psi. Losing about 0.25 bbl/min, 15 bbl/hr. Call for new mud to have on location as needed. 22:00 - 00:00 2.00 STWHIP P WEXIT 22:00 update. Depth=10766.9'. DHWOB=900 Ibs. 2.52/2.3/2750 psi. IAP=480 psi, OAP=30 psi. Pit vol=269 bbls. 24:00 update. Depth=10769.0', DHWOB=1500 Ibs. 2.53/2.58/2740 psi. IAP=560 psi, OAP=55 psi. Pit vol=225 bbls. Losses seem to have healed up. 12/5/2004 00:00 - 01 :00 1.00 STWHIP P WEXIT Continue milling window. Losses have healed up completely. 2.55/2.57/2747 psi. IAP=590 psi, OAP=60 psi. Pit vol=226 bbls. DHWOB=1000 psi. 01 :00 - 02:10 1.17 STWHIP P WEXIT Continuing to mill. At 10769.9'. Taking new mud off of the vac truck. DHWOB and motor work trending down. Probably past the 1/2 way point. Getting good metal on the ditch magnets. Still have 100% returns. 02: 1 0 - 02:40 0.50 STWHIP P WEXIT Pits full of new mud. PVT =435 bbls. 2.6/2.6/2800 psi. 02:40 - 03:00 0.33 STWHIP P WEXIT 10771.5', Possibly thru the window. Try drilling. Making hole. Preliminary window depths 10766'-10771.4'. 03:00 - 03:40 0.67 STWHIP P WEXIT 10775', Started losing returns again. Drilling at 2.55/2.33/3350 psi. ROP=10 fph. Drilled to 10782' 03:40 - 04:40 1.00 STWHIP P WEXIT Ream/Backream window. Returns have mostly healed up again. 04:40 - 06:30 1.83 STWHIP P WEXIT Dry drift the window down and up. Slick as a whistle. POOH to pick up build section BHA. Printed: 12/1612004 4:01:31 PM ) ') Page 8. BP Operations Summary Report L5-17 L5-17 WORKOVER NORDIC CALISTA NORDIC 2 From - To Hours Task I Code NPT Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Phase --- 12/5/2004 3.00 STWHIP N DPRB WEXIT 06:30 - 09:30 09:30 - 09:45 0.25 STWHIP P WEXIT 09:45 - 12:00 2.25 STWHIP P WEXIT 12:00 - 12:30 12:30 - 14:15 0.50 STWHIP P 1.75 STWHIP P WEXIT WEXIT 14:15 - 16:00 1.75 STWHIP P WEXIT 16:00 - 16:15 16:15 - 16:55 0.25 STWHIP N 0.67 STWHIP N SFAL WEXIT SFAL WEXIT 16:55 - 18:00 18:00 - 18:30 18:30 - 00:00 1.08 STWHIP N 0.50 STWHIP P 5.50 STWHIP P Start: 11/22/2004 Rig Release: 12/15/2004 Rig Number: 2 Spud Date: 11/22/2004 End: 12/5/2005 Description of Operations -----.- Lift off injector from lubricator. Notice well is flowing +/- 1/4bpm MU injector to lubricator. Shut in annular pressure built to 55psi. Open well and bleed off quickly with small flow. RIH to 1000' circ BU. Trip to surface. Well still flowing small about. I Might be balloning effect from losses. Open EDC (lost comms with tools, shows open circuit) and RIH to 4000'. Circ BU showing normal bbg of 32u trip to surface. Small flow. RIH to 300' wo pump TOH. UD complete BHA #6. Install lubricator cap and monitor well. 156 bbls in active pit at 0940hrs. Check out all BHi componets for open circuit. Found SLB's cable between reel junction box and collector bad. Well giving back small stream at 0950 hrs...continue to monitor. MU new BHA on walk and check. Sametime make repairs to SLB cable. No downtime. Well still giving back samll amount of mud 1-1/2 bbls over last 2 hrs. Close SSSV to avoid mess at floor while PU BHA. P/U build section BHA. (65.09') Open SSSV (4800psi) RIH no pressure beneath SSSV. Tag at 10796' correct to 10782'. Up wt=43k dwnwt=26k Drill build section f/ 10782' Q in=2.70 Q out=2.40 FSP=2570 WOB=.5k frequent stalls. Drill to 10795'. Lost comms agai with tools as before. Same cause, the SLB's jumper w' . The wire used is the same as the coils e-line. It is stiff d the connection to the collector is a very poor des' for this wire and should be replaced with a stronger c necter. Either that or replace the jumper with a more re . ent wire. TOH to 10000' pump at min rate Trace problem. Same as be e, the SLB's jumper wire. The wire used is the same e coils e-line. It is stiff and the connection to the c ctor is a very poor design for this wire and should be laced with a stronger connecter. Either that or replace jumper with a more resilient wire. Install other jumper wire. Same type. RIH back to bottom. D' ahead f/ 10795' 2.76/2.54 FS=2970 MW=100 afety meeting Re: plan forward for tour. Drill ahead build section with slow ROP. ROP is 10-20 fph. JAP=503 psi. OAP=90 psi. Pit volume=362 bbls. Free spin = 2630 psi at 2.74 bpm. Drilling at 2.74/2.6/2950 psi. Losing fluid at about 9 bph. Bringing on remaining 85 bbls of mud from vac truck. Had another problem with the SWS eline collector. Fixed by tightening set screws. Printed: 12/1612004 4:01:31 PM ~1f ~ AIlASIiA. OIL AND GAS CONSERVATION COMMISSION Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 Re: PBU L5-17 304-397 Dear Mr. Stagg: ! ..!1"(';;"'f;~'~'" FRANK H. MURKOWSKI, GOVERNOR 333 W. -¡nt AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. } J orman Chairman BY ORDER OF THE COMMISSION DATED thisL day of 0 er,2004 ~W~ Enc!. ~ SCANNE[) NO\! 0 :i 2004 ~(~ t+ ,~rø STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAfLCT 282004 20 MC 25.280 Alaska Oil & 1. Type of Request: B Abandon D Repair Well B Plug Perforations D Stimulate D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Change Approved Program D Operation Shutdown D Perforate D Re-Enter Suspended Well A;,!G~;:;í~g~ Plug back for sidetrack /' III Other D Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 55.0' 4. Current Well Class: ,,/ a Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number 188-139 /' 6. API Number: / 50- 029-21889-00-00 9. Well Name and Number: PBU L5-17 / 8. Property Designation: ADL 028320 10. Field / Pool(s): Prudhoe Bay Field / Lisburne Pool ~ PRESENTWELCÇONOITIONSl)MMARY , . Effective Depth MD (ft): I. Effective Depth TVD (ft): Plugs (measured): 11050 9184 None Size MD TVD Burst 11. Total Depth MD (ft): 11142 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 9224 Length Junk (measured): None Collåpse 115' 20" 115' 115' 1490 470 4250' 10-314" 4250' 4089' 3580 2090 1 0480' 7-5/8" 1 0480' 8688' 6890 4790 847' 5-1/2" 10293' - 11140' 8546' - 9223' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 10635 - 10990 8809 - 9097 3-1/2" x 2-7/8" Packers and SSSV Type: 7-5/8" x 2-7/8" Baker HB Packer and a 3-1/2" AVA 13Cr TRSSSV Tubing Grade: L-80 Packers and SSSV MD (ft): 10275' 2124' Tubing MD (ft): 10355' 12. Attachments: 181 Description Summary of Proposal 0 Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Ted Stagg Title CT Drilling Engineer Signature r...Z..- .~._. . IC/';¿ ~.¡ Phone 564-4694 t/(I Coml11ission . Use. Only iii BOP Sketch 13. Well Class after proposed work: ./ 0 Exploratory 181 Development 0 Service 15. Well Status after proposed work: 0 Oil 0 Gas 0 WAG 0 GINJ a Plugged DWINJ iii Abandoned 0 WDSPL /' November 8, 2004 Date: Contact Ted Stagg, 564-4694 Date Prepared By Name/Number: Sondra Stewman, 564-4750 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: :3 0 L{. ~ 9 7 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: 'ifs f-- gop E ~. SSOO pç;, .~ßfL MOV U COMMISSIONER APPROVED BY THE COMMISSION Date t!¿~ 'tliæte '-- OR1G1NAL To: Winton Aubert Sr. Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Ted Stagg CTD Engineer Date: Oct. 22, 2004 Re: CTD Tubing Swap and Sidetrack of Lisburne Well L5-17 Lisburne Well L5-17 is scheduled for a through-tubing sidetrack with coiled tubing. Prior to CTD sidetracking, all perforations will be cement squeezed and the 3 V2" x 2-7/8" production tubing and packer will be replaced /' with 4-1/2" L-80 tubing and packer. The sidetrack, L5-17 A, will kick off from a window milled from a mechanical whipstock. The following describes work planned to prepare L5-17 for swapping the tubing and sidetracking and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed tubing swap and sidetrack is attached for reference. 1. Confirm integrity of casing and OA. / 2. Kill well with 2% KCI. .L \/01,7, 2--0 b~{~ ldG~ 3. Cement squeeze all existing perforations with service coil. v 4. RU Nordic 2 with II" BOPE. Test stack. 5. Pull 2-7/8" L-80 tubing. 6. Retrieve packer and tailpipe. 7. Complete well with 4-1/2" 12.6# L-80 ffiT-M tubing with new packer and 4 Y2" tailpipe. 8. PT completion. RD II" BOPE. NU tree and 7-1/16" CTD BOPE. Test. 9. Use 2 3/8" coiled tubing to underream 5 V2" liner. Re-test squeezed perfs to 1000 psi. 10. Set mechanical whipstock at 10,770' MD (8862ss) 11. Continue with CTD window milling and open hole drilling as detailed in the Permit to Drill application. Step 3, cement squeezing of all existing perforations, is scheduled for the week of November 8, 2004. Step 4, RU of Nordic 2, is scheduled for November 21,2004. ~~' \/ ¡! fþj I(J/~f Ted S agg l/ CTD Drilling Engineer cc: Well File Terrie Hubble TREE = ----? WELLHEA 0 = Ffv'C ACTÙA. fOR= 'AXElSÖN -KEf."ËL8T;" - "'55,' ~êF: li'f\l;--'-'--'--'-----'------ \ ,......~ __n.~; .......~ ~<^' ".~."~'~ <..,,~«..~.,.,....,.,..~ ".,~.,,;"'...'" "". KOP= 2900' .. n' ~ """"'''''~'''< "'''_'''.._",,,~,,.~,.,,.YM_,''''''''''^,,~, -~'.< A.~Jll.~= ._._,~~..~^9..1,,0.9~ cetum M) = 10693' 'ï::etumiVÖ = .. ''''-¿8ëx)",'&3' Minimum ID = 2.205" @ 10344' OTIS XN NIPPLE r 10-3/4" CSG, 45.5#, J-55, 10 = 9.953" H 4250' 3-1/2" lBG-IPC, 9.3#, L-80, .0073 bpf, D =2.992" H 10245' 1 TOPOF2-718"lBG-IPC H 10245' 1 1 TOP OF 5-1/2" LNR H 10293' 1 12-7/8" TBG, 6.5#, L-80, 0.00579 bpf, D = 2.441" H 10355' I 1 7-518" CSG, 29.7#, L-80, 10 = 6.875" H 1 0480' ~ ÆRFORA llON SlJv1M\ RY REF LOG: l T/OJL 50S ON 01/24/89 ANGLE AT TOP PffiF: 39 @ 10540' Note: Refer to Production œ for historical perf data SIZE SA= INTERVAL OpnlSqz DATE 2-1/8" 1 10540-10584 S 02/15/89 2-1/8" 1 10608-10634 S 02/15/89 2-1/8" 1 10635-10730 0 02/15/89 2-1/8" 4 10730-10750 0 07/01/96 2-1/8" 4 10775-10868 0 07/01/96 2-1/8" 4 10880-10990 0 06/30/96 1 PBTO H 11094' 15-1/2- LNR, 17#, L-80, 0.0232 bpf,lD =4.892" H 11142' [)\TE 01/30189 07/16/91 01/05101 03102101 REV BY COMM:NTS ORIGINAL COMR..ETlON WORK OVER SIS-CS CONVERTED TO CANV AS SIS-LG FINA L DATE REV BY COMWENTS 10/02/01 RN'TP OORRECfIONS 11/01/01 GRC'tlh M\ Y 2000 MLL CMT,FCO SANC L5-17 / e c L L ~ ~~ "'I II ~.. SAFETY f\OTES: CAT SSSV H2S (PRv1) 60. r 2124' H3-1/2" AVA 13CR TRSSSV, ID= 2.812" 1 CI-EMICAL M\NDRELS ISTI M) I TVD DEV I lYPE I VLV I LATCH I FQRTI DATE I 1 2228 2228 0 KBUG-LTS OJ BK-2 0.0 07/16191 GAS LIFT MANDRELS DEV lY PE VL V LATCH FQRT DATE 7 TG TG 43 TG TG 42 TG TG 42 TG TG 41 TG TG ST M) TVD 2 2850 2849 3 5631 5091 4 7915 6789 5 9508 7954 6 10133 8424 ~ 1 10245' 1-t31/2"X2718"XO I 10258' HBAKER FBRSEAL ASSY, ID =2.34" 1 1 10275' H7-5/8" X2 718" BKRHB PKR,ID=2.34" I I 1 10344' 1- 2 7/8" OllS XN NIP, ID = 2.313", WINO GO, ID = 2.205" 1 10355' 1"27/8" BAKER WlETITU3ING TAIL 1 I 10355' HELMDTTLOGGID 08/08/91 I .. 1 11050' H 9400 LBS OF 20140 SAND, FOO'D 1 LISBU~EUNrr WB.l: L5-17 PERMT I\b: 88-139 AR I\b: 50-029-21889-00 SEC 2, T11N. R15E 44.68 FEL 3263.64 HI.. BP Exploration (Alaska) '1'REE = }" WB.LHEAD = FMC ACTUÁ fOR = .. AXElSÖN KB. 8.EV = 55' SF. ËLér;;""" ..",..",..m,,' t<óP'~ .. ......" 2900' ,~'Äi'-gle"~",--- 45'~-9.1~õ', Datum MD = 10693' ~ ,- < ' Datum lVD = 8800' SS ~? SAFETY NOTES: CAT I SSSV H2S (PPM) 60. L5-17A Proposed Completion 8 4 1/2¡' TRSSSV 4 GLMs ~ I 10-314" CSG, 45.5#, J-55, ID = 9.953" 1-1 4250' ~ ~ ~ z 4 1/2" x 7 5/8" Packer 4 1/2" Tailpipe wI X Nipple I \..-) 1 TOP OF 5-1/2" LNR l-i 10293' I .. I 4 1/2" Half Muleshoe 1 jt. into 5 1/2" liner 17-5/8" CSG, 29.7#, L-80, ID = 6.875" l-i 10480' ~ .. Whipstock to be set at 10,770 at top of Zone 5. IPBTD H 11094' I ~~: .f 'I ~m~ I 11050' H 9400 LBS OF 20/40 SAND, FCO'D I 15-1/2" LNR,17#, L-80, 0.0232 bpf, Ð=4.892" H 11142' I DA TE ~ BY COMM:NTS 01130/89 ORIGNAL COMPLETION 07/16/91 WORK OVffi 01105/01 SIS-CS CONVERTED TO CANVAS 03102101 SIS-LG FNAL DATE REV BY COMMENTS 10/02101 RN/TP CORRECTIONS 11/01/01 GRCltIh MAY 2000 MLL CMT,FCO SANe LISBURNE UNrr W8.L: L5-17 PffiMfT No: 88-139 API No: 50-029-21889-00 SEC 2, T11 N, R15E 44.68 Fa 3263.64 FNL BP Exploration (Alaska) ~~ r " Blind ram ~ Choke line I HCR valve ~=0==0~ Pipe ram ~ Empty Cavity ----r--I or VBRs ~ I S{ ==0~ I DTK 12/08/03 Nordic 2 11" & 13-5/8" Workover BOP Stack «5000 psi) " 11" or 13-5/8" Annular Preventer 3 ~ 11" or 13-5/8" BOP 0 þ'l// \ Kill line HCR valve ~=0==0~ 11" or 13-5/8" BOP 0 0 11" or 13-5/8" tubing head þl / Þ I ~=0~=0~ , ~=0~ ---. I Type of Problem Well Name! Csg ! Cmt! WH i PBU Wells A-18 B-33A E-18 sc H-16 sc H-25 J-01 sc J-23 K-11 pc K-13 sc K-19 pc N-20 sc P-18 sc ? R-34 sc pc W-08 pc 4-19. 9-23. sc pc 9-47. 11-27. 6{fG{q't 14-39. sc 15-45. 