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178-065
~ STATE OF ALASKA ( ALASKA LJIL AND GAS CONSERVATION COMMISSION ,,..-, .~. WELL COMPLETION OR RECOMPLETION REPORT AND LO$\~',' ~.T~' No. of Completions 1 a. Well Status: 0 Oil 0 Gas 0 Plugged iii Abandoned 0 Suspended 0 WAG 20AAC 25 105 20AAC 25 110 21. Logs Run: DIL 1 BHCS 1 CAL 1 GR, FDC 1 CNL 1 CAL 1 GR, GR 1 CNL 1 CCL, PAL, CAT CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE GRADE Top BOTTOM Top BOTTOM SIZE H-40 Surface 115' Surface 115' 30" N-80 Surface 2717' Surface 2717' 17-1/2" N-80 1 S0095 Surface 10881' Surface 9609' 12-1/4" 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage. Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1731' SNL, 1129' WEL, SEC. 09, T10N, R14E. UM Top of Productive Horizon: 4191' SNL. 3959' WEL. SEC. 09, T10N, R14E, UM Total Depth: 4400' SNL, 4376' WEL, SEC. 09, T10N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 675356 y- 5938612 Zone- ASP4 TPI: x- 672589 y- 5936088 Zone- ASP4 Total Depth: x- 672178 y- 5935869 Zone- ASP4 ---~ 18. Directional Survey 0 Yes iii No 22. CASING SIZE 20" 13-3/8" 9-518" WT. PER FT. 94