16-26 16-27 PWDW MPU Wells K-25 E-4 sc DIU Wells 4-38/K-34 1-41/0-23 I 1-53/0-20 1-61/0-20 1-33/M-23 ¡ Exp Wells I Sourdoug 3 Badami 4 Badami 5 KRU Wells 2T-21 y y y y pc y y y y y y y y y y y y y y y y y y ? ? y y y y ? ? ? i Observation y cond leaking broached gas to sfc fluids to sfc gas in cellar fluids to sfc broached press on sc oil in cellar press on sc gas in cellar o&g to sfc g&m in cellar gas in OA broached g&w in cellar broached wtr outside gas release broached subsidence subsidence broached I Notes: 1. Surface casing leaks 10 2. Prod casing leaks 5 I I 3. Problems w/sfc casing cementing 24 4. Problems w/prod csg cementing 1 I I I 5. Well Head leaks 5 I I I 6. Subsidence around the conductor 4 7. Disposal fluid to surface 11 8. Other gaslfIuid to surface 14 sc-probs.xls 10/4/96 y y y y gas in cellar broached broached broached gas to sfc prss on OA broached broached subsidence subsidence sc cmtg Sheet1 -' ì ~'b -/3C¡;· Comments Press'd annulus & cond started leaking Broached while disposing in nearby well Also press on sc Shallow leak in SC- welded speed head Packed casing hanger seals 5C leak at 60'· down squeezed Fluid surfaced while disposing down annulus OA press tracked IA pressure/Prod csg leak Oil in cellar- sc leak at 30' Press would not bleed down Prob 60 - 80' below sfc- to be RD'd Leak in the sc at - 80'- down sqz'd OA Leak @ 420'- seals leaked- pc also leaked Leak in pc- sqz'd OA- ok press test Disposal fluids surfaced Hydrate gas/downsqz'd/g&w in cellar Disposal fluids surfaced 3bpm wtr outside welVsource not determined Sudden /sc parted 81 '{41'bgl)/downsqz not good Disposal fluids surfaced Conductor slipped down hole Conductor & tree leaning Hydrate gas/no emt to sfc Disp'l fluids broached/leak @1200'/csg wear Disposal f/4-48/K-43 broached in 4-38 Disposal f/1-51 broached in 1-41 Formation gas to sfc out side conductor Reservoir press on OA due to pc poor emt Disposal f/1-33/M-23 broached in M-23 Disposal down #3 broached around #3 During disposal, WH subsided During disposal, Wh subsided Lost eirc early while cmtg/no action taken SçANNE.O NOV 1 '1 Zu05 Page 1 Action/Result WH seals bleed OA to be RD'd sqz'd OA RWO sqz'd OA RWO Obs well 51 down sqz sc gravel fill gravel fill WOC arctic pak 51 displ 51 displ P&A well sqz'd pc sqz'd OA 51 displ 51 displ 51 displ THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 2000, E E PI~ E W M A T E R IA L U N D E T H IS M A R K ER R C:LORIXMFILM.~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 3453' FNL, 154' FEL, Sec. 2, T11 N, R15E, UM At top of productive interval 3261' FNL, 5014' FEL, Sec. 2, T11N, R15E, UM At effective depth At total depth 3264' FNL, 45' FEL, Sec. 3, T11 N, R15E, UM 5. Type of Well: Development __X Explorato~__ Stratigraphic__ Service__ (asp's 717271, 5974952) (asp's 712408, 5975008) (asp's 712098, 5974995) 6. Datum elevation (DF or KB feet) RKB 55 feet 7. Unit or Property name Lisburne Unit 8. Well number L5-17 9. Permit number / approval number 188-139 10. APl number 50-029-21889 11. Field / Pool Lisburne Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 115' Surface 4195' Intermediate 10425' Liner 849' 11142 feet Plugs (measured) 9224 feet PBTD tagged (5/02/2000) @ 11050' MD. 11050 feet Junk (measured) 9147 feet Size Cemented Measured Depth 20" 215o# Poleset 115' 10-3/4" 1600 Sx AS III & 350 Sx Class G 4250' 7-5/8" 325 sx class G 1 0480' 5-1/2" 15o sx C~ass G 11142' ORIGINAL True verticalDepth 115' 4089' 8688' 9224' Perforation depth: measured 10635'- 10750'; 10775'- 10868'; 10880'- 10990'. true vertical 8809' - 8901'; 8921' - 8996'; 9006' - 9097'. Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 PCT @ 10245' MD; 2-7/8", 6.5#, L-80 PCT @ 10355' MD. Packers & SSSV (type & measured depth) 7-5/8" X 2-7/8" BAKER HB PACKER @ 10275' MD. 3-1/2" AVA 13CR TRSSSV @ 2124' MD. RECEIVED ~ . JUL 2 1 2000 Alaska 0~; & Gas Col;s. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Shut in Representative Daily Avera,qe Production or Injection Data Gas-Mci Water-Bbl 400 2000 40 Casing Pressure Tubing Pressure 55O 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run m Daily Report of Well Operations __X Oil __X Gas m Suspended 17. I hereby certify ~l~t the~o/~ing is true and correct to the best of my knowledge. Signed ///~~~//j~ ~'J'~ ~"~ Title: Disposal / Rog Compliance Engineer Mike Bill ~ u v- ~./ Service Date Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE L5-17 DESCRIPTION OF WORK COMPLETED MARASEAL GEL / CEMENT SQUEEZE FOR GSO & FB ACID BREAKDOWN TREATMENT Date Event Summary 9/16/1999: 10/14/1999: 10/2211999: 10/24/1999: 3/15/2000: 4/13/2000: 4/17/2000: 4/18/2000: 4/22/2000: 4/27/2000: 5/01/2000: RIH & tagged PBTD @ 11067' MD. MITIA to 2500 psi - passed. MIT-T to 3000 psi - passed. MIRU CTU & PT'd equip to 4000 psi. RIH w/CT & killed well. Tagged PBTD, then PUH to 10500'. Pumped a gelled sand slurry containing 9400 lbs of 20/40 mesh river sand to place an isolation plug across the following perforation intervals: 10635'-10750' MD 10775'-10730' MD 10635'-10868' MD 10880'-10990' MD RECEIVED Target level is 10620'. POOH. FP'd well. RD. RIH & tagged TOS @ 10649' MD. RIH & tagged TOS @ 10643' MD. ,IUL 2 1 2000 Alaska 0[~ & Gas Co;~s. Anchorage MIRU CTU & PT'd equip. RIH w/CT & killed well. Tagged TOS @ 10630'. Pumped a gelled sand slurry containing 600 lbs of 20/40 mesh river sand to raise the TOS to target of 10620'. Made a final TOS tag @ 10626' MD. POOH. RD. RIH & tagged TOS @ 10642' MD. Dump bailed 4 gallons of 20/40 mesh sand. LDFN. Dump bailed an 4 gallons of 20/40 mesh sand to 10634'. Dumped 4 gallons of Cement. Performed a CTU Maraseal Gel/Cement Squeeze for Gas Shutoff as follows: MIRU. Tested BOPE. RIH w/CT & tagged BTM @ 10615' CTM. PUH 10' & pumped 1% Slick Water down coil. Pumped 175 bbls of Maraseal Gel down the backside & 50 bbls down the coil, followed by 92 bbls of 15.6 ppg Latex Acid Resistive Cement to squeeze the open perforation intervals: 10540' - 10584' MD 10608' - 10634' MD Placed all 175 bbls of Crosslinked Maraseal Gel & 87 bbls of Cement behind pipe. Attained a max squeeze pressure DP of 2600 psi. Contaminated Cement w/Biozan & washed out contaminated Cement to 10500'. POOH. FP'd well. RD. WOC. RIH &tagged TOC @ 10513' MD. MIRU CTU. PT equip. RIH & milled a 2.2" hole in cement f/10510' - 10620' MD. PUH to 10400 & PT'd squeeze to 1000 psi - lost 50 psi in 5 minutes. RBIH & milled through cement / sand interface to 10655'. POOH w/BHA. Page I L5-17 DESCRIPTION OF WORK COMPLETED MARASEAL GEL ! CEMENT SQUEEZE FOR GSO & FB ACID BREAKDOWN TREATMENT Date Event Summary 5/02/2000: 6/12/2000: 7/13/2000: 7/14/2000: 7/1512000: RIH & performed FCO to 11050'. Swapped wellbore to Crude. POOH. RD. Loaded IA w/Crude. MITIA to 3000 psi - passed. RIH & set Frac Sleeve @ 2114' MD. MIRU CTU. PT'd to 4000 psi. RIH to 10240' CTM & pumped the following fluid schedule: (a) 10 bbls of Xylene (b) 10 bbls of HCL (c) 140 bbls of Diesel POOH. RD. Performed a Fullbore Acid Breakdown Stimulation as follows: MIRU. PT'd equip to 9000 psi. Pumped HP Emulsified 15% HCL Acid Treatment w/Rock Salt Diversion @ max rate of 15 bpm & 6500 psi. Pumped 275 bbls of Dowell Gelled Acid & 590 bbls of Dowell SXE (Emulsified Acid). Pumped 2 Rock Salt Diversion Stages w/over 2400 psi of diversion in each. Injectivity improved by approx 300 psi @ 15 bpm. RD. RIH & pulled Fmc Sleeve. Placed L5-17 BOL & gathered representative production data. RECEIVED ,11.II, 2 1 2000 ~. ~,, Alaska 0~, e. Gas 0ohs, Commission Anchorage Page 2 STATE OF ALASKA ALASKA~% AND GAS CONSERVATION COMMIS,~"~'N REPORT:,JF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing __ Alter casing __ Stimulate ~_ Plugging __ Perforate _ Repair well __ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 3452' FNL, 153' FEL, Sec. 2, T11N, R15E At top of production interval 2018' FSL, 265' FWL, Sec. 2, T11 N, R15E At effective depth 2018' FSL, 265' FWL, Sec. 2, T11N, R15E At total depth 3263' FNL, 44' FEL, Sec. 3, T11 N, R15E 5. Type of Well: Development Exploratory Stratigraphic Service Datum elevation (DF or KB) RKB 55 feet 7. Unit or Property name LISBURNE UNIT 8. Well number L5-17 9. Permit number/approval number 88-139 / 10. APl number 500292188900 11. Field/Pool Lisburne Pool 12. Present well condition summary Total Depth: measured: 11142 feet true vertical: 9224 feet Effective Depth: measured: 10540 feet true vertical: 8733 feet Casing Length Size Cemented Conductor 80' 20" 2150# Poleset Surface 4250' 10 1600 sx AS III & 350 sx Class G Intermediate 10480' 7 5/8" 325 Sx Class G Liner 849' 5 1/2" 150 SX Class G Plugs (measured) Junk (measured) None. None. Measured depth True ve~ical depth 115' 115' 4250' 4089' 10480' 8688' 11142' 9224' Perforation depth: measured 10730-10750', 10775-10868', 10880-10990' true vertical 8829-8845', 8865-8941', 8950-9041' Tubing (size, grade, and measured depth) 3 1/2 in. 9.3# L-80 @ 0-10245' MD, 2 7/8 in. 6.5# L-80 @ 10245-10355' MD, Packers and SSSV (type and measured depth) 2 1/3 X 6 7/8 PKR @ 10275' MD, 2 4/5 x 3 1/2 TRSSSV @ 2124' MD RECEIVED JUL 22 Alaska 0il & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Please refer to attached. Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Representative Daily Avera.qe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 895 14900 50 Subsequent to operation 1150 17000 50 15. Attachments 116. Copies of Logs and Surveys run __ I I Daily Rep~iit (~f We, ll 01~erations ..~ Oil ~ Gas 117. I hereby f.~r~fY~y/~ f~egoing is true and correct to the best of my knowledge. / Tubing Pressure 550 550 Status of well classification as: __ Suspended Service Date ~/~/? ? Form 10-404 Rev 06/15/88 ' SUBMIT IN DUPLICATE L5-17 Acid Wash 8/24/96 1 RU stimulation company. Held pre-job safety meeting Pumped 190 BBL 12% 90/10 DAD Acid followed by 400 BBL 1% KCI down coil. Loaded well and pumped 720 BBL slk crude down backside during acid flush stage. Recip coil from 10700 to 11000' MD during acid and flush. Did not see a pressure change. 3 Released service company. Well: L5-17 2124 2125 2228- ~2229~ 2950 2851- 5632-i 7915 7916 9508 9509 10133 10245i 10246- 10275- 10276 10344- 10348 103554 10480- 10650- Ped 10700 -- I !1o65o~ 10800 GPMA WEB Date: 5/5/99 APl: 500292188900 Well Type: PROD SSSV Type: CAT I - SSSV Orig Compltn: 1/30/89 Annular Fluid: LIFT GAS Last W/O: Reference LDT/CNL SOS Ref Log Date: 1/24/89 Log: LastTag: 11069elm TD: 11142ftKB Last Tag Date: 3/25/99 Max Hole 45 deg @ 9100 Angle: Date Note 1/31/89 Minimum ID: 2.205" OTIS XN NIPPLE @ 10344' ELMD WORKOVER 7/16/91 RECOMPLETED Ang!~ @ TS: deg @ Ang!e @TD: 33 deg@11 Rev Reason: Last Update: 4/4/99 Date Note 1/31/89 Well Status: ACTIVE 1/31/89 Tubing Hanger: FMC GEN 4A @ 33' MD Last Tag Depth @ 11142 Top Of Fluid Depth ~ 10534 Depth TVD Type Descriptiol~ ID 2124 2124 TRSSSV 3-1/2"AVA 13CR TRSSSV, ID=2.812" 2.810 10245 8509 XO 3-1/2"X2~7/8"CROSSOVER (ELMD) 2.000 10275 8532 PKR 7-5/8' X 2-7/8" BAKER HB PACKER, ID=2~34" (ELMD) 2.340 10344 8584 NIP 2-7/8" OTIS XN NIPPLE, ID=2.313", W/NO GO, ID=2.205" (ELMD) 2.310 10355 8593 TT 2~7/8" BAKER WLEG/TT 10355' ELMD (8~8-91) 3.000 Size Weight Grade Top Btm Feet Description 10.750 45.50 J-55 0 4250 4250 SUR. CASING 7.625 29.00 L-80 0 10480 10480 PROD. CASING 5.500 17.00 L-80 10293 11142 849 LINER Size Weight Grade Top Btm Feet Description 3.500 9.30 L-80 0 10245 10245 TUBING-IPC 2.875 650 L-80 10245 10355 110 TUBING-tPC ~hem ica~ Marldlte]s]V~lve$ Stn MD TVD Man Man VMfr VType VOD Latch Port TRO Date Vlv Mfr Type Run Comment 1 2228 2228-KBUG-L CA E 1.0 BK-2 0.000 0 CIM Stn MD 'rVD Man Man VMfr VType VOD Latch Port TRO Date VIv Mfr Type Run Comment 1 2850 2849 MERLA TG CA RD 1.5 TG 0.000 0 5/28/95 GLM 2 5631 5091 MERLA TG TE D-14R 1,5 TG 0.000 0 GLM 3 7915 6789 MERLA TG CA RD 1.5 TG 0.000 0 5/28/95 GLM 4 9508 7954 MERLA TG TE D-14R 1.5 TG 0,000 0 GLM 5 10133 8424 MERLA TG CA RD 1.5 TG 0.000 0 5/28/95 GLM interval TVD 10540- 8734-8769 10584 10608- 8787-8884 10730 10730~ 8884~8901 10750 10775~ 8921-8996 10868 10880- g006-gQ97 10990 Zone Status FeetSPF Date Type Comment C 44 0 Sqz SELECTIVE SHOTS (9) t22 0 SELECTIVE SHOTS (16) 20 4 7/I/96 APERFADDPERFS 93 4 7/1/96 APERFSS(80'SHOT @ 4 SPF), ADDPERFS 110 4~3~96APERFSS(78'SHOT @ 4 SPF), ADDPERFS STATE OF ALASKA ALASKA?-''~. AND GAS CONSERVATION COMMISS~ REPORT ,.~F SUNDRY WELL OPERATI~.,NS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Perforate Pull tubing _ Alter casing _ Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 3452' FNL, 153' FEL, Sec. 2, T11N, R15E At top of production interval 2018' FSL, 265' FWL, Sec. 2, T11 N, R15E At effective depth 2018' FSL, 265' FWL, Sec. 2, T11 N, R15E At total depth 3263' FNL, 44' FEL, Sec. 3, T11 N, R15E Repair well _ Other _ 5. Type of Well: Development Exploratory Stratigraphic Service Datum elevation (DF or KB) RKB 55 feet 7. Unit or Property name LISBURNE UNIT 8. Well number L5-17 9. Permit number/approval number 88-139 / 10. APl number 500292188900 11. Field/Pool Lisburne Pool 2. Present well condition summary . Total Depth: measured: true vertical: Effective Depth: measured: true vertical: Casing Length Conductor 80' Surface 4250' Intermediate Liner Perforation depth: 10480' 849' measured Size 20" 10 7 5/8" 51/2" 11142 feet 9224 feet 10540 feet 8733 feet Cemented 2150# Poleset 1600 sx AS III & 350 sx Class G 325 sx Class G 150 sx Class G 10730-10750',10775-10868',10880-10990' true vertical 8829-8845',8865-8941',8950-9041' Tubing (size, grade, and measured depth) 3 1/2 in. 9.3# L-80 @ 0-10245' MD, 2 7/8 in. 6.5# L-80 @ 10245-10355' MD, Packers and SSSV (type and measured depth) 2 1/3 X 6 7/8 PKR @ 10275' MD, 2 4/5 x 3 1/2 TRSSSV @ 2124' MD Plugs (measured) Junk (measured) None, None. Measureddepth 115' 4250' 10480' 11142' True vedical depth 115' 4089' 8688' 9224' RECEIVED JUL 22 lggg Alaska Oil & Gas Cons. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL Prior to well operation Subsequent to operation Represent~ive Daily Average Production or Iniection D~a OiI-Bbl Gas-M~ Water-Bbl Casing Pressure 895 14900 50 895 14900 50 Tubing Pressure 550 550 15. Attachments Copies of Logs and Surveys run 117 Daily Report o~/Well Operations _~ Oil ~ Gas __ I hereby gmng is true and correct to. the best of my knowledge. Signed /~/~'/,"~' ~'r ,~, Title ~ / 6. Status of well classification as: Suspended Service Date ~'/9/?~/ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE L5-17 DESCRIPTION OF WORK COMPLETED REPERFORATIONS Date Event Summary 06-30-1996 07-01-1996 RIH w/2 1/8" EnerJet Strip guns and reperforated the following: 10848'-10868' MD (zone W4) 10898'-10918' MD (zone W4) 10925'-10933' MD (zone W4) 10937'-10942'MD (zone W4) 10949'-10954' MD (zone W4) 10966'-10985'MD (zone W4) 10988'-10999' MD (zone W4) All shots at 4 SPF, 0 (zero) deg phasing and random orientation. RIH w/2 1/8" EnerJet Strip guns and reperforated the following: 10730'-10750' MD (zone W6) 10775'-10795' MD (zone W5) 10800'-10810' MD (zone W5) 10818'-10848' MD (zone W5) 10880'-10890'MD (zone W4) All shots at 4 SPF, 0 (zero) deg phasing and random orientation. Well: L5-17 ffKB 2228 2229 2850 2851 4250 5631 5632 7915 7916 9508 9509 10133 10134 10245 10246 10275 10276 10344 10345 10355 10356 10480 10560 10740 10800- 10850 10800 10850 10900 10950 10900 NiP Per[ Per[ Perf Per[ Per[ GPMA WEB Date:515199 APl: 500292188900 Well Type: PROD SSSYType: CATI- SSSV Ori9 Compltn: 1/30/89 Annular Fluid: LIFT GAS Last W/O: Reference LDT/CNL SOS Ref Log Date: 1/24/89 Log: Last Tag: 11069 elm TD: 11142 ftKB Las~ Tag Date: 3/25/99 Max Hole 45 de9 @ 9100 Angle: ' Date Note 1/31/89 Minimum ID: 2.205" OTIS XN NIPPLE @ 10344' ELMD RECOMPLETED WORKOVER 7/16/91 Angle ~ TS: deg~ Angle ~ TD: 33 deg @ 11142 Last Update: 414!99 Date Note 1/31/89 Welt Status: ACTIVE 1/31/89 Tubing H~nger: FMC GEN 4A @ 33' MD Last Tag Depth ~ 11142 Top Of Fluid ,_D.e.~t_~h~ 10_534 ~her (plu~s,, e qu i p; etc);~EWELRY Depth TVD Type Description ID 2124 2124 TRSSSV 3-1/2"AVA13CRTRSSS~ ID=2.812" 28t0 10245 8509 XO 3-1/2" X 2-7/8" CROSSOVER (ELMD) 2,000 10275 8532 PKR 7-5/8" X 2~7/8" BAKER HB PACKER, ID=2 34" (ELMD) 2340 10344 8584 NIP 2~7/8" OTIS XN NIPPLE, ID=2.313", W/NO GO, ID=2 205" (ELMD) 2310 Size Weight Grade Top Btm Feet Description 10.750 45.50 J-55 0 4250 4250 SUR CASING 7,625 29.00 L-80 0 10480 10480 PROD CASING 5500 17.00 L-80 10293 11142 849 LINER 3500 930 L-80 0 10245 10245 TUBING4PC 2875 6.50 L-80 10245 10355 110 TUBING-IPC Stn MD TVD Man Man VMfr VType VOD Latch Port TRO Date VIv Mfr Type Run Comment ', 1 2228 2228-KBUG-L CA E 10 BK-2 0,000 0 CIM Stn MD TVD Man Man VMfr VType VOD Latch Port TRO Date Vlv Mfr Type Run Comment 1 2850 2849 MERLA TG CA RD 1,5 TG 0000 0 5/28195 GLM 2 5631 5091 MERLA TG TE D-14R 15 TG 0000 0 GLM 3 7915 6789 MERLA TG CA RD 1.5 TG 0.000 0 5/28/95 GLM 4 9508 7954 MERLA TG TE D-14R 1.5 TG 0,000 0 GLM ' 5 10133 8424 MERLA TG CA RD 1,5 TG 0.000 0 5/28/95 GLM interval TVD 10540- 8734-8769 10584 10608- 8787-8884 10730 10730- 8884- 890t 10750 10775- 8921-8996 10868 10880- 9006-9097 10990 Zone Status Feet SPF Date Type Comment C 44 0 Sqz SELECTIVE SHOTS (9) 122 0 SELECTIVE SHOTS (16) 20 4 7/1/96 APERF ADDPERFS 93 4 7/1/96 APERFSS(80'SHOT @ 4 SPF), ADDPERFS 110 46/30/98APERFSS(78'SHOT @ 4 SPF), ADDPERFS 1. Type of Request: 2. Name of Operator STATE OF ALASKA ALA,~r~ OIL AND GAS CONSERVATION COMMI~:::~ION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ AR(~Q Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1823' FSL, 155' FEL, Sec. 2, T11N, R15E, UM At top of productive interval 2018' FSL, 265' FWL, Sec. 2, T11N, R15E, UM At effective depth 2018' FSL, 265' FWL, Sec. 2, T11N, R15E, UM At total depth 2016' FSL, 44' FEL, Sec. 3, T11N, R15E, UM 12. Present well condition summary Total Depth: measured true vertical 1 1 1 42' feet 9224' feet Effective depth: measured 1 0540' feet true vertical 8733' feet Other 6. Datum elevation (DF or KB) RKB ,55' 7. Unit or Property name PRUDHOE/LISBURNE UNIT 8. Well number L5-17 9. Permit number/approval number 88-139 10. APl number 50-029-21889-00 11. Field/Pool LISBURNE OIL POOL Plugs (measured) NONE Junk (measured) NONE Cemented Measured depth True vertical depth Casing Length Size Structural Conductor 8 0' 2 0" Surface 4 25 0' 1 0 - 3 / 4" Intermediate Production 1 04 80' 7 - 5 / 8" Liner 8 4 7' 5- 1 / 2" feet 2150 lb. Polset 1600 sx AS III & 350 sx Class G 325 sx Class G 150 sx Class G Perforation depth: measured 10540-10917' true vertical 8733-9036' Tubing (size, grade, and measured depth) 2-7/8" L-80, tbg w/tail @ 10315' WLM Packers and SSSV (type and measured depth) Pkr @ 10245', & AVA-SSSV @ 2094' 13. Stimulation or cement squeeze summary 14. 115' 115' 425O' 4O89' 1O48O' 8687' 10293-11140'8550-9223' RECEJV£D Intervals treated (measured) Wahoo 7,6,5,4 Treatment description including volumes used and final pressure please refer to the attached Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 673 4034 43 Tubing Pressure 517 661 1712 8695 375 Service Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended 17. I hereby certify that the foregoing is true ~,,~d correct to the best of my knowledge. Si~ned ~'"~"- ~~~- Title Lisburne Operations Engineering Aide Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE ]Date 6/28/91: Lisburne Well L5-17 Stimulation Procedure Event Rigged up Halliburton Services. Pressure tested lines - ok. Closed fracture acidized Wahoo 7, 6, 5 and 4 perforations from 10,540' to 10,917' MD with the following fluids: 1,808 BBL Emulsified Acid 1,100 BBL Gelled Water 672 BBL Crude Return well to production. RECEIVED JUN - 8 1992 OjJ & Gas Cons. ~;ommissio~ Anchorage /'-'" STATE OF ALASKA ~ 0 R i ALAbr,,A OIL AND GAS CONSERVATION COMMISSI~., ~ ' ' ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing X Alter casing Repair well Perforate Other X WORKOVER 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1823'FSL, 155'FEL, SEC. 02, T11N, R15E At top of productive interval 2018' FSL, 265' FWL, SEC. 02, T11N, R15E At effective depth At total depth 2016' FSL, 44' FEL, SEC. 03, T11N, R15E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55' feet 7. Unit or Property name Prudhoe Bay Unit/Lisburne 8. Well number L5-17 9. Permit number/approval number 88-139 / 91-207 10. APl number 50- 029-21889 11. Field/Pool Prudhoe Bay Field/Lisburne Pool 12. Present well condition summary Total depth: measured true vertical 11142'MD feet Plugs (measured) 9924'TVD feet bkb Effective depth: measured true vertical 11094'MD feet Junk (measured) 9183'TVD feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length .. 85' 4220' 10450' -. 847' Size Cemented Measured depth 20" 2150# Poleset 115' 10-3/4" 1750 sx 4250' 7-5/8" 325 sx 10480' 5-1/2" 150 sx 10293'-11140' 10540'- 10584' (9 perfs), 10608'- 10744' (16 perfs), 10777'- 10865' (16 perfs), 10883'- 10917' (6 perfs) 8623'-8658' (SS), 8676'-8785' (SS), 8812'-8883' (SS), 8898'-8934' (SS) True vertical depth Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80 @ 10326' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary None Baker "HB" Retrievable Packer @ 10245'; AVA 13 Cr SSSV @ 2124' 14. Intervals treated (measured) JAN 2 7 992 Treatment description including volumes used and final pressure Alaska 0il & Was Cons. Re_oresentative Daily Average Production or Iniection Data Al3l;horagu Prior to well operation Subsequent to operation 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 classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~___~ ~~ TitleWorkoverEn~lineer Form 10-4{34 Rev 06/15/88 Date SUBMIT IN DUPLICATE ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK LISBURNE L5-17 NABORS 2ES KILL: 9.5 NDNU: 10.0 07/15/91 ( 1) L/D COMP ASS'Y. MW: 8.3 Seawater TD:ll142 RIG ACCEPTED @ 11:30 HRS, 7/14/91. R/U TO KILL WELL. PUMP PB:ll139 DN TBG, ANNULUS. SET BPV. N/D TREE. N/U BOPE. TEST BOPE. SUPV:RBMGTT PULL HGR TO FLOOR. SPOT 100 BBLS HEC PILL. POOH W/ COMP ASS'Y. DAILY:S63,170 CUM:$63,170 ETD:S63,170 EFC:$547,000 PTBG: 6.5 TCSG: 6.5 RCMP: 11.0 07/16/91 ( 2) RIH W/ COMP ASS'Y. MW: 8.3 Seawater TD:ll142 L/D COMP ASS'Y. TEST BOPE. R/U W/L. RIH. TEST CSG TO PB:ll139 3500 PSI. OK. R/D W/L. RIH W/ 3-1/2" COMP ASS'Y. SUPV:RBMGTT DAILY:S25,928 CUM:$89,098 ETD:S89,098 EFC:$547,000 NDNU: 5.0 RCMP: 9.0 07/17/91 ( 3) RIG RELEASED. MW: 8.3 Seawater TD:ll142 RIH W/ 3-1/2" COMP ASS'Y. STING INTO PBR. TEST. M/U HGR. PB:ll139 DISP HOLE W/ SEAWATER, 100 BBLS DIESEL. LAND TBG. TEST TBG SUPV:RBMGTT ANNULUS. SET BPV. N/D BOPE. N/U TREE. TEST TREE. SET BPV. SECURE WELL. RIG RELEASED @ 20:00 HRS, 7/16/91. AVA SSSV @ 2124' BAKER 'HB' PKR @ 10244' TT @ 10325'. DAILY:$289,9~5 CUM:$379,033 ETD:$3~9,033 EFC:$547,000 RECEIVED JAN ? i99 Alaska Oil & Gms Cons. ~ommtsSto~ Anchorage ARCO ALASKA INC. LISBURNE ENGINEERING DATE: FROM: September 12, 1991 Laura S. Lahrson ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: Log: Well /qo5-31 L5-17 ~-32 Tape: Well Report Well L4-32 Type Run Perforating Record 1 Perforating Record 1 Production Profile 1 Jewelry Log 1 Production profile 1 Dual Propagation Resistivity-GR-MD I Dual Propagation Resistivity-GR-TVD 1 Type LIS Tape DPR-RWD Data (with report) Type Final Well Report RUn Run Date// Company 8/9/91 q/[~/q{ Schlumberger 8/19/91 Schlumberger 8/7/91 Camco ,, 8/8/91 Camco 8/8/91 Camco 8/7-19/91 Teleco 8/7-19/91 Teleco Run Date 7/23/91 8128191 Date 9/4/91 Company Atlas Teleco Company Teleco SIGN AND RETURN TO: LAURA S. LAHRSON; ATO 409 ARCO ALASKA, INC. P.O. Box 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED BY: Exxon BPX AOGCC D&M TRANSMITTAL # 649 RECEIVE 1991 ~nchorage C°mrnlssto~, ARCO ALASKA INC. LISBURNE ENGINEERING DATE: FROM: July 12, 1991 Laura S. Lahrson ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: LOGS: Well Type (1 blueline, 1 sepia) L1-02 Production Profile Run Run Date Company L1-09 Production Profile Production Profile Production Profile 1 6/17/91 Camco I 5/30/91 Camco 1 5/30/91 Camco 1 5/30/91 Camco SIGN AND RETURN TO: LAURA S. LAHRSON, ATO 409 ARCO ALASKA, INC. 700 G STREET; ATO 409 ANCHORAGE, ALASKA 99510 RECEIVED BY: Exxon BPX AOGCC D&M TRANSMITTAL # 645 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. STATE OF ALASKA A,_~SKA OIL AND GAS CONSERVATION COMMI~,ION APPLICATION FOR SUNDRY APPROVALS OR IGiNA Abandon __ Suspend ~ Operation Shutdown ~ Re-enter suspended well__ Alter casing __ Repair well __ Plugging ~ Time extension __ Stimulate ~ Change approved program __ Pull tubing X Variance ~ Perforate ~ Other __ 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic ~ Service 11142'MD feet Plugs (measured) 9924'TVD feet bkb 11094'MD feet Junk (measured) 9183'TVD feet BKB 4. Location of well at surface 1823' FSL, 155' FEL, SEC. 02, T11N, R15E At top of productive interval 2018' FSL, 265' FWL, SEC. 02, T11N, R15E At effective depth Size Cemented Measured depth At total depth 2016'FSL, 44'FEL, SEC. 03, T11N, R15E 12. Present well condition summary Total depth: measured true vertical measured true vertical Length .. 85' 20" 2150# Poleset 115' 4220' 10-3/4" 1750 sx 4250' 10450' 7-5/8" 325 sx 10480' ._ 847' 5-1/2" 150 sx 10293'-11140' measured see attached true vertical subsea see attached Effective depth: 6. Datum elevation (DF or KB) KBE = 55' feet 7. Unit or Property name Prudhoe Bay Unit/Lisburne 8. Well number L5-17 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9. Permit number 88-139 10. APl number 5O- 029-21889 11. Field/Pool Prudhoe Bay Field/Lisburne Pool True vertical depth Tubing (size, grade, and measured depth) 2-7/8"to 10326' Packers and SSSV (type and measured depth) Packer@ 10245', SSSV@ 2094' Description summary of proposal x Detailed operations program 15. Status of well classification as: Commissioner Oil X Gas 13. Attachments 14. Estimated date for commencing operation July 15, 1991 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~ Title Workover Engineer FOR COMMISSION USE ONLY BOP sketch Suspended Date IApproval No{~:::~/""~-d~ ~' / Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance Mechanical Integrity Test ~ Subsequent form required Approvea Approved by order of the Commission ,t~,~t~-~ ~ Form 10-403 Rev 06/15/88 0RtGINAL ~' .... LONNIE C. Date '~ LISBURNE L5-17 WORKOVER PRELIMINARY PROCEDURE OBJECTIVES' Replace the current 2-7/8" completion with 3-1/2" equipment. 7/8" tubing is buckled above the completion packer. The 2- PROCEDURE: 10. 1. Set BPV. MIRU AUDI Rig #4. 2. Pull BPV. Kill tubing by circulating/bullheading with 8.5 sea water. 3. ND tree, NU and test BOP's. 4. Engage tubing hanger. Pull and LD the 2-7/8" tubing. Inspect PBR seal assembly. 5. RU slickline. RIH and set positive plug in tubing tail XN nipple. POOH and RD. 6. Pressure test 7-5/8" x 5-1/2" casing to 3500 psi. 7. Run 3-1/2" completion tubing with GLM's, CIM, and 1/4" treater Space out tubing. Displace well to clean inhibited seawater. 8. Land tubing. Circulate diesel down annulus thru circ valve to freeze protect. and annulus. 9. Set BPV. ND BOPs. NU & test tree. Move Rig. Pull BPV. 11. Turn well over to production. string. Test tubing Bottom Hole Pressure: 3500 PSI @ 8800' Sub Sea Workover Fluid: 8.5 PPG Sea Water ,~7"..~- BOP STACK CONFIGURATION ATTACHMENT II 13 5/8", 5000 PSI WP TRIPLE RAM STACK WORKO VER I RISER ANNULAR PREVENTER PI PE RAMS ! ! PIPE RAMS i I DRILLING SPOOL I I BLIND RAMS I 2" KILL LINE MANUAL HYDRAULIC GATE GATE 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. ~ype oT Meques[: Abandon Suspend Alter casing.__ Repair well Change approved program Operation shutdown Re-enter suspended well Plugging Time extension Stimulate__~ Pull tubing Variance Perforate Other 2. Name of Operator ARCO ALASKA INC. 3. Address P.O. BOX 100360 ANCH. AK 99510 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 1823' FSL, 155' FEL, Sec. 2, T11N, R15E,UM At top of productive interval 2018' FSL, 265' FWL, Sec. 2, T11N, R15E, UM At effective depth 2018' FSL, 265' FWL, Sec. 2, T11N, R15E, UM At total depth 2016' FSL, 44' FEL, Sec. 3, T11N, R15E, UM 6. Datum elevation (DF or KB) RKB 55' feet 7. Unit or Property name Prudhoe/Lisburne Unit 8. Well number L5-17 9. Permit number 88-139 10. APl number 50-029-21889 11. Field/Pool LISBURNE OIL POOL 12. Present well condition summar, y Total depth: measurea 11142' true vertical 9224' feet feet Plugs (measured) NONE Effective depth: measured 10540' true vertical 8733' feet feet Junk (measured) NONE Casing Length Size Structural Conductor 80' 20" Surface 4250' 10-3/4" Intermediate Production 10480' 7-5/8" Liner 847' 5-1/2" Cemented 2150 lb. Poleset 1600 sx AS III & 350 sx Class G 325 sx Class G 150 sx Class G Perfor.ation depth: Measured Depth 10540'-10917' True Vertical Depth 8733'- 9036' Tubing (size, grade, and measured depth) 2-7/8" L-80, tbg w/tail @ 10,315' WLM Packers and SSSV (type and measured depth) Pkr @ 10245', & AVA-SSSV @ 2094' Measured depth Trueverticaldepth 115' 115' 4250' 4089" 10480' 8687' 10293'-11140' 8550'-9223' RE¢£1V D MAY 1 6 t991 Alaska 0il & Gas Cons. C0mmiSS't0t~ Anchorage 13. Attachments Description summary of proposal_~x Detailed operations program BOP sketch~ 14. Estimated date for commencing operation May 21, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oilx_ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,qned ''~ ~'- /,~i1;.,~.~,'7/ T.E. Krawietz Title:Sr. OperationEn,qr. ,/ l~ FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative my witness ! Approval No. Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 1 O- ORIGINAl SIGNED BY Approved by order of the Commission LONNIE C. SMITH Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATI- r 4~ Lisburne Well L5-17 Stirnulatio~ Procedure 1. Pull gaslift Valves and install dummy GL V's. s. ' COntrol provided by Surface Closed Fracture &cidize Wahoo 7, 6 6500 psi With the followin~ s~-- · 7, 5 and 4 at chokes and · maximum I00 bbls ~5% l~el . o "mulation fluids: treating pressure o£ ' 1200 bbls 4,~ o led HCL. 900 bbls cru~eu cru~le/lO% I-ICL emulsified acid. Re/ease Service COmpany and Open Well ~o flo~v. Static BPIp = 3918 psig at 8900' ss. 3~ RECEIVED MAY 1 6 199t Alaska 0ii & Gas Cons. Oommissioa Anchorage .- STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well 2. Name of Operator 7. Perr~t..1N.~mber ARCO Alaska, Inc. 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 029-21889 · , 4. Location of well at surface 9. Unit or Lease Name 1823' FSL, 155' FEL, Sec. 2, T11N, R15E, UM r~ Prudhoe Bay Unit/Lisburne At Top Producing Interval~~ 10. Well Number 2018' FSL, 265' FWL, Sec. 2, T11N, R15E, UM L5-17 At Total Depth 11. Field and Pool 2016' FSL, 44' FEL, Sec. 3, T11N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ' --'--" Li sburne 0i 1 Pool RKB 55'[ ADL 28320 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01/08/89 01/23/89 02/1.6/89' N/A feet.MSL 1 ,, 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 11142'MD/9224'TVD 11094'MD/9183'TVD YES [] NO [] 2094' feet MDI 1900' (approx,) . 22. Type Electric or Other Logs Run D IL/NGT/SP, LBT/CNL/CAL/GR, GCT ~ CL/GR/CNL/CBT/CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,, 20" 91.5# H-b,O .~.,r f 11~;' 30" 2!50# Po~. eset 10-3/4" 45.5 J-55 R,.r-f z~?Br~' 13-!/?" !600 sx AS !!! & 350 sx 2~.~ss G. Tep job w/!50 sx .~.S I 7-5/8" 29.7# L-gO -~,.rf 10480' 9-7/8"j 325 s.x ¢'1.___ G 5-1/2" 17.0# L-R0 I 102q~' 11140' 6-_R/M'I~ !50 sx C~.___ G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) .... 2-7/8" 1 0326 ' 10245 ' See Attached .. 26. ACID, FRACTURE, CEMENT SOUEEZE', ETC. DEPTH INTERVAL (MDi AMOUNT & KIND OF MA'~'ERIAI[. USED See attached Well l~ork log, dated 2/16/89, for fracture data 27. N/A PRODUCTION TEST ........ Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GA$-MCF wATER-B'I~L CHOKE SIZE I'GAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATEDdk OIL-BBL GAS-MCF' wATER-BBL elL 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. None Fractured well 2/16/89. ,,, Form 10-407 015/WC6 CON'I~'NuED ON REVERSE SIDE Rev. 7-1-80 Submit in duplicate 29. GEOLOGIC MARKERS NAME Top Wahoo Zone 6 Top Wahoo Zone 5 Top Wahoo Zone 4 Top Wahoo Zone 3 MEAS. DEPTH 10603' 10759' 10877' 11105' TRUE VERT. DEPTH 8783' 8907' 9003' 9193' 30. FORMATION TESTS Include interval tested, pressure data, alt fluids recovered and gravity, GOR, and time of each phase. No ne 31 LIST OF ATTACHMENTS,^ 'Well Hisf, ory, Gyrotz copies), Well Work log (dated 2/16/89) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Regional Drilling Engr. Date 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 welt 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- lng and 'the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: if no cores taken, indicate "none". Form 10407 Date Job Code ,~ []SL []CL []CTU Description of Work SSSV Pulled Carrier Pulled (assoc. w/Kvalve) Recover. Diesel / ~ S$SV Remarks INon Recov. Diesel SSSV Pulled Set. No.} SSSV Ran I SSSV Ran Ser. No. Carrier Ser. NO. []Carrier Ran (assoc. wlKvalve) ICarrier Ser. No. I Tubular Casing Problems Well Work Lo~ IOS/W~ -~-rx'.. I z. 5"-/7 Tbg/TT 5_ize~. S$SV Nipple .Z~¢ ,4,,,,¢ Min. Rest,IDeptl~ SiTP(. - Cost Estimate Remarks /.~A~. Remarks Remarks ,5: Remarks Remarks S $ $ S $ AFE No. ~ CC# Time ..... , Log Entry ,i _/ Page of Complete [:~ Incomplete Time Log entry F= ~-,. ~~.~ ....... ,,, , , ,, , , , , ,, , ~ , ~ ~ ~ ~ ~~ ~ .... ...... ~ ~ ~~ ,, ~ ~. ~~ ,, .... ~ ~, ~ ~~s , , , ,. . ,, , ,., ,, ,, . , , , , . ~ . , ,, , ~ , . , , , , , ..... $UB-$URFACE DIRECTIONAL ~URVEY I~]UIDANCE I~]ONTINUOUS I~OOL Company A,RC.,O ALAS, KA~ INC. Well N~me .LI, SBURNE L5r17 (18,23' FSL~15,5' FEL,SEC 2'TllN,R, 15E,UM) Field/Location PRUDHOE BAY/L,,,,ISBURNE POOLz,N.,O,RTH SLOPE~ALASKA Job Reference No. 73134' . SCHWARTZ Date 28-JAN-89 Comput,ed By: KRUWELL GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO AL&SK~ INC. LISBURNE L5-17 PRUDHOE 8AY/LISBIJRNE POOL NORTH SLOPE, AL/~SKA SURVEY DATE: 28-JAN-g9 ENGINEER: SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVSRAGED D~VIATION AND AZIMUTH INTERPOL&TION: LINE.~R VERTICAL SECTION: MORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH fl~ NORTH 85 DEG ~T MIN WEST CJMPUTATI,_,N O~TE: ARCg ~L~$KA [NC. L[SSURN~ L5-17 PRUDHOE 8AY/L[S~URNE NORTH SLOPE, AL&SKA POOL INTERPOLATED VALUES FOR EVEN 100 TRU MEASIJReD VERTT UEPTH DeP SU'5-SE ~, CAL VERTICAL D15VIATION TH DEPTH DEG MIN -55 gO .g O 145.00 0 126 .99 0 16 .99 .99 0 10 .99 0 24 .99 0 9 .99 0 22 .99 0 5 0.00 O.O0 100.00 100.00 200.00 ZO0.O0 300.00 299.99 244 400.00 399.99 344 500.00 499.99 444 600.00 599.99 544 700.00 699.99 644 800,,00 799.99 744 900.00 899.99 844 COUR S ? V ERT IC AL A!IMtJTH SECTION D'5G M'[N FEET N 0 O ¢ 0.00 S 39 55 .: -0.26 S 35 22 ~ -0.80 S 51 25 E -1.'37 S 38 13 E -1.:31 S 42 45 E -2.30 S 41 28 E -2.61 S 58 3 F -3.05 S 56 19 F -3.38 S 23 20 E -3.69 1000.00 999.99 944 1100.00 1099.99 1044 1200.00 1199.98 11t4 1300.00 1299.98 1244 1400.00 1399.98 1344 1500.00 14}9.98 1.444 1600.00 1599.9~ 1544 lfO0.O0 1699.91 1644 1800.00 1799.95 1744 1900.00 1899.95 1844 .99 0 6 .99 0 11 .98 0 10 .98 0 11 .98 0 15 .98 0 29 .98 0 .97 0 52 .96 0 51 .95 0 46 S 81 23 15 -3.93 S 31 25 E -4.00 S 68 54 E -4.31 S 54 ? E -4.59 S 40 42 E .-4.39 S 54 13 E -5.34 S 74 29 ~ -6.19 N 88 7 f -7.50 N 83 32 E -9.01 S ~5 17 F -10.37 2000.00 1999.94 1944.94 ZIO0.OO 2099.93 2944.93 g200.O0 2199.92 2144.92 2300.00 2299.90 2244.90 Z400.00 2399.89 2344.~9 ZSO0.OO Z499.8'? 2444. ~7 Z600.gO 2599.87 2544. ;~7 2700.00 Z699 . 80 2644. ~0 Z800.OO 2799.59 2744. 59 zgo0.oo 2898.93 2a43.93 0 48 0 51 0 52 0 55 0 43 2 51 4 50 8 19 S 84 23 E -11.73 S a~ 47 E -13.18 S 95 33 E -14.70 S ~4 58 ; -16.29 S 99 ~ E -18.12 S 9'3 9 ~ -19.93 S ~q 56 W -19.96 N R2 40 W -16.45 N 85 26 W -10.01 S ~ 59 W 1.27 3000.00 2991.27 3100.OO 3094.05 ]ZO0.O0 3189.6.7 3300.00 3284.53 3400.00 3378.95 3500.00 3472.65 3600.00 3564.27 3700.00 3653.84 3800.00 3740.41 3900.00 3823.03 2942.27 12 30 3039.05 16 3134.67 17 47 3229.53 18 55 3323.9~ 19 3417.65 Z1 46 3509 27 3598.~4 27 4R 368~.4! 32 29 376~.03 35 21 S ~1 47 W 18.91 S R3 24 W 43.47 S ~5 51 W 72.34 S ~7 44 W 103.70 S 39 46 W 136.~5 N ~'~ 4'~ W 171.30 N ~9 29 W 211.22 N ~9 10 W 255.59 N 99 0 W 305.50 N 37 i6 W 361.75 13-FE9-89 KELL~ gATE OF SURVEY: ~USH[NG FLFV~TION: ENGINEER: FEET OF MEASURED DEPTH 90GLEG RECT~NGULAP. SEVERITY NO~TH/SOUTH DEG/IOO ~E~T CSORDIN~TES E~ST/.~EST FEFT 0.00 0.00 N 0.~0 E 0 22. 0 15 S. 0 '~5 E.~. 1,04 0.64 'S 0.76 E 0.3r 1.11 S 1.2'~ :~ 0.20 1.65 S 1.69 E 0.31 2.08 S 2.15 E 0.45 2.45 S 2.43 ~ 0.33 2.75 S 2.85 E 0.25 3.03 S 3.16 E 0.06 3.18 S 3.46 F 0.32 3.37 S 3.70 0.47 3.45 S 3.76 0.00 3.66 S 4.05 0.13 3.75 S 0.00 4.03 S 4.61 0.14 4.4;' S 5.02 0.37 4.89 S 0.14 4.99 S 7.15 0.08 4.87 S 8.67 0.36 4.87 S 10.04 0.00 5.0i $ 0.00 5.14 S 0.04 5.28 S 0.00 5.41 S O.OO 5.53 S 1.08 5.60 S 2.73 5.73 S 1.61 5.~5 S 3.07 4.59 S 4.42 4.59 S 11.40 12.84 14.35 15.94 17.76 19 ~7 19.60 16.10 9.6 :-) 1.61 4.83 6.82 S 2.64 10.16 S 1.46 12.81 S 0. 85 14.~:8 S 1.19 15.26 S 3.5~ 15.18 S 2.65 15.05 S 3.63 14.40 S 5.04 13.67 S 1.59 11.87 S 19.47 44.34 73.47 105.06 137.9~ 172.89 212.90 257.34 307.33 363.60 HORIZ. gIST. FEET PAGE 1 28-JAN-89 55.00 FT SCHWARTZ DEPARTURE ~ZlMUTH DEG 0.00 N 0 0 E 0.29 S 60 0 E 1.00 S 49 39 E 1.70 S 49 13 E 2.36 S 45 42 E 2.9'9 S 45 52 E 3.45 S 44 46 E 3.96 S 46 6 E 4.39 S 46 15 E 4.70 S 47 23 E 5.00 S 47 38 E 5.10 S 47 27 E 5.46 S 47 53 E 5.73 S 49 ~ E 6.13 S 48 49 E 6.72 S 48 20 E 7.62 S 50 5 E 8.72 S 55 6 E 9.95 S 6~ 39 E 11.16 S 64 7 E 12.45 13.83 15.29 16.83 18.60 Z0.36 20.42 16.96 10. '73 4.85 S 66 16 E S 68 10 E S 69 47 E S 71 14 E S 7241 E 574 1E S 73 42 E S 71 38 E S 64 38 E S 1'~ ZZ W 20.63 S 70 41 W ~.5.49 S 77 5 W 74.58 S 89 6 W 106.0~, S BZ 5 W 138.78 S 83 41 W 173.5~ S R~' 59 W 213.43 S 85 57 W 257.75 $ 86 ~7 W 307.63 S 87 27 W 363.79 S 88 7 W ARCO ALASKA iNC. L[SBURNE L5-17 PRUDHDE 8~Y/LISBURNE NORTH SLOPE, ALASKA POOL COMPUTATION D~T:: 13-FEB-89 D~TE O~ SURVEY: KELLY 5USHING ELEVATION: ENGINEER: PAGE Z ZS-J~N-89 55.00 FT SCHWARTZ TRUE MEASURED VERTICAL DEPIH DEPTH 4000.00 3903.34 ~.100.00 3918,94 4200.00 4052 4300.00 4125.18 4400.00 4198.57 4500.00 427Z.24 4600.00 4346.34 4'7,00.00 4420.11 4800.00 4492.89 4900.00 4564.9? 5000.00 4636.44 5100.00 4707.91 5ZOO.O0 4779.20 5300.00 4850.67 5400.00 4922.64 5500.00 4995.00 5600.00 5067.45 5700.00 5140.66 5800.00 5214.91 5900.00 5289.96 6000.00 5365.19 6100.00 5440.40 6ZOO.O0 5515.72 6300.00 5591.12 6400.00 5656.63 6500.00 5742.7'1 6600.00 5818.52 67'00.00 5893.54 6800.00 5968.42 6900.00 6042.9J ?000.00 6117.01 llO0.O0 6190.81 7200.00 6Z64.40 7300.00 6337.83 7400.00 6410.73 7500.00 6483,7,2 7600.00 6556,95 7700.00 6630.1S 7d00.00 6703,36 7900.00 6777.31 INTERPOLATED VALUES FOR COURSE DEVIATION AZIMUTH PEG MIN DEG MIN SUB-SEA VERTIC,~.L DEPTH 3848.34 N 88 21 W 3923.94 ~ N 89 31 W 3997.07 ' ; N 99 3 W 4070.18 42 54 N ~ 42 W 4143.57 42 42 N 88 46 W 4217.24 42 21 N ~B 1~ W 4291.34 42 1 N 88 ~ W 4365.11 42 54 N 88 9 W 443~.89 43 42 N 87 30 W 4509.97 44 4 N ~7 19 W 4581.44 44 28 N ~7 1 W 4652.91 44 29 N 85 37 W 4724.?.0 44 30 N 84 3.3 W 47,95.67 44 ]2 N R4 1~ W 4867.64 43 43 N 83 35 W 4940.00 43 37 N ~3 19 ~ 5012.45 43 23 N 03 39 W 508~.66 42 25 N ~4 T W 5159.91 41 39 N 94 !3 W 5~34.96 41 12 N ~4 9 W 5310.19 41 16 N ~4 10 W 5385.40 41 5 N 93 ~l W 5-%60.72 4t 11 N 33 47 W 55'36.!2 40 58 N 93 45 W 5511..53 40 49 l',J93 47 W 5587.71 ~0 21 N ~3 43 W ~763 52 41 l N 83 0 W 5913.42 ~1 44 N ~4 ~S W 5987.93 41 58 N ~4 53 W 6062.01 42 2Z N 6135.8! 42 32 l'J 86 20 W 6209.40 42 36 N 96 50 W 6282.83 42 58 N ~7 20 W 6355.13 43 17 N 87 ag W 6501.95 42 56 N ~7 20 W 6575.15 42 5q N ~7 iK W ~64~.36 42 40 N 97 ~q W 6722.~1 42 1 N 88 ~ W EVEN t. O0 VERTICAL SECTION FEET 42! .28 486.58 554.66 ,522.79 690.62 758.16 325.26 392.71 961.24 10~0.53 1100.45 1170.39 1240.~0 1310.43 ].379,82 1448.78 1517.66 1585.73 1652.69 1718.75 1784.61 !~350.48 1916.21 1981.86 2047.38 2112.24 2177.39 2243.33 2309.70 23?6.39 2443.56 2511.03 2578.73 2646.59 2715.02 27,83.33 2851.40 2919.51 2987,.60 3054.~7 '~E ~SURED DEPTH DOGLEG RECTANGULAR COORDINATSS FORIZ. SEVERITY NORTH/SOUTH E~ST/WEST DIST. OEG/IO0 FE'ET ;EfT FEET 5.57 2.17 0 0.25 0.44 O .47 0.82 0 0.94 0.7'1 1.31 0 .5~ 0.43 0. 7,1 0.51 0.73 1 .07 1.19 0.11 0.24 0.57 0.26 0.36 1.12 0.77 0.53 0.72 0.61 0.40 0.61 0.98 0.39 0.96 0.46 0.39 0.05 0.19 1.35 0.61 9.36 S 423.11 W 423.21 8.32 S ~8.5'1 W 488.58 7.52 S 556.71 W 556.76 6.12 S 624.q2 W 624.95 4.68 S 692.84 W 692.85 2.96 S 760.43 W 760.44 0.84 S 827.55 W $2'1.55 1.32 N 895.03 W 895.03 3.89 N 963.56 W 963,57 7.09 ti 1032.80 W 1032.82 10.47 ,N 1102.65 W 1102.7,0 14.88 N 1172.45 W 1172.55 20.97 N !242.31 W 1242.49 27.77 N 1~11.93 W 1312.22 35.08 N 1380.97 W 1381.4! 47.02 N t449.54 W 1450.17 50.86 N 1518.02 W 1518.87 58.11 N 1535.74 W 1586.81 64.85 N 1652.39 W 1653.66 71.59 r,l 1718.13 W 1719.62 78.26 N 1'783.6~ W 178~.39 85.19 N 1849.21 N 1851.17 92.42 N 1914.59 W 1916.82 99.52 N 1979.89 W 1982.39 1.06.68 N 2045.0? W 2047.85 113.64 N 2109.59 W 2112.65 121.21 N 2174.3,5 W 2177.73 128.89 N 2239.92 W 2243.62 135.61 N 2305.97 W 2309.95 141.66 N 2372.39 W 2376.62 147.43 N 2439.32 W 2443.77 152.24 N 2506.62 W 2511.24 156.14 N 2574.22 W 2578.95 159.58 N 2642.01 W 2646.82 162.47 N 2710.40 W 2715.27 165.11 N 2778.70 W 27;33.61 168.13 N 2846.73 W 2851.69 171.34 N 2914.B0 W 2919.83 1 7,4.48 N 29~2. 84 W 29.'37.94 176.94 N 3050.11 W 3055.24 OEP~RTIJRE ~kZIMUTH OEG MIN S 88 43 W S 89 1W S 89 13 W S 89 26 W S 89 36 W S 89 46 W S 89 56 W N 89 54 W N 89 46 W N 89 36 W N 89 27 W N 89 16 W N $9 1 W N 89 47 W N 88 32 W N 88 17 W N 88 4 W N 87 54 W N 87 45 W N 87 36 W N 87 29 W N 87 21 W N 87 14 W N 87 7 W N 87 0 W N 86 54 W N 86 48 W N 85 42 W N 86 38 W N 86 34 W N 86 32 W N 86 31 W N 86 31 W N 86 3Z W N 86 34 W It 86 35 W N 86 37 W N 85 38 W N 85 39 W N 86 40 W COMPUT~TIQN DATE: 13-FEB-89 ARCO ALASKA INC. LISBURN~ L5-17 PRUDHOE B~Y/LISEURN5 NORTH SLOPE, ALASKA POOL INTERPOLATED VALUES FOR EVEN !00 FEET T MEASURbD VER DEPTH D 3000.00 68 8100.00 69 8ZO0.O0 70 8300.00 B400.O0 71 8500.00 72 8600.00 72 8-'00°00 8800.00 74 8900.00 "5 RUE SU~-SEA TIC~L VERTICAL EPTH 51.87 ~7.03 02.46 ~7 52.11 25.98 99.24 ~1 4].60 14.92 DEVIATION 6947.t~6 ~4! B 7022.58 41 3~ 7097.11 42 4 7170.98 42 39 7Z44.24 43 ?BBS.60 44 10 7459.92 44 48 COURSE VERTICAL DDGL AZIMUTH SECTION SEVE DEG MIN FEET OEG/ N 38 16 W 3121.45 N ~7 ZI W ~187.36 N 87 3'9 W 325~.99 N 37 47 W 3~1~.95 N ~7 55 W 3385,59 N ~7 59 W ~452.~4 N ~7 5~ W 3520.96 N 88 I W 3589.83 N 87 55 W 3659.27 N 87 59 W 371~.31 9000.00 9100.00 9200.00 9300.00 9400.00 9500.00 9600.00 9100.00 9800.00 9900.00 1585.74 '1656.3B 7727.29 7799.79 7873.4Z 79-%7.28 8021.59 3096.25 ~171.63 5241.36 7530.74 45 1 7601.38 45 7 7677.29 44 1.3 7744.79 42 4~ 7~!ft.42 42 31 7~92. IR 42 7966.59 41 47 804 't.25 41 Z3 8116.6~ 40 49 8192,~6 40 44 N 87 54 W 3799.87 0 N 87 53 W 3~70.59 0 N ~ 8 W 3941.05 1 N ~9 5 W 4009.83 1 N 89 32 W 4077.38 0 N ~9 5! W 4144.63 0 S 89 4,3 W 4211.36 0 S 89 17 W 4277.67 1 S ~q 50 W 4343.11 0 S ?~ 37 W 4408.12 0 lO000.O0 10100.00 IOZO0.O0 IOBO0.O0 10400.00 10500.00 10600.00 10100.00 10~00.00 10900.00 83 84 86 ~7 23.09 98.87 T4.88 50.70 Z6.20 OZ .36 80.55 59.~5 40.29 Z1 .77 S q8 27 W 4473.11 0 S ?8 17 'd 4533.02 0 S 38 6 W 460Z.64 1 $ 88 ] 5 W 4667,48 S 3~ 7 W 4732.69 S 88 17 W 4797.10 2 S 87 53 W 4859,04 0 S '~9 I~ W 4919.60 S q9 43 W 497~.94 0 ~,! q9 52 W 5036.74 1 1100 1110 1114 0.00 0.00 Z.O0 91 91 92 .51 9049.51 33 28 9133.48 '52 41 9168.32 32 41 N ~9 46 W 5092.75 1 N 89 3q W 5146.93 0 N ~9 3q W 5169.56 0 KELLY DaTE OF SURVEY: ~USHING EL EV,~TION: ENGINEER: OF M[aSUPED D'EP'TH r'o RECTANGULAo COO RITY NgRTH/SOUTH E~S lOO =EET FE .22 179. .ZO 181. .15 1!4. .58 1~7. .48 189. .41 191. .86 194, .52 1 96. .54 199, .41 201. 28-J~N-89 55.00 FT SCHWARTZ .26 204.0) N ~795.12 W 3800.61 N 85 55 W .68 206.73 N 3865.85 W 1871.37 N 86 56 W .42 209.!4 q 3936.32 W 3941.88 N 86 57 W ,45 21.0.80 N 4005,17 W &OlO.71 N 86 59 W .35 211.60 N 40'12.84 W &078.33 N 87 1 W .34 211.91 N 4140,24 W 4145.66 N 87 4 W ,48 211.99 N ~207,16 W 421Z.49 N 87 6 W · 02 211.38 N 4273.6,~ W 4278.91 N 87 10 W ,53 210,29 N 4739.38 14 4344,47 N 87 13 W ,07 208.84 N 4404.67 W 4~09.62 N 87 17 W .Z9 207. .20 205. .10 203. .16 201. .00 1 )9. ,94 196. .60 194. .14 193. · 90 192. .75 192. 20 N 4469.96 W 4474.76 N 87 20 W 34 N 4535.1.~ W 4539.82 N 87 24 W 30 N 4600.13 W 4604.62 N 87 28 W l~ N 4665,30 W 4669.64 N 87 31 W 05 N 4730.94 W 4735.03 N 87 35 W 80 N 4795.60 W 4799.63 N 87 39 W 69 N 4857.86 W 4861.76 N 87 42 W 35 N 4918.67 W 4922,47 N 87 44 W 76 N 4978.22 W Agql.gq N 87 46 W 73 N 5036.1q W 5039,87 N 87 4~ W .18 192. .00 192. .00 193. 73 :4 5092.35 W 5095.~9 N 87 49 W 98 N 5146.65 W 51~0.27 N 87 51 W 11 N 5169.34 W 5172.94 N 87 51 W C3 N 3116.7! W 312.1.85 N 86 42 W 47 N 3132.63 W 3187.80 N 86 44 W 40 N 3248.22 W 3253.45 N 86 45 W 03 N 331~.17 W 3319.44 N 86 46 W 50 N 33,30.80 W 13386.11 N 86 47 W 87 ~"4 3448.16 W 3453.49 N 86 48 W 26 N 3516.19 W 3521.55 N 86 50 W 70 N 35~5,06 W 3590.45 N 86 51 W 13 N ~654.5.1 W ~659,93 N 86 52 W ~7 N 3724.57 W 3730.02 N 86 54 W RCIN~TES fiORIZ. DEPARTURE T/WEST giST. AZ'IMUTH ET FEET OEG MIN ARCO ALASKA INC. LISBURNE L5-17 PRUDHOE BAY/LISBURNE POOL NORTH SLOPEs ALASKA COMPUTATION DATE: 13-FE~-Sg PAGE 4 DATE gF SURVEY: 2B-JAN-89 KELLY ~USHING ELEVATION: 55.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 1000 FEET OF ME~SUPED DEPTH TRUE SUB-SEA ' COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DE:~ MIN DEG MIN o. o o o. oo-s soo S ~l 2~ E -~ g] 2000.00 1999.94 1944.94 ~'~' 8 S ~4 2~ E -11.73 3000.00 2991.27 2942.~1 1~ 30 Sql 47 W 18.91 4000.00 3903.34 3848.34' 38 31 N 88 21 W 421.28 5000.00 4636.44 4581.~4 44 28 N 87 t W 1100.~5 6000.00 5365.19 5310.19 41 16: N 84 10 W 1784.61 lO00.O0 611'1.01 6062.01 42 22 N 85 21 W 2443.56 8000.00 58~1.87 6796.87 41 35 N 88 15 N 312!.45 9000.00 75~5.7~ 7530.74 45 1 N 87 54 W )799.87 VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY N~RTH/SOUTH EAST/WEST DIST. ~ZIMUTH FEET OEG/10O FEET F ,:,. ET FEET DEG MIN 0.00 0.32 0.00 4.83 5.57 0.7! 0.24 0.61 0.22 0.26 0,00 N 0.0O E 0.00 N 0 0 E 3,~7 S 3.70 E 5.00 S 47 38 E ~.01 S 11.40 E 12.45 S 66 16 E 6.82 S 19.47 W 20.63 S 70 41 W 9.36 S 4233.11 W 423.21 S 8,~ 43 W 10.47 N 1102.65 W 1102.70 N 78.26 N 17~3.6~ W 17R~.39 N 1,47.43 N 2439.32 W 2443.77 N 86 32 W 179.03 N 3116.71 W ]121.85 N 86 42 W 204.09 N 3795.12 W 3800.61 N 86 55 W lO000.O0 5323.09 8268.09 40 46 llO00.O0 9104.51 9049.51 33 28 11142.00 9223.82 916R.32 32 41 S 88 27 W 4~73.11 N 89 46 W 5092.75 N 99 39 W 516'9.56 0 1.38 0.00 207.20 N 4469.96 W 4474.75 N 87 20 W 192.73 N 5092.35 W 50g5.99 N 87 49 W 193.11 N 5159.74 ,4 5172.94 N 87 51 W COMPUTe[ION D,~TE: 13-FEB-89 ARCO ALASKA INC. LISBURNE L5-17 PRUDHOE BAY/LISBURNE NORTH SLOPE~ ~LASKA PO3L TRUE Mt.~SUR~D VERTICAL DEPTH DEPTH 0.00 0.00 55.00 55.00 155.00 155.00 255.01 255.00 J55.01 355.00 455.01 455.00 555.01 555.00 655.01 655.00 155.01 755.00 855.01 855.00 955.01 955.00 1055.01 1055.00 1155.02 1155.00 1Z55.02 1255.00 1355.02 1355.00 1455.02 1455.00 1555.02 1555.00 1655.03 1655.00 1755.04 1755.00 1855.05 1855.00 1955.06 1955.00 Z055.07 Z055.00 2155.08 Z155.00 2255.09 Z255.00 Z355.10 2355.00 Z455.12 2455.00 2555.13 2555.00 Z655.16 2.655 -00 2'/'55.29 2755.00 2855.2'0 2855.00 2956.84 Z955.00 3059.46 3055.00 3163.65 3155.00 3268.81 3255.00 332'4.58 3355.0'3 3481.07 3455.00 3589.74 3555.00 3701.31 3655.00 3817.45 3755.00 3939.37 3855.00 INTERPOLATED VALUES SUB-SEA VERTICAL DEPTH DEG~MIN -55.00'::??~ O 0.00~ 100.00 5 200o00,: 0 25 3O0.O0 0 23 4OD.DO 0 22 500.00 0 15 600.00 0 18 700.00 0 12 800.00 0 8 COURS: DEVIATIgN AZIMUTH D=G M IN S 74 Z E s 56 11 ~ S s2 ! ~ S 33 1Z; S 51 4 E S 35 15 F S 39 40 ~ S 73 40 ~ 900.00 0 13 1000.00 0 2 1100.00 0 12 1200.00 0 9 1300.00 0 13 1400.00 0 19 1500.00 0 31 1600.00 O 46 1700.00 0 53 1800.00 0 45 56 0 35 56 10 76 20 43 36 37 54 6210 8649 ~5 3q ~6 50 FOR EVEN 100 FEE VFRT!C~L OOG S E C T i g h S E V FEET gEG 0.00 -0.05 -0~60 - 1.14 -1.58 -2.13 -2.44 -2.90 -3.19 -3.63 E -3.81 -3.97 E -4.17 E -~.46 E -4.76 E -5.08 E -5.77 E -6.84 -8.34 E -9.76 -1l.ll -12.52 -14.01 -15.57 -1T.Z3 -19.21 -20.25 -13.42 -13.31 -~.~3 10.43 3R.81 61.51 93.74 127.98 164.48 206. :,34 256.20 315.04 384.73 1900.00 0 45 ZO00.O0 0 49 2100.00 0 52 2200.00 0 5~ 2300.00 I 6 2400.00 1 4 2~00.00 0 6 2600.00 2 10 Z700.O0 3 41 2900.90 6 39 S 93 46 F 585 0 E S 84 53 E S 95 25 E S ~36 1'~ E S 88 29 E S 0 38 E N ~ 56 W N q2 55 W S 89 59 W 2900.00 10 3000.00 14 57 3100.00 17 19 3200.90 18 40 3300.00 19 19 3400.~0 21 11 3500.00 24 54 3600.00 Z7 5l 3100.00 33 3800.00 36 S 82 lg w S 82 11 W S q5 1~ W S 87 4 w S 99 21 W N '~9 44 W N ~9 N ~9 10 W N ~38 4~ W N 87 17 W T 0~ LEG ERITY /100 0.00 0.14 1.12 0.55 0.24 0.45 0.33 0.50 0.42 0.62 0.20 0.1'5 0.00 0.00 0.11 0.34 0.20 0,49 0.02 0.21 O.1Z 0.08 0.08 0.11 0.63 O.OO 1.01 1.55 1.90 3.32 4.25 3.56 1.38 1.19 0.96 3.05 2.90 3.67 4.60 2.70 ,, KELLY SU~-SFA DE~TH R ~_C T ~ ""IGUL,a R NORTH/SOUTH FEET 0.00 N 0.01 ,3 0.47 S 0.97 S 1.35 S 1.96 S 2.2~ S Z.63 S 2.86 S 3.15 S 3.51 S 3.3;3 S 3.59 S 3.70 S 3.89 S 4.25 S 4.72 S 4.9~ S 4.94 S 4.82 S 4,.94 S 5.08 S 5.23 S 5.35 S 5.51 S 5.55 S 5.6~ S 5.59 S 4.93 S 4.3~ $ 5.61 S 8.81 S 11.96 S 14.12 S 15.21 .S 15,21 S 15.10 S 14,39 $ 13.47 5 10.78 S D~TE qF SURVEY: ~USHYNG ELEV&TION: ENGINEER: CgORDIN~TES HURIZ. E~ST/WEST DIST. F E "T FEET 0.00 E 0.00 0.05 E 0.05 0.57 E 0.74 1.07 = 1.45 1.48 E 2.01 1..99 E Z .80 2.28 F 3.20 2,71 E 3.81 2.9~ E 4.13 3.40 E 4.64 3.57 E 4.87 3.73 E 5.03 3.91 E 5.31 4.20 E 5.60 4.48 E 5.94 %.79 ~ 6.40 5.44 E 7.20 6.49 E 8.18 8.00 E 9.40 9.43 E 10.59 10.'7~ E 11.86 12.18 E 13.20 13.67 E 14.63 15,21 ~ 16.13 16.87 ~ 17.75 18.85 ~ 19.65 19.89 [ 20.69 18.05 ~ 18.90 12.98 E 13.89 4.12 ~: 6.01 10.87 W 12.23 33 '=5 W 34 69 . .~ o 95.03 w 96.03 129.44 W I 30.33 !!~.05 W 156.74 208.52 W 209.06 2~7.9~ W 258.35 31~.89 W 317.17 3~6.55 i,I 3q6.7} / 28-JAN-89 55.00 FT SCHWARTZ DEPARTURE ~ZIMUTH DEG MIN N 0 0 E S 76 29 F S 50 29 E S 47 53 E S 47 43 E S 45 24 E 5 45 Z? E S 45 20 E S 46 12 E S 47 12 E 547 8 E S 47 52 E S 47 29 E S 43 41. E 549 I E S 49 24 ~ S 49 0 E S 52 30 E S 58 17 E S 62 55 E S 65 22 E S 67 Z2 E 569 4 E S 79 36 E S 71 54 E S 73 35 E 574 3 E S 72 47 E S 6~ ll E S 4~ 17 E S 6Z 41 W S 75 16 W S 7q lO W S 81 32 W S 83 17 W S 8~+ 46 W S 85 51 W S $5 48 W S 87 33 W S 83 24 W ARCO ALASKA '[NC. LISBURNE L5-17 PRUOHOE BAY/L[SBUffNE POOL NORTH SLOPt, ALASKA COMPUTATION DAT~: 13-FE,~-89 PAGE 6 DATE OF SURVEY: 28-JAN-89 KELLY BUSHING ELEVAT[ON: 55.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVE>~ 100 FEET OF SU~-SEA DEPTH TRUE St,lB-SE ~ COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG M[N '' ~!~ · i' 4067.15 3955.00 3-~00. O0 4204.0! 4055.00 4000.0 4340°67 4155.00 .4100.00 4~76.65 ~255.00 4200.00 ; 42 25 ~611.69 4355.03 4300.00 : '42 7 4747.78 4455.00 4400.90 43 15 4~86.14 4555.00 4500.00 44 0 50Z5.98 ~655.00 4600.00 44 ~9 5166.06 4755.00 4700.00 44 31 5~06.04 4855.00 4800.00 44 10 VERTICAL ODGLEG RECTANGULAR CQORDIN~TES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. ~ZIMUTH FEET DEG/IO9 F~EI' FEET FEET DEG MIN N 89 20 W 464.98 N 99 Z W 557.~0 N 38 ~R W N 88 23 W 742.44 N B8 ~ ~ 833.10 N 87 55 W 925.32 N 97 17 W 1020.91 N ~6 47 W 111~.62 N 84 45 W 121~.71 N ~4 1'~ W 1314.63 3.85 0.50 0.26 0.72 0.64 0.96 0.62 ! · 01 0.92 0.48 8.54 S 465.8'7 W 466.95 S 88 57 W 7.48 S 559.46 W 559.51 S 89 14 W .~.52 S 652.5:9 W 652.60 S 89 30 W 3.41 $ 744.70 W 744.71 S 89 44 W 0.59 ~ ~35..40 W 855.40 S Bg 57 W 2.44 N 927.A5 W 927.65 N 89 50 W \ 6.63 N 1023.18 W 1023.21 N 89 37 W 11.45 N 1120.80 W 1120.86 N 89 24 W 18.75 N 1218.62 W 121~.77 N 8g 7 W 29.20 N 13!6.11 W 1316.42 N 88 4~6 W 5444.14 4955.00 4~00.00 43 38 5582.85 5055.00 5000.00 43 29 5719.41 5155.00 5100.00 42 11 5853.50 5255.00 5ZOO.D0 41 16 5986.45 5355.00 5300.00 41 14 6119.37 '5455.00 5400.90 ~1 5 6252.13 5555.00 5500.00 41 2 6~84.62 5655.00 5600.00 40 5~ 6516.14 5755.00 5700.00 40 27 6648. ~,5 5855.00 5800.00 41 19 N 83 21 W 1410.69 N 83 35 W 1505.87 N '84 11 W 1593.B1 N 84 6 W 1688.10 N 84 11 W 1775.67 N ~3 37 W 1~63.20 N ~3 48 W 1950.47 N 83 45 W 203V.31 N ~3 36 W 2122.69 N ~3 12 W 2209.24 0 .44 0.67 0.18 0.26 0 .35 0.69 0.35 0.75 1.16 1 .11 38.60 N 1411.67 W 1412.20 N 88 26 W 49.55 N 1506.30 W 1507.12 N 8~ 6 W 59.45 N 159~.76 W 1599.87 N 87 52 W 61~.45 ~'I 1.687.63 W 168q.02 N 87 40 W 77.3f N 1774.78 W 1776.47 N 87 39 W ,~6.60 N 1861.87 W 1853.88 N 87 20 W 96.1! N 19~,8.67 W 1951.04 N 87 10 W 105.58 N 2035.05 W 2037.79 N 87 1 W 1'14.78 N 2119.98 W 2123.09 N 86 54 W 125.04 N 2206.01 W !209.55 N 86 45 W 6782.02 5955.00 5900.00 41 41 6916.26 6055.00 6000.00 42 7051.~5 6155.00 6100.00 42 25 7187.23 6255.00 6200.00 42 35 7323.49 63'55.00 6'300.90 43 7 7460. IZ 6455.00 6400.00 43 4 1597.33 6555.00 6500.00 ~2 56 7733.98 6655. O0 6600.00 43 0 7869.93 5755.00 6700.00 ~,2 8004.19 6855.00 6800.00 41 hi 94 26 W 2291.74 ri q4 5q W 2387.28 N 85 56 W 2478.25 N ~6 47 W 2570.08 N BT 26 W 2567_.62 N 87 47 W 2756.55 N 37 20 W 2~49.58 N ~7 14 W 2942.68 N ~7 5R W 303~.72 N 88 15 W ~124.23 0.94 0.55 0.91 0.23 1.02 0.56 0.06 0.36 0.51 0.20 134.47 N 2294.06 W 2297.99 N 85 38 W 142.63 N 2383.2~ W 2387.51 N 86 34 W 150.07 N 2473.91 W 2478.46 N 86 31 W 155.66 N 2565.58 W 2570.30 N 85 31 W 160.31 N 2658.02 W 26.62.85 N 86 32 W 164.03 N 2751.93 W 27~6.81 N 85 35 W 168.05 N 2844.92 W 2849.8~ hi 86 37 W 172.44 N 2937.95 W 2943.09 N 86 38 W 176.24 N 3029.96 W 3035.08 N 86 40 W 179.11 N 3119.50 W 3124.63 N 86 42 W ~137.0~ 6955.00 6900.00 40 58 8269.88 7055.00 7000.00 41 21 8~03.U9 ~155.09 7100.00 42 5 8539.51 7255.00 7200.00 42 49 ~676.87 7355.00 7300.00 4~ 45 8815.91 7455.00 7~00.00 44 16 8956.55 7555.00 7500.00 44 55 9098.04 7655.09 7600.00 45 6 9238.51 7755.00 7700.00 43 44 9575.01 7855.00 7300.00 42 31 N 87 1~ W 3211.64 N 87 43 W 3299.03 N 87 57 W 3388.20 N 97 59 W 3477.74 N ~'? 59 W 3573.93 N 9-? 59 W ~670.36 N 37 57 W 3769.18 N 87 53 W 3869.21 0.11 0.48 0.50 0.38 0.62 0.66 0.27 0.69 N ~8 29 W 3967.77 . 1.46 N .~9 25 W 4060.53 O.ZB 182.5-) N 3206.89 W 3212.0B N 86 44 W 186.25 N 3294.24 W ~299.51 N 85 45 W 189.59 N 33:33.41 W 3388.71 N 86 47 W 192.~1 N 3474.96 W 3480.30 N 86 49 W 196.14 N 3569.06 W 3574.45 N 86 51 W 199.52 N 3665.60 W 3671.03 N 86 53 W 202.98 N 37~_4.44 W 3769.91 N 85 54 W 206.68 N 3864.4-3 W ~869.98 N 8.5 56 W 209.93 N 3963.05 W 3968.61 N 86 58 W 211.44 N 4055.95 W 4061.45 N 87 0 W ARCO ALASKA INC. LISBURNE L5-17 PRUDHDE B~Y/LIS~URNE POOL NORTH SLgPE~ ALASKA COMPUTATION DATE: 13-FEB-B9 'PAGE DATE OF SURVEY: 28-JAN-89 KELLY BUSHING ELEVATION: 55.00 FT ENGINEER: SCHWARTZ INTERPOLA'TEO VALUES FOR EVEN 100 :EET DF SUB-SEA SEPTH TRUE SUB-SE~ COURSE VERTICAL DOGL~ZG RECTANGUL6~ COORDINATES HgRIZ. DEPARTURE MhASURED V~RTICAL VERTICAL DEVIATION AZI~UTH SECTION SEVERITY NORTH/SOUTH EAS~/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH BEG MIN DIG M~N FEET · 9510.4~ ?~55.00 7900.00 ~:!13 N q9 57 W 4151.62 9644.~2 8055.00 8000.00 ~:;:~8 S 99 ~ W ~241.15 9778.00 8155,00 8100.00 ~0 54 ~910.08 82~5.00 8200,00 ~0 44 10042.11 8355.00 8300.00 40 43 10173.83 8455.00 8400.00 40 31 10305.69 8555.00 8500.00 40 54 1U~37.99 8655.00 8600.00 ~0 34 !0567..~9 8755-09 8700.00 38 9 10693.79 8855.00 8~00.00 37 6 S 88 55 W 4323.77 S 8B 35 W 4414.67 S 8~ 22 w 4509.45 $ 88 9 W 4585.72 S 88 15 W 4671.19 S 87 55 W 4757._B1 S 87 53 W 4~39.11 S 89 1 1 W 4915.86 10818.17 8955.00 8900.00 35 47 10940.32 9055.00 9000.90 34 18 11141.00 92Z3.82 9168.~2 32 41 S 89 54 W 4989.56 S 99 52 W 5059.52 N 89 39 W 5169.56 DEG/IO0 FEET FE%T FEET DIG MIN 0.44 0.59 0.09 0.19 Z .OB 1.09 1.08 0.51 1.26 1.92 1.59 0.00 211.93 N ~147.25 W 4152.67 N 87 4 W 211.74 N 4137.04 W 4242_.32 N 87 8 W 210.57 H 4~Z4,9~ W 4B30.11 N 8l 12 W 20~.69 N 4411.25 W ~4!6.18 N 87 17 W 206.44 N ~4,~7.43 W 4502.16 N 87 12 W 203.86 N 45~3.12 W 4587.66 N 87 27 W 201.06 N 4569.02 W 4673.35 N 8T 32 W % 198.21 M ~755.60 W 4759.72 N 87 36 W 195.40 N %837.BZ W 4~41.76 N 87 41 W 193.40 N %914.93 W 4918.73 N 87 ~4 W 1~2.'72 N 49,38.87 W 4992.59 N 87 47 W 192.72 N 5059.03 W 5062.70 N 87 49 W 1'93.11 N 5169.3~+ W 5172.94 N 87 51 W ARCO ALASKA INC. LIS6URNE L5-17 PRUOHOE BAY/LISBLIRNE POOL NORTH SLOPE, ALASKA MA~K~R TOP WAHOO ZONE 8 TOP WAHOO ZONE 5 TOP WAHOO LONE LAST GCT READING P~TD TOP WAHOO ZUNE 3 ID COMPUTATION DATE: D~TE OF SURVEY: 28-J~N-89 KELLY ~USH!NG ELEVATION: 55.00 FT ENGINEER: SCHWARTZ INTERPOLATEO VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 182)' ESL ~ 155' ~EL, SECZ, TllN, R15E,UM MEAsuREO 9EPTH BELOW ~ B ,10603.00 107~9.00 10877.00 1'1051.80 11094.00 11105.00 11142.00 P. ECTANGULAR COORDINATES FRUM KB SU~3-SEA NO~TH/SOUTrl E~ST/WEST 8782.95 8727.95 19~+.63 N 4859.?0 W 8907.21 8852.21 192.90 N 4954.00 W 9002.92 8947.92 192.71 N 5023.01 W 9147.91 90'~2.91 192.82 N 5120.62 W 9'!83.&3 9128.~'3 192.96 N 5143.41 W 9197.6.B 91'~7.6~ 192.99 N 5149.35 W 9223.82 9168.82 193.11 N 5169.34 W TV9 ARCO ALASKA INC. LISBURNE L5-17 PRUDHDE 8~Y/LISBURN6 NORTH SLOPE9 ALASKA POOL COMPUT~.TION D~TS: l~-FEB-89 KELLY TOP WAHOO ZONE TOP WAHOO ZONE TOP WAHOO ZON~ LAST GCT RE~DZNG PBTO TOP WAHOO ZI]NE SURF&CE MEASURED ~EPTH BELOW K~ 10603.00 10759.00 ~ 10877, O0 11051.80 11094.00 11105.00 11142.00 SUMMARY D&TE ~ U S H I N G OF SURVEY: ELEVATION: ENGINEER: FINAL MEASURED DEPTH WELL LOC&TION ~T TO: TP '- .U= SU~-SE~ VERTICAL VEP.,T[CAL DSPTH DEPTH 111~2.00 9Z23.82 9168.82 LOC~TION : 1323' FSL E 155' =EL, SEC2, TllN~ R TVO FROM KB SUB-SE 8782.95 8'127 . 95 8907.21 8852.21 9002. g2 8947 . q 2 9147.91 g012.91 91B3.~3 9128.43 9].92.68 9137.68 HORIZONTAL DEP~R'TURE 'ST ~NC E ~ Z IMUTH ~:E ET OEG MIN N 87 51 W 5172.94 ZB-J~N-89 55.00 ~T SCHWARTZ RSCT~NGUL~R COOROIN NOPTH/SOUTH EAST! !9~.63 N 4859. 192.90 N 4954. !92.T1 N 5023. 192.~2 N 5120. 192.~6 N 5143. 192.99 N 5149. 193.11 N 5169. 15E,UM ~TES WEST 70 W O0 W O1 W 62 W ~+1 W 35 W SCHLUMBERGER D I RECT I ONi::::tL SURVEY COMPANY ARCO ALASKA INC. WELL F I ELD L I SBURNE LS- l ? PRUDHOE 8AY/LI SBURNE COUNTRY USA RUN ONE BATE LOOOEO 28 - JAN - 89 REFERENCE: ?B; 34 POOL WELL' L:ISBUR'NE L5-~'-'' HORIZONTAL PROJECTION (1823' FSL, 155' FEL, SEC 2, TllN, R15E, UM) NORTH 4000 ~000 2000 1000 -1000 S~UTH -4000 - _L:U'J~__ HE$1' REF 79134 SCI::IL£ = 1/1000 IN/FT : ,~,. ~ ~ , ~: ~ .... ~ t"t'"?' '"?"*'"?t'"['?'? ......... ~"'~"'~"T"'t'"? ....... ~'-'--r' '~"'~"~'"~r'"r-t .............. ~ .............. t ....... +"~ ........ "~"'*"~' '* * ~ ~" ~ *-* ~ '"*"~" *~' ' .... 1 ........ ~'T"??"~'T'~"?"-','"~'"~"?" '~'"~'"'"~-"~'-~-~-~ ...... ~-~'--~-'-~'--~ "'~'-~'--~'-~---~"?-'~ ....... ?-" ..... ?'~'--,-"~ ....... ~--'~'-.~..'~ .......... ~ ....... ~ ................ ~ ~ ~ ~ , ~ : ~ , ~ : ~ : ~ ; "-Y'T"T-~ ..... 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PROJECTION ON VERTICRL PU:eqE 27. - 207. ~I::I~.ED IN VERTIC;IL OEPTI.16 HORIZ $CPlLE = 1/500 IN/FT Item 24' Well Completion or Recompletion L5-17 (cont' d) Perforation Depths MD 10540 10545 10550 10555 10559 10563 10567 10582 10584 10608 10610 10625 10634 10642 10651 10655 10660 10669 10675 10689 10692 10733 10736 10743 10744 10777 10779 10783 10790 10805 10807 10814 10826 10831 10836 10843 10846 10852 10856 10859 10865 10883 10886 10902 10906 10912 10917 Report TVD 8734 8738 8742 8745 8749 8752 8755 8767 8768 8787 8789 8801 8808 8814 8821 8824 8828 8836 8840 8851 8854 8886 8889 8894 8894 8922 8923 8926 8932 8944 8946 8951 8961 8965 8970 8975 8978 8983 8986 8988 8993 9008 9011 9024 9027 9032 9036 & Log 015/WC6 ARCO ALASKA INC ' LISBURNE ENGIN EERFNG DATE: 3-13-8.. ~::~"~ FROM: JOHN BARBO / E.o,o E . ,HE OH FINALS FOR L5-17 ~ CNL (RAW) ~ CNL (PORO) ~ CYBERLOOK DLL RUN 1 NGT RUN I RUN I 1/24/89 SOS* RUN1 1/24/89 SOS. RUN I 1/24/89 SOSe (2" & 5") 1/24/89 SOS. (2" & 5") 1/24/89 SOS. CH FINALS FOR L5-17 '~CNL RUN I (2"& 5") 1/24/89 SOS. CET RUNI 1/28/89 SOS, GCT RUN I 1/28/89 SOS ~%~CNL RUN I 1/28/89 SOS~ ~_~~BT RUN I 1/28/89 SOS ~ -----Rt. RUN I 1/28/89 SOS (With PRECNL and PRECNT corrections)· JOHN BARBO ARCO ALASKA, INC. 700 G STREET; ATO 415 ANCHORAGE, ALASKA SIGN AND RETURN TO: 9951O RECEIVED BY: EXXON STANDARD PLANO D&M CENTRAL FILES TRANSMITTAL # 612 (PAGE I OF 3) ARCO ALASKA INC. LISBURNE ENGINEERING DATE: 3-13-89 FROM: JOHN BARBO ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: ~i~BHP FOR L5-17 2/19/89 CAMCO OH FINALS FOR L5-17 fllI~PHYSICAL FORM. LOG RUN I 1/23/89 SOS ~ MWD GAMMA RAY RUN I 1/18/89 SOS ., CH FINALS FOR L5-17 ~~- .' CASING COLLAR LOG RUN I 2/15/89 DA FINALS FOR L5-25 TBHP 2-23-89 CAMCO L. EMP LOG RUN I 2/23/89 ~,,,.~GCT (tape only) RUN I 1/8/89 SOS SIGN AND RETURN TO: CAMCO (CASED HOLE) (CASED HOLE) JOHN BARBO ARCO ALASKA, INC. 700 G STREET; ATO 415 ANCHORAGE, ALASKA 99510 RECEIVED BY: EXXON STANDARD PLANO D&M CENTRAL FILES TRANSMITTAL # 612 (PAGE 2 OF 3) .!USpec,tor ST~T£ 0£ ALASF~A l~tA$~ OIL & ~A$ CO~5££VATION CO~II$SION B.O.P.E. l~spectien Report ~ 7':-. --- _. Resecve P!.~__ .,'~..._ _.~____.___.~. Hu~ System ,_. ~z~p'Tank ....... '/',. Flow Monitor ~ ..'/ ..... Blind Rems_ .......... Choke Line ~.C.R. Valve.... Kill Line Check Valve Pressure After Closure. /~0 psis. .__ Fump incr, clos, pres, 200 psi~ :_.__min sec. £ull Charge Pressure lttstned:___L__mtq~'se~- . Lo.er Kelly__ / Test Inside BOL~/ Test Pressure~, .,.. Choke Hsni[eld ...... ~est Fressure,,~~P~,, ___ ~ , Adjustable Chokes. , ........... .._: Hvdrauicall~ C_pe~ated choke / Tes~ Results: Failures ............ Test Ti~e rs, =-.=. ......... Repair or Replacement of fat. led equipment to be made vithin days and Inspector/ Co~tsmion office nottiied, .... .... cc - Opera~o~ cc - Supervisor November 9, 1988 Telecopy: (907)276-7542 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, inc, P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit L5-17 ARCO AlaSka' Inc. Permit No. 88-139 Sur. Loc, 1823'FSL, 155'FEL, Sec. 2, TllN, R15E, b%L Btmhole Loc. 2201'FSL, 8'FWL, Sec. ~,~ TllN, R15E, UM. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. me pe~it to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to comencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to ¢o~ncing installation of the blowout prevention equipment so that a representative of the Co~ission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a dtverter system is required, please also notify this office 24'hours prior to commencing .equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~ tru~~urs, v, '" " Chairman of Alaska Oil and Gas Conservation Co~ission BY ORDER OF ~E COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ;"'-. STATE OF ALASKA r~-, ALASK,. OIL AND GAS CONSERVATION ,.. JMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [~ Redrill [~1 lb. Type of well. Exploratory [] Stratigraphic Test El Development Oil F~ Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 35' Pad 20' feet Prudhoe Bay Field 3. Address 6. Property Designation Lisburne 0il Pool P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28320 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.O25) 1823'FSL, 155'FEL,Sec.2,TllN,R15E,UM Prudhoe Bay Unit/Lisburn( Statewide At top of productive interval 8. Well nu ,tuber Number 2170'FSL, 420' FWL,Sec. 2,T11N,R15E,UM L5-17 #8088-26-27 At total depth 9. Approximate spud date Amount 2201 'FSL, 8' FWL,Sec. 2,T11 N, R15E,UM 11/10/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line L5-1 5 9205 ' TVD 3457 ' ~ surface feet 60 ' @ surface feet 2560 1 1 06:~ 'MD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth2500' feet Maximum hole angle 41 o Maximum surface 3372 psigAttotatdepth(TVD) 4490 psig 18. Casing program ...... Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-4£ Weld 80' 35' 35' 115 115' 2000 # Poleset 13-1/2" 10-3/4' 45.5# J-55 BTC 4234' 34' 34' 4268 4100' 325 sx Class G & 1250 sx AS Ill '~-il'8~' /-~/U" Z~./¢ L-St; 151C 0364~' 33' 33' 10397 8705' 300 sx Class G 6-3/4" 5-1/2" 17.0# L-80 FL4S 863' 10200' 8556' 11063 9205' 200 sx Class G 19. TO be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface RECEIVED Intermediate Production NOV (,i ;7 ]988 Liner Perforation depth: measured Alaska 0il & Gas Cons. Commission ',~ ~.nchorage~ true vertical 20.;Attachments Filing fee [] Property plat [] BOP Sketch Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20AAC 25.050 requirements 21. I herebY certify that the foregoing is true and correct to the best of my knowledge~ si'gned Title Regional Drilling Engineer Date// ,~/ Commission Use Only (TEK) PD3/033 Permit Number - I APInumber IApprovaldate JSeecoverletter 'oE~-/~ ~ I 50-- © 2-~-'~- / ¢'¢'~ 11/09/88 for other requirements Conditions of approval Samples required ~ Yes [] No Mud Icg required L-] Yes ~ No Hydrogen sulfide measures ,~'Yes [] No Directional survey required ~ Yes ~ No Required workin, g,,l~ssurC)for BOP~F_, Fq2M; [] 3M; ~ 5M; [] 10M; E~ 15M Other: ./' ./ '/ / / ~ ~ J ' by order of Approved Commissioner the commission Date Form 10-401 ~.-:f~-1-'8"5 , Submit~-n triplicate LISBURNE L5-17 PRELIMINARY WELL PLAN DRILLING PROCEDURE 1) MIRU Pool 5. 2) Drill 13-1/2" hole to 2500'MD. Kick off and build angle at 2.5°/100'MD to 41°17'/N85°47'W. Maintain hole angle and direction to 10-3/4" casing point at 4268'MD/4100'TVD. 3) Run and cement 10-3/4" casing to surface. 4) Drill 9-7/8" hole to 7-5/8" casing point of 8705'TVD/10397'MD. 5) Run and cement 7-5/8" casing. 6) Drill out 7-5/8" casing and 6-3/4" hole to TD, 9205'TVD/11063'MD. 7) Run open hole logs. 8) Run and cement 5-1/2" liner. 9) Clean out liner and change over to brine w/diesel cap. 10) Install dummy hanger and master valve. Release drilling rig. 11) Run cased hole logs. 12) MIRU completion rig. 13) Run 2-7/8" single completion string. 14) Release completion rig. 15) Perforate and stimulate. RECEIVED NOV U 7 1988 Alaska Oil & Gas Cons. Commission Anchorage NOTE: a) In accordance with Area Injection Order No. 4, excess non-hazardous fluids developed from well operations and as necessary to control the fluid level of the reserve pit, will be disposed of down the 7-5/8" x 10-3/4" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed w/250 sx of cement followed by Arctic pack upon the completion of the fluid disposal process. b) The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. PD3/033.2 LISBURNE L5-17 PRELIMINARY WELL PLAN DRILLING PROCEDURE c) Maximum surface pressure is based upon BHP of 4490 psi at 9205'TVD, less an oil column to 8500'TVD, less a gas column to surface. d) Wells within 200' of the L5-17 are: L5-15 60' from L5-17 at surface. L5-13 120' from L5-17 at surface. L5-21 119' from L5-17 at surface. PD3/033.3 L5-17 ?'"'-~ 5000 6000 0 )000 .._ 2000 3(100 4000 5000 6000 7000 0 ' ' ~ I I I ~ I I ZO'CONDUCTII 1 I ~ , I I ~ ~ 0 ooo ARC13 ALA,SKA, INC. 2000 :,~CALI= I IN. = 1880 FT. 2000 SHL: 1823' FSL, 155' FE., ~(OP TVD = 25~)0 SEC: 2, ~11N, f115E, Ul ~.5 7.5 THL: 2170' FSL, 420' FV~L, ~000 1~.5 17.5 2~ .5 37.5 ~1.3 EOC T'/D=401~ ~D=4!52 DEP= ~000 ~ 10-3/~' SURFACE T fD = 4100 MD~268 DEP -- 647 ~ N 85 DI[G 47 MIN W 4718 Fl(TO TARGET) AVERA8 E ANBLE 41 DE~ ? MIN . 7000 7000 K=IO TVD = 7816 MD = 8947 DEP = 3734 K-5 TVD = 7895 MD = 9~ 19 DEP = 398~ 8000 j ~~ 8000 SADLEROCI IT TVD = 857~ MD = 10224 [,EP = 4677 L{ :U TVD = 8575 MD = 10224 C EP = 4577 K~ VIK TVD = 88~ 5 MD = 10281 DEP = 4621 7=5/8' CAS NG TVD = 870 5 MD = 10397 DEP = 4891 9000 ~=~=~ ~'~- =~'~ ~B ~ 1~4~ ~=~ .................... ~. ~- 9000 TD/5-1/Z'CASING TV[ --S20S MD=11063 DEP=,.133 [ 000 ............................................................... ~ [ 000 0 ] 000 ~000 3000 ~000 5000 6000 7000 VFRTTNRI AFNTTnKI F-~ O_ W 5000 C~ W 6000 > W o -8000 0 0 0 (%1 w z 6:) 65) E - N OOOROINR'I'ES -7000 -6000 -5000 -4:000 -3000 -2000 - 1000 0 1000 I i i . / 1.~ 7 I 1000 -8000 -7000 -6000 -5000 0 -4000 -3000 -2000 - 1000 E - N OOORDINPITES o Z LS-g I o 0 I 0 0 I 0 o E - N COOROINRTES -400 -300 -200 - l O0 0 1 O0 200 300 i i I i i I I i i I I i I I I i I I i I I i i I I I I I I I I I I' I I I i i i i i i i I I i i i i i I i ! i ! I i i i i t ' ~~.x2 6 ~787 il- 17 I . i i i i i i i i i i i i t i i i i i i i i I i i i i i i i i i i ! ! i i ! t i i i i i ! i i i i ! i i i i i ! i I i i i i i i -400 - -300 -200 - 1 O0 0 1 O0 200 300 E - kl COOROINRTES £ - N COOROINB?£S -8000 -7000 -8000 -5000 -4000 -3000 -2000 -1000 0 1000 ~ I I i i i i i ~ i ~ I I I i I I I I I I I I I i i i I i i i i , i i i i i , I i i i i i i i i i I I , i i i i i i i i i i i i i s i i i i [ i t i i i i i i i o LS 21 - 30s ~ ~350 ~ 40 ~21 LS- 3 ~7~ , - ' = 275r ~'8~ I00 ,, , , , , , , ] ~ , , , , , , , , , , i , , , , , , , , , , , , , , , , , , , , , , , , , , , ~ , , i , , , , , , ~ , , i , , , ~ , , , , , , , , , , , , , , , , , -8000 -7000 -8000 -5000 -~000 -3000 -2000 -1000 0 1000 - N OOOROINST~S L5-17 MUD PROGRAM Plas Density Visc. Depth (TVD) #/gal (CP) Yield Point Initial 1OM #/1 O0 ft2 Gel Gel FL CC/30M Surf 8.8 Funnel to to 160- 10-3/4" 9.2 300 Csg Poi nt % % pH and Oil Solids Type of Mud 40-60 30+ 50+ 25 0 8 Operate all solids removal equipment to maintain PV as low as possible. cement contamination. 10-3/4" ---SET 10-3/4" CASING ..................... Csg Shoe 8.8 Minimum 2 2 5 15 to to Possible to to to to K-10 9.2 4 5 10 25 Gel -Benex Spud Mud Pretreat with Bicarb or soda ash for 3.5 Low Sol ids to Non-di spersed 6.5 Operate all solids removal equipment to maintain weight as low as possible. K-lO 9.2 12 6 2 5 4 2 4 to to to to to to to to to 7-5/8"Csg. Pt. 10.4 20 10 4 8 6 5 8 Low Solids Non-dispersed Low Lime .25 to .50 ppb excess lime To control potential shale problems in K-lO to K-2 interval, increase mud weight only as required. DO NOT weight up prematurely. Use low viscous pill sweeps to clean hole as needed. Expect some possible gas cutting below the top of the K-lO shale. Use degasser as necessary. Mud weights should be kept as low as possible to minimize differential sticking problems in the Sadlerochit Sand. Should torque or drag become excessive, treat with medium nut hulls and screen out at shaker. If torque or drag continues, treat system with crude oil as required. Maintain fine screens on shakers to allow use of 75% of screen area. ...... SET 7-5/8" CASING ................................ 7-5/8" pH 10-12 water base Csg. Shoe 9.3 12 10 2 5 8 0 8 mud with 30,000 ppm Cl. to to to to to to to to to 5-1/2" Csg Pt 9.5 20 20 4 8 15 5 12 ..... SET $-1/2" LINER ......... On daily service company mud report, log hours that desilter, desander, and degasser are run; and the number of cones in operation and size of shaker screens being used. Report volumes injected or dumped to reserve and water used. 2 This mud plan is a guideline only. These exact mud properties, including mud weight, need not be maintained if rig supervisory personnel feel hole conditions warrant otherwise. Any radical changes should be discussed with Anchorage before implementation. 3Verify correct mud properties after circulating bottoms up prior to cementing 7-5/8" casing. 4Verify correct mud properties prior to cementing liner after circulating bottoms up. 10/14/88 PD3/OO9a,4 MUD SYSTEM POOL 5 I SAND TRAP 12 BBLS PIT I PIT 2 DEGASSER PIT DESANDER PIT 105 BBLS 99 BBLS I I i PIT 3 PIT 4 MUD CLEANER PIT PILL PIT 100 BBLS 108 BBLS PIT 5 PIT 6 VOLUME PIT SUCTION PIT 391 BBLS 280 BBLS I C, ommiss~O~'~ BRANDT TRIPLE SHALE SHAKERS SWACO DEGASSER, 1000 GPM PIONEER DESANDER (2 EACH, 1000 GPM) PIONEER DESILTER/MUD CLEANER (2 EACH, 800 GPM) PIONEER CENTRIFUGE (2 EACH, 100 GPM) JG 6/14/88 13-5/8" 0000 PS1 BOP STAC,. DIAGRAM ACCUMULATOR, CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. :5. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REPIAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REIMAINING PRESSURE. PIPE RAm BLIND RAMS DRILLING SPOOL PIPE RAMS DRLG SPOOL CSG SPOOL 13-3/8" STARTING HEAD ALL BOP EQUIPMENT 5000 PSI RATED . 5. . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 13-5/8" BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING ,JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. FUNCTIONALLY TEST CHOKES. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A ZSO PSI LOW PRESSURE TEST FOR A MINIMUM OF $ MINUTES, THEN TEST AT THE HIGH PRESSURE. INCREASE PRESSURE TO :5000 PSI AND HOLD FOR A MINIMUM OF ::5 MINUTES. BLEED PRESSURE TO ZERO. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST :5 MINUTES. BLEED PRESSURE TO ZERO. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3 MINUTES. BLEED PRESSURE TO ZERO. OPEN TOP SET OF PI PE RAMS THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST :5 MINUTES. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST :5 MI NUTES. BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLIND RAMS. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. CHECK OPERATION OF DEGASSER. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORI"I. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. JG 8- Z6- 85 POOL 5 DIVERTER SYSTEM SCHEMATIC -ARCO ALASKA, INC. FILL-UP LINE RISER FLOWLINE 20" 2000 PSI DIVERTER ,I CONDUCTOR 10" BALL VALVE RESERVE PIT 10" VENT LINE 2 EACH 10" FABRI-VALVE 37 WITH MANUAL OPERATORS EQUIPPED WITH LINKAGES WHICH OPEN ONE VALVE AS THE OTHER IS CLOSED WELL DIVERTER LINES DISCHARGE 100' FROM RIG IGNITION SOURCE. JG $/14/88 ARCO Alaska, In, Post Cffice sox ~00350 Anchorage. Alaska 99510-0350 Teiept~one 907 276 !21.5 October 6, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT' Conductor As-Built Location Plat- L5 Pad (Wells 17, 25, 32, 33, 36) Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG'hf Enclosure If you have GRU13/1.2 ARCO AJas~<a, Inc. is a ..q-~Jbsidiar¥ of ~,,*~antJcRicht e~C.~m~a,q¥ Sec. 2 PROTRACTED SECTION LINE Sec. I o35 031 e29 027 e23 .21 019 ol3 0 LEGENDi o~ .9 0 · EXISTING WELLS 07 o PLAN WELLS o5 0 '~ ASBUILT WELLS 0 I 0 I HEREBY CERTIFY THAT PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, AND THAT THIS PLAT REPRESENTS AN ASSUILT SURVEY VICINITY MA= NO SCALE LOCATED WITHIN PROTRACTED SEC s. I E, 2 , T. I I N., R. 15 E., U. M. LS' 17 Y=5 974 950.40 LAT.= 70°20'03.099" X= ?!7271 36 LONG.= I48°14'13.914" 1823' F.S.L. 155' F.E.L. El_= 213.1 L§'25 ¥=§ 975 190.51 LAT.= 70°20'05.459'' X= 717271 .61 LONG.= 148°14'13.70:~ " 2063' F.S.L. 148' F.E.L. EL= 19.8 ;.. L§-32 ¥=5 975 400.34 LAT. = 70o20'07.473 X= 717 446.51 LONG.= 148°14'08.420'' 2268 F.S.L. 33' F.W.L. EL= 19.8 L5 -33 Y= 5 975 430.37 X= 717 271 2303' ES.L. L5.36 LAT. = 70°20'07.818" LONG. = ! 48° 14 ' 1,3 . 507" 141' EE.L. EL= 19.7 Y=5 975 520.21 LAT. = 70°20'08.651" X: 717 446.61 LONG.: 148Ol4 '08.516" 2387 'F. S.L. $7' F.W.L, EL = 19.9 MADE BY ME. OR UNOER MY ~,. ~ 3. B~IS ~PE~ISlON, AND T~T A~ DIME~'IONS ANO OTHER ~TAI~ - ~.,,:,_.. . ~.... ......... ~ '~ · , ~ o NOTES I. BASIS OF LOCATION IS LSNORTH & L§SOUTH DRILL SITE MONUMENTS. 2. ALL COORDINATES SHOWN ARE A.S.P. ZONE 4. OF ELEVATION. IS ARCO OATUM (MLLW) ARCO Alaska, Inc. DRILL SITE LS-17 CONDUCTORS 17~25,32,33 & 36 ASBUILT LO CATIONS tDr. by 88 Ick by ~ Ism 2o~o,, t Dwq. No. NSDP-OOOo-cEA- 4100- 009 '(9 rh~ 13) I0. (10 ~d 13) 12. 13, (/4 =h~ 22) 5) BOPE (23 thru 28) (29 rhr~ 31) eology: Endearing: c£Fc rcs c%T v: 08/11/88 011 - YES NO Is the permit fee attached .......................................... ~ .... .. 2. Is well to be loca=ed im a defined pool ............................. ~ , 3. Is well located proper distance from proper%7 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 amd is wellbore at included ................ ,, 7. Is operator the.only affected party .................... '-. ........... 8. Cam permit be approved before fifteen-day.wait ...................... ~_ Does operator have a bond in force .................................. ~_ Is a conservation order needed ...................................... ,, Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ........................ : ~ . 14. 15. 16. 17. 18. 19. 20. 21. '22. Is conductor string provided ........................................ Will surface casing protect al! zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface amd intermediate or production strings .. Will cement cover all k~o~rm productive horizons ..................... Will all casing give adequate safety i~ collapse, tension and burst. Is this well to be kicked off from am existing wellbora ............. Is old wellbore abandonment, procedure included on 10-403 ... ......... Is adequate wellbore separation proposed ' eee. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. Is a dtveruer system required ....................................... ~ Is the drilling fluid program schematic and lis~ of equ/pment adequate/~' Are necessary diagrams and descriptions of d/verier and BOPE a=tached./~ Does BOPE have sufficient pressure ra~ing - Test ~o ,_,~OdDCD psig .. ~ reply /APl 53 (Hay 84) ' Does the choke manifold co w RP- . ................. Is the presence of H25 gas probable ................................. ,, , explora~o~'and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented POOL INITTAL CLASS STATUS GEO. AREA - UNIT NO. ON/OFF SHORE ?,zf ~S ! ,/ Additional Remarks: L 5'- ~.f ~_. sr~ . I / z '- . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. [,~S Taoe ~eriftcatlon List:ln~ $chlUmberQer Alaska Computiu;~ Center **** REEL HEADER DATE : 89/02/1~ O~IGIN : FLOC REEL N~E : 71113 CONTINUATION # PREVIOUS REEL COMMENT ~ ARCO, PRUOMOE BAY/LISBURNE POOL, LISBURNE L5-17, 50~029-21889 S~RVlC~ N~E : EO~T DATE : 89/02114 T~PE NA~E : 73113 CONTINUATION # PREVIOOM TAPE CO~ENT t ARCO, PRUDHO~ BAY/bISBURNEPOOb,'hISB~URN~ 55"1"7, 50~029-21889 FILE HEADER 2/li PAGEt ******************************************************************************** B ROU~H=. NORI~! SbOPE AP1 NUMBER: . 50'029'21889'00 ' I ~ '~ 5 ~., . LOCATION., 1823 FS5 & 15 P~3tR~J~M~M~,: ~:'lt~ ~ :~:~:~ ' ~' ' "' ...... ,0 ABOVE LIS ~'ape verification Listing Schlumberger Alaska Comp~t~ng Center 14-FE~-198. 11,21 DaTE bOGGeD: 28-jAN-~9 TD DRILLER: 11094 TD bOGGER: 11087 BIT ~I E 1~ 9 25 ItE ~- 6:~85 ~ 1'094 B~T B { TYPE F[~UID IN HOi~E{ BRINE DENSI' ¥: 9,2 LOGO~NO DISTRICT{ DG. GI~G ENGINEER: 4615 SCHWARTZ S~RINGER 54,0 GL: 20.0 REMARK~.~EDs: INTO SWS DblJ D:AT:ED 24~JAN-89 ){',{ TO FILE EDIT,O01 P W TH CASING AND CEMENT $c~,,1 ~berqer ~lasXa Co,put n'-~ e~ter 14-F~8-)989 i1~21 PAGEI 3 CORR.,CTION APPLIED. (~I~I~ P~S$, CH LIMESTONE ~ATRI×) NPNI.C~I, NPNI,CA?, & N~I.CTI COR~ECTIONS WERE TYPE ~ CONS Count 13 ce 0 "C A ~l~tUde c L m ~! .:.. :: ~!~:.~'i~O ~¥ .m",."l~ t'l 1J 1 mil ii:4 iq [:-] m : - LI$ Tape verification Listln,~ Schlumberoer alaska Co~Dutlnq Center i4-FEB-1989 i1:21 PAGB~ FO~MR? ~PECIFICRTION RECORD ** SET TYP~ - 64ZB TYPE REP~ CODE V~LUE I 66 0 0 000~ ~0 ?ace verification tlstino chlumber{~er Alask'a Computlnd Center ~ DATA RCFT,CN2 T~N$,CN2 NP~I,CTi DFP~ T~N$,CN2 NPHI,C~i PT, .PHY,'CTI DEPT, ~PHI.Cli li107,500 NPflI,CN2 928,443 CNTC,CN2 11100,000 ~PHI.CN2 1928,443 CNTC,CN2 200~:000733 CCb,CN2 ll00O 00O 3713757 3270000 1595 300{{.426 CFTC,CN2 1gB6.780 GR,CN -0.009 NPHI,CAi 6,543 NP~IeCA2 ,28B 3,609 TNRA,CN2 1981:781 · NPHi '02 RC~T,CN{ CNTC, ?~?C,CN2 3~50 38~0,834 , CCboCN2 0,009 NPhi,CA1 3,541 NPHIeCA2 508 TNRA 0. C .. , N 109 RCN'f,'CN2 Tape veriiicatlon List, ino mchlumber<~er Alaska ComOutlng Center DEPT. 10200.600 hFtil,CN2 RCFT. C~2 2]0.926 CNTC,C~2 ~'F~S ,C~2 2970 CCC CCb,C~J2 ~P~I .C'~J -999: ~50 DEPT, 10~,000 NPHI,CN2 ~CFT,CN2 ,568 CNTC,CN2 TE~S,CN2 2860,000 CC4.CN2 NPHY~CT! -999,250 DFPT, 9900.000 NPHI,CN2 RCFT,CN2 ~61.~67 CNTC,C~2 T~NS;CN2 ~$10, O0 CC~,CU2 NPHI;CI! -999.250 D~P?, gBGO,nn NPN!,CN2 RCFT~CN2 ' 405*876 CN?C,CN~ ' ' CN2 2B50,OOO CCb. C~2 N'PMI:.~C.:T:~~9:99~250 R.~F.? : ~ NPHI 97,00- 9~ 9. 2.55 CNTC,CN2 ;0::0'0: CC~CN:2 14-F~]B-~.989 1~ :21 PAGEI 51,626 T~Ra.CN2 1010.211 CFTC,CN2 4,448 RCN~,~ 238,247 G e -099.250 NPHI,CA2 '999,250 43 294 TN!~ CN2 '0, 07 NPHI,CAI 4.006 RCNT,CN2 .260,087 999.250 NPHI; A CN 1103:I 5 CFTC, '0.010 NPHI,CAI -99 250 NPHI,CA2 27,267 TNRA,CN2 118~, ,CN2 . ,CAi 3. 157 RC~T,C'~2 J,~9 GR.CN2 376, -999, 0 NPH~eCA2 -0 009 ,CN2 3,341 RCNT eCN2 363~'I54 :' GR NPH):.CAI -999,250 NPHI 1 ,.190 CFTC 0:08 3,5:22:~-R:C~T.CN,2: : ~ ! .339,686 OR,, CC ,ape ~eriticarlon I, lstinn Schlumberger glas~a Computing Ceoter i4-F£'E.-19E9 11:21 PAGE{ ? 30.231 112.5,8~4 O'OlO NPBI,CA1 355;584 GR,CN2 77, -999~-250 NPHI.CA2 '9~,~ F]L.E NA~E :-EDIT ,001 $~RVICE : FLIC VERSION : OO1A02 DATE { 89/02/14 { 1024 {: LO LAST FILE ~ · D g . ,g .002 ~C hAST .F,I.SE LiS ~ave verification Listin~ $chlumberoer AlasKa Com~ut~n~ Center I4-F~B-!9~9 11:21 PAGEI 8 TABL~ ~£¥P£ : CONS TU~"I.. V~LU DEFI ~ ARCO ALASKA, INC, Company Name STAT ~LASKA State or Province COU~ NORTH SLOPE County_ FL, !823' FSL & ~55' FE~ FXeZe Location TOWN 12~ Township RRNG 1SE R LONG ~G! SC.W~.TZ En~: SON 731~ .Se TABLE TYPE : CURV DEFI...... D. EPT DEPTH C~AN NA, E LIS '~ e l.a. e verification L,~stlno S~.hlU,~.ber,~er Alaska Co~'~uutln6 Center I~-FEB-1989 11:21 PAGEI mmmmm~mmmmm#mmm#mmmm~mmmmm~mmm TYPE REPR CODE VAbUE ~ 65 FT ~1 66 25 1~ 68 ~4 f5 FT 15 66 69 16 66 ~ 0 66 ~ oo oo 42 O0 TN£A. CN1 73099 42 420 0~, ~CN:T CN~ CPS 7:3099 4~0 O~ L,~ lace veriticati, on LJ. stin~ Sch].u~berner alaska Computino Center 11:21 PAGE: I0 *$** FILE TRAILE~ **** FILE NA~E : EDIT ,002 SERVICE : FLIC YERSlO~; : OOIAO~ D~TE : ~9/02/14 ~X REC SIZE : I0~4 FILE TYPE : LO LAST FILE : : 89/02/~ 4 N : FLIC 73~ 13 : ':: h RCO, PRUDHOE B AY/L.I S:B:URN~ :~P~O.O~ ,' :b tSBURNE 55" 17:,:.: 50-029~2I 889 ~.~::'~;~ :... ~..:.~ ~ · . ~ .~: : ~ ~ ~ : ..:: ~ PRI!D,~If~. ~AY/I, ISOUR.NE POOL LIS Tape Verification Listin~ PAGE~ ~$~ REEL BEiADER ~* S~RVICE N~ : GCT DATF : 89/02/13 REEL NA~E : 73134 CON?INU~T~ON # ~ PREVIOUS RE~L : COMMENT : GCT [,IS,ARCO P~UDHOE BAY/LISBURNE POOL t5-I7,50-029-21~9 ATE : 89/02/13 ~APE ~A~E~ CONTINUAT~O~ ~ S TAPE : CCT LIS,ARCO PRUDHOE B.A'Y/bI'$:BU~NE' POOL L5-17,50-029-21889 T DA LIS Ta~e verilicat~o~ l, isting Sc~lt3~berger ~]a~.~a Computing Center 13-FEB-1989 18:0i PAGE: E%EV~TIOMS KB: 55. DF: 5a, 28-Ja~'89 11~42. B~T SIZE 1: 9,875 ~ 10480 B{T SIZE ~:6,75 ~'11142 TYPE FLUIn I~ HOt, E: BRI~E DENSITY: 9,2 LOGGER ON BOTTOm! 04:0] 28-JAN PRUDHOE BAY SCHWARTZ WIT~ESS: SPRINGER TCC A :79 S~ $, F nce _bls Bchl .ABLE TYPE : CLtRV OEFI DEPT DEPTH ChANNeL N~ME H[,~ Devlatlom R~l~oth DFVI Deviation NSDR North South Drift EWD~ East ~est Drift Co~:ponent ED TRUE VERTICAb DEPTH AS CHANNEL, GDEP GYRG DEPTH CWEL CURVATURE OF THE~ WFbb PAGEI 3 DATA FOFMAT &PEC~FICATTOM ~ECO~D SET TYPE - 64EB ** TYPE RE,PR CO E 'A:b:I].E 0 I " 4 00~ ~000 ,~ 6t~ [3I~ Iapc Yerl~ication Li.s. ti[~,~ 8cbl,.~mberQer A].~t<a ComQut~° Center 3 ~,.B ]9~9 18:01 DFPT, 65516.5~0 HSAZ.GCT 9fi,644 DEVI,GCT 0.152 NSDR,GCT 0,000 EWD~.GCT 0,000 VDEP.GCT 40,000 GD£P,GCT 40.000 CWE[~,GCT 0,000 EWD~:GC? .458 VD~P,GCT 347,891 GDEP,GCT 347,900 CWEL,GCT O~PT. 65400.000 N~AZ.GCT 269,952 DEVI,GC? 23,392 NSDR,~C? ~ DR,'~W GCT -189,681 VDEP.GCT 3513.098 CDFP,GCT 354),798 CWE~ EWDR,~C? "48t!,844 VDEP.GCT , D~PT, 65284,000 HLAZ,.c EWDR.GCT '5120,613 VDEP.G T 9147;9~8 GDEP,GCI 11051,795 CWEL,~C? .% )mmmmmmmmm~m~mmmmmm~mmmmmmmmm$ F'~ELD" NA'~E ~ ~UDHOE BAY/LiBBU.NE POO[~ $~ATE ': : '~" :~' :i'i;A:SKA.: :. A'HOROUG : NORTH SL[iPE R~ ~ :'~ ~50"0~::29'.~.'~:~: 889"00 REFERENCE N~ ~ 73099 SCH,~U~BERGE[~ wF. bI., SERVICES DIVISION COMPIITING CENTER COMPANY NAME: WELL: FIELD: BOROUGH: STATE: APl NUMBER: ARCO ALASKA, ~C, PRIJOHOE BAY/LISBL!RNE POOL NORTH SLOPE AGASKA 50-029-218fl9-00 ~DCA?ION: I823' FSb & !55' PFRMANEN'r OATU;'~ ~,$i, KI,EV'ATION: O. RANGf]: 1SE LIS Tape veriffcation Listir~f~ SchlumbeTger AlasKa Comput]n~ Center 9-f'E~3~-i 989 09:40 bOG ~EASURED FR~M {{Kg 55. A[~[)¥E pE~A~ENT DATO~ ELEVATIONS K6: 55. ~F: 54, GL; 20. RUN NIJ~B~RI ONE TD DRIDbERI 1~142. TD !,O~GER! CASING ~: 7 5/8" ~ DR~[,LER DEPTH Of' 10480 BIT SIZE 1: 6 3/4" ~ 11142. TYP~ FLUID ,N HO~E, POLYMER ' ¥' ~ ~ VISCOSITY: 36. DEN$I~ . , MUD RESISTIVITY: 0 179 ~ 70. ~I~TR. ATE R~$I$~V Y. 0,15 ~ 60, ~{!D~CAKE.~E$ISTIViTY~ 0.264 ~ 6], T~M.E CIRCULATION ENDED: PRUD'~{OEBAY L~GGIN~ E:NG, I~E~i~R i) ARNER ~SKELL / VEN:H A U S/CODPER: ~ ANO LOGGER DEPTH OF 10480 STANDOFFS USED ON :R TYPE TUN1 VALU DEFI CN NtTI STAT COUN FL SECT TOWN RiNG ENGI D. WARNER SON 7~099 .APIN 50*029'21889' ARCO A~,ASKA, INC. Company Name PRUDHOE BAY/bISBURNE POOL Field Name LI~BURN~: 1;5-17 We~oNamei. USA Nat AbAS~:A State or Prov~nce NORTH SLOPE County_ 1823' FS[~ & 155' FEI, F~e~d boca~on 2 - Seet~on ilN Township ate t chlUmmerqer Ala$~a C. om;)ut~nq Center 9-FEB-1989 09:40 f'IAZ TENS H. TEN NPHT TR NR~ CNT CFTC ALI ~N~ ~T ~ ~EF1 Pad ~amma Tension ~UD TEMPERATURE HEAD TENSION NEUTRON POROSITY CALIBRATED THERF~L NEUTRDN RATIO RAW CORRECTED NEAR THERMAL COUNTS RA~ CORRECTED FA~ !HER~Ab COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FAR THERNAL COUNTS Gamma Ray Caliper Tension ~UD TE~PERA~.R~, HEAD TEN$10N oscopy ed Gamma Ray- ~Sm Thor[um, U~anium, end Potassium m URA,N Uraniu~ . ~2~C ~lndow 2. (,5- 1,,[ .) ~4NG PAGEI 4 ~tS Tape veri~.lcatio~ bistlno schlumberger AlasKa t~o~putinq Center o9:40 TYPE REPR C~ DE VALUE ~ 4 65 FT 15 66 68 1.6 66 1 o 66 0 ** SET TYPE - CHAN ** ..................... ..... .. .... ... ..... :;:--. ...... . ..... ........,,............. N~E SERV UNI? sErvIcE APl AP1 ~PI -~ FILE NUMB NUmB SIZE RE~ PROCESS ID ORDER # hOG TYPE CDAGS ~GD NUmB SA~P Ebf:~ CODE (HEX) O0 000 O0 0 ~ 1 ! 4 68 0000000000 68 0000000000 'T ~?E.~b~ O0 00.0 O0 0 ) 0 0 0 0 ~ 1 !,:ii' i ,-:~,i!1i 68 0000000000 ~g 0000000000 4 , 00( 0o0 0 1 ~. 4 PAGEI 5 0 0 0 I LIS Tape Verification bistinq SchltJmberqer AlasKa Com,',uting C~,nter 9-F}~-lgBq 09:40 PAGES 6 CAb! tnb TENS B~TEM CN6 HTEN SGR NGT C~R URAN NG~ W2NG W~N~ [,0~, ,.~YPE CbAS$ MOD N~MB SAMP EbE~ CODE (HEX) IN 5~8]B'; O0 0o0 oO 0 ] 1 I 4 6B 0000000000 ~ s~87 ~o ooo oo o ~ I i 4 ~ oooooooooo ~Eo? s~8~ ,~o ooo oo o ~ 1 I ~ ~ 0oo0oo0ooo I,~ 54~387 O0 000 O0 0 I 1 I 4 .- 0000000000 ~Pz s4~as7 uo ooo oo o ~ 1 ~ 4 ~ ooooeooooo ~,~, ~~v oo ooo oo o , , ~ 4 ~' oooooooooo ~ s~? oo ooo oo ~ ~ i ~ ~ 2~ oooooooooo Po s4~a~ oo ooo oo o ~ ~ 4 oooooooooo ~,~ s4sa~v oo ooo oo o 1 s 4 ~ oooooooooo eps s4e3o~ oo ooo oo o ~ ~ 4 .~ oooooooooo s ~8a87 oo ooo oo o ! 1 ~ ~ ~ ~s s~87 ooooo oo o ~ ~ ~ c~s ~sa~: ooooo oo o ~ ~ 4 ~i e~s ss~ooooo oo o , ~ ,._ O0000 O0 0 bO I ' ' LIS Tape Verification bist, ir~q ~TE,v,~GT 159. 125 C~{. DEPT, O~S T LL , ~DT [,SHV,LDT ~E~ LDT ~CN? CNb llOOO.oOo LLS,DLL 15.@91 TEMS,DL~ 1,331 RHOB,~DT 0.007 QSP, DT 90,91~ blT~,LDT 1166,000 $~HV.LDT 2,70t CALl,bDT 33.20t Pl~Z,L, DT 265.13'; HTEN,LD~ 6~86~000 RCFT,CNh 10 · 38 SGR,NGr 0.45b URAN.NGT 23'423 ~4MG"N~T 159'5.00 CS.NGT D 10900, DLb DLL, 58,878 536~,000 I08 ~084 438 466B 000 4~ 2~5 485 875 000 W5~G,NGT l.,LO~Dbb ~TE~DL6 DRMO LDT I.,S bDT $81 bDT SI. RH bDT GR bDT NPH! CGR~NGT ~I~G, NGT WS~,NGT HTEN,~G'r !8~,570 ,212 956,500 5OO -0 O0t 180 03 184 713 2 69,3 4 498 5845 000 0 20 w2NG,~GT TE~$.~GT SGR DbL RTEN DLL 552 bDT LSRH bDT 79,853! 5188'000 16 977 C 04 URAN i,~Gf ~GT 22 94 7 1045 5 N~ 3 W 0 H~ 7 hbD 9 DRH~ 8 SS 9 RS B NPHi T~ ,DT bDT ,DT 500 ~T] CNb D L L T N R N L ~I$ Ta~e Veriilcatiun f,~.stinq ChlUm erger alaska Computtno Center 9-1~ic:B-i{989 09:40 DEPT, 10700,OOU bLS CGR DL!, 10 179 TE.~S D~HI,LDT 2,943 LS.LDT -0.007 LL,LDT 94,262 LITI~ LSH~,LDT ~165,000 L!JR~,LDT 2 667 CALl DEVI,LS? 16~902 PIAZ ~TEM,LDT 16~0,250 HTEN HTE~,CN{, 102~.,145 CAbl POTA,NG~ 0,47~ URAN ~TEN,NGT 155.75u C$ D L b DLL DT .LDT bDT LDT LDT NGT 30~,535 5132.000 0 35 05(, 1218 000 6,996 I01,399 102~,625 795 ,000 4t 996 3 877 6 819 879 000 bbD,DLL MTE~.DI,L DRH~,LD~ L~,bDT SIRH'bDT RB,hDT GR,bDT NPMf,CN~ CNTC,CN~ TEN$,CN~ CGR,N~T WSN'G.,NGT HTEN,NGT 320,495 155,750 ~: ooo 18 313 18~ 05~ 659 177 697 7460 52~7 60~ lO t7 ,000 SGR HTEN PEF bSRH A~IM MTTEM TENS DbL DLL LDT LDT CNt: DEPT OLL ~DT LDT bDT ~DT 10600,OOU bbs ~9,346 TENS 27,966 RHO8 26b,725 LITH I161'000 SSHV ~ 06u 4oo DLh 5 P' bDT 0 L~T ~24 bDT 1216 hOT 3 bDT 595 ~NIb; : 2057 ~3 bbD,Dbb 1}~ 366 SGR 'Ot, L i25 HTEM DLL 0 ~TE~eDLL ,bDT 020 SS1,LDT 272 OOO S 1RH*!,bDT. 'il Z ~ NGT 9 000 5:08 b ~T )T T~ PAGE: . 31 t'75 000 ,8 "< ,,.9! CA I,I 0 000 H' 149 ORHO ,000 ;T $( LIS 7ape verif'lcation Listing SchlumbeY'ger Alaska Co~putJr)O Center -999,25(~ PI~Z,hC'T -9~9.250 ~TE~,SDT -~9. 50 RCFT,C~.!b -999. 50 CALI,CN5 -999,250 6GR,NGT 33,642 W4NG,NG~ 152,~75 C$'~G' EHD OF DATA 9-F~]iB-1989 09~4J ~999,250 999,250 -9~ 74 S~5 O0 NPHI,CNb TENS,CN~ CGR,N6T W~NG~NGT HTEN.N~T '999 250 TENS '999 250 TNRA -999 250 CFTC -999 250 49 574 TMOR ~2 0 DT NGT NGT PAGE~ *~** FILE TRAILER NAME ~ EDIT ,001 : F[~IC 00I AO~ ' . 9t02Y B ~ 1024 F,~** FIhE HEADER ~E U A LIS Tare Verl~lca SChlumberger Alaska Computlnq Center PAGg: 10 TOwN llN Township R~N'G 1SE R~ e LATI [,~ ude ENGI D WA~iER E] ame SON 7~099 Numbez APIN 50-029'21889-00 ~P1 Serial Numbe~ TABLE TYPE : CURV DEFI DEPT NEL NAME [,~S ' Shallow (ReSistiVitY) ~ U b~ CRe§istivit¥) mma-Ra¥ Ray ~rOm Thorlum, ATE~ MUD TEMPEI~AT .~RE Uranium, and Potassium ,: an,d:: Po~aSs'l,um 0 LIS Tape YeI'ltication b.;~st~nq SChlumberger AlasKa Co.,put nq Center 9-Fk:~-1989 09~40 PAGE{ 11 TYPE REPR CCtD~ VAbUE 9 6S 12 68 14 65 FT 15 66 68 1~ 66 t 0 66 1 SET TYPE - CHAN $, Ut~I? SEI~VICE ~p! APX R.p! APl FZt, E NUI~Ii3Nu~:B StZE :RgeR .eeOC:ESS DE:PT FT 54838~( 00 000 O0 0 · ~L8.: DLP' OHtqM ~,483:8',? O0 000 O0 0 0 ¸6 LIS Tape Yeri~ication Listing S~hlumberqer Alaska Computinq Center 9-FEB-1989 09140 ['AGE: ¸12 DEPT, i1000,000 LLS,DLR C~,DL~ 17.506 TEN$.DLR 8GR,NGR 4~ 65~{ CGR.NGR URAN.NGR .~4)2 ~ING,NGR W4NG,NGR 5 405 ~5..~.NGR CS,NG~ 887,50q HTEN.NGR D£P?, 10900.000 064 ~4N~ ~,481 C$'~GR 877.000 D'BR i3.553 3~,000 ~iTE~I.DLR 524 ,173 THOR,NGR 14H,9~6 ~2~iG,NGR 7,072 TEN$.NGR 5168,000 MTE~,DbR I ,904 W2NG.NGR 2,948 TENS.NGR DLR DLR NGR 17 '79 52t2 4]6 SGR 250 HTEN 445 POTA 679 W3NG 000 ~?E~ DLR NGR 57 5168 DI,,R 407, NC; R 5,2.0...~, 0 O0 52.494 1034,000 21'294 107:00-,: 0 O 0.:-; P,68.~ D 6R NGR DL R N ,R NS, CS,NOR 861'000 HTEN'NGR i009,5( DEPT, I0449,007 bLS.Dba ~0 150 ~::CG'~, DbR' : ':-':-.:"5 i~:~ 8'52:' 'TEN ~"'DL::R 48 2~ SG.~, :~E 7 ~, ii ,~ c~9. ~CR ~ ~ .~4NG.NGR 5.733 W5NG.NG NGR 157 00,0 OLR DLR ~6 LIS Tape Ver~..tca~ion i,.~.t~t;i~'~ Schlumberger A].asKa Con~t>utln9 Center 989 END OF DATA PAGEt t3 *$~ FILE TRAILER f'ILE NAME : EDIT ,002 SERVICE : FLIC VERSION : 001;%02 MAX. REC SIZE : 1024 FILE TYPE : LO b~ST FILE : ,003 VER$ I ON hAST FILE APIN & 155' FEI, 50-029-21889-00 Tow ha' r Provi, nce ; Name ~u-mber SLIS Ta~.e Verification L~sting cblUm erqer AlasKa (.o~pt. tlnc{ Center g-F~:B-~ 989 09:40 PAGEs 14 TYPE ~ C{JRV DE:PT DPH! D~HO DEPTH CHANNEl, NA~E Density Porosity ~ul~ D~nsit¥ Delta tho pboto-~lectric Factor UAb~TY CO~!~ROb OF bO~G S~AC~NC FUR bUT {)AbY?Y CONTRQL ON SHDRT SPACING FOR bDY ongSpacin~ ComPuted Count Rate [bb+bU/2 ,onQ UD~.r i-2 ~{ndow Count Rate (bU~+hU}~ On ~ower wlndo~ Count Rate {t~o~oq w{ndow Count Rate Short Spac(ng ~ Nlndow Cou t Rate 8~hort spacxnqz windo~ Count Rate LIS Tape Verification [~istlng $~h!umber~.er AlasKa ComD~]t~n~ Center 09:40 DATA FORA!AT SPECIffIC., 'A'I~,,It3N RECt, RD' '' ] ** SET TYPE - 64EP ** TXPE REPR CODE 0 ] 73 152 4 66 l 5 66 7 65 98 ~865 ~{Og9 11 66 6 12 68 ~] ~6 0 PAGE: 15 O0 0 0 LIS Tape Veiiiicatior Listiflg Schlumberger A]aS~a ComPutind CeBter NAM[ SERV JNIT SEW ICE APT AP! APl APl FILE NIT~B ~UMB ~TZE REPR P 0 ESS ID ORDER # LOG TYPE CLASS MOD NUMB SA~?'F ELE~ CODE (hEX) LB 54838~ O0 OOO On O 3 I 1 4 68 0000000000 548389 * 68 0000000000 TEN LDH PHT CNH PU O0 INRA CNH 548387 O0 RCN? CNW CPS 548387 O0 CFT CNH CPG 54838! O0 ~ C~H C.S s4e~8; O0 c,~c C~H c~s 548387 OD c~. ~A~! 54,387 oo o00 00o O0 000 O0 000 O0 00o O0 000 O0 000 O0 0 3 1 I 4 0 3 1 1 4 68 0000000000 0 3 1 I 4 68 0000000000 O 3 1 I 4 68 0000000000 0 3 I I 4 6g 0000000000 0 1 1 4 ~ ~000000000 O0000000O 0 I I 4 0 3 I 1 4 68 0000000000 0000000000 PAGE~ 16 DATA bDH ~4.TE~ C{~H I:1159,949 DPHI L, DH 3425 ,125 HTEN 750 '~b,: ,~:b~H': !'' .165 125 HTE., 2:?:'0:' :.RHOB bDH :2 4.'15: DRHO bDH 8,0~ 082 b$ [,DH 375 1211 000 $1RH ,H 7!5 '{CFT 461 LDH 0 GOO LIS Tape Yerifica~gion Listlnq $cblumberqer A].as~a Comuutinq Center 09:40 17 EF LDH LDH bORH bDH AZi~ LDU LDH ~o9oo,o49 4.691 256.2~0 2~' 44d 1,951 16~,750 10800 049 4 859 196 125 257 5o0 28~ib27 000 055 6620 OPHI bDH LSH¥ LDH DEVX LDH MTE~,LDH RCNT. CNH GR CNH HTEN CNH 10700,049: DPHI 750 LSH~ 24~, 14,390 137 ' ~ 1!6~ 000 445 2980 4~9 17 078 98 1 1061 RNOB.LDH LITH,LDH P1AZ,bD~ ~CFT,C~H CALX,CaH 2 0 RMOB bOH LITH bDH SSH.V ,{.,DH bDH bDH .406 CALl ,CN~ 464 DRHO.LDH 0 53 1219 8 SSi LDH t, DH LDH bDH LDH -CNH 2 O 3 64! DRHO 037 4 9 SIRH 039 RB 824 . OR LDH D.H CNH CNH 0 026 265 500 212 0OO 2 009 7 ~H ~H 7 PAGE; 16 PEF,LD[! LU,LDH SS2,LgH ~EN$,LDH T~RA,C~H C~T~,C~H 10450,049 ' ' 4 148.750 110 2 824 136 759 5044 000 47~ 44~ 709 156 625 END OF DATA 34,567 0,GO7 ~0.125 i164 0C 156 625 1590 425 78 -999 250 LITH~i'DH CALX*LDH ~TE~,L'DH CALI~C~H 2 119 DRHO.LDH -0 ! 0_6 L$ LDH 16 203 SS1 LOH 413 000 6iRH 895 RB 2?4 653 CNTC 895 TENS LDH LDH LDH CNH CNH -0 7O7 **** FILE TRAII,~ER **** ,003 ION : Og!A02 I 8'./02/8 ~XEREC ~IZE LAST FILE : ' ~:$i,,.,, FIhEH:E!A:OER::::,:i$*$* ,004 7 We Tape verification bisttn~ chlumberger Alaska Co~:PUtin Center 9-FhB-?969 09:40 PAGE; 19 COUN NORT~ &hOPE County_ .. FL 1823 FSL & 15~' FEb Field bocatton SECT 2 Section T~W~ 11N TownShip R~NG i5~ Range LAT! ba~tude SON 73~99 ~ APIN 50~029 21889-00 T~BLE TYPE ~ CURV DEFI RATIO R~NT RAW CORRECTED NEAR ,T}iERMAb CC, U~T5 RCF~ RAW COR:R:£:CTED FAR THERMAL' COUNT& :.. , :. ~ : : VAbUE 0 LIS Tape Veriiication List':ln~.~ Schlumberger AlasKa Computi, m_g Center 9-FEB-1989 09:40 PAGE: 20 T¥ REPR ODE VALUE 15 66 68 0 66 i $~$ SET TYPE - CHAN $* NAME SKRV UNIT SERVICE API AP1 API APl FIbE NUMB NUMB SIZE REPR ID ORDE{~ # LOG TYPE CLASS MOD NUMB SAMP E~E.~ CODE ................................,..,,...-...-----.----.---...--.....--..-...-...- 468:. 0¢ NPHI CNC ptl 548387 TNRA CNC 54B387 O0 000 O0 CPS 548387 O0 000 O0 CPS $48~87 O0 000 O0 T CNC CPS 5~8.387 O0 000 O0 :FTC CNC CPS 548]~7 O0 000 O0 OR CNC GAPI 548387 O0 000 O0 CAb! CNC T~ 54-#3~7 O0 000 O0 0 0 '~ 1 1 0 4 1 0 4 68 0 O0 29B0 0 ~' CNC HTEN ~, 9 RCNT 4920 000 I~ T£~4 500 HTEN 9~ 0 ~TEM, NC 48~0 000 4808 000 ~TEM ~NC TNRA, CNC 156 250 HTEN RCNT 1 LiS Tape Verification Listinq Scb~um.erqeI AlasKa £.or~:Lutin6 Ce~ter 9-Fk.B-1989 09:40 DEPT, 10000.00o ~PHI.CNC ~CFT.C~C 4~7.15~ C~T~:C~iC CAL!.C. IN' 2.898 TEN CNC DEPT, ggOOeO00 NPHI,CNC RCFT C,9C 43~.15b C~TC,CNC C~5~:CNC 2.~98 TEN$.C~C D~PT, 9800.000 NPHX,CNC RCFT,CN~ 42~,708 CNTC,CNC CAL~,¢N 2,898 TEN$.CNC DEPT. ~699.500 NPHI,CNC RCFT,CNC 410,129 CNTC.CNC CALI*CNC 2,8~8 TENS,CNC END OF DATA 38,421 TNRA.CNC 3.510 RCNT.CNC 14b~,975 CFTC,CNC 423.577 GR,CNC o 1478 51 C~TC,C~C 4628:O0 MTEM,CNC ! 0.000 HTENeCNC 42.077 TNRA,CNC 3~711 RCN?,CNC 1512,25 F' 5 9 37.157 TNRA.CNC 3,44! RCNT,CNC 4~60,000 1547,074 97'003 1549, 8910218 73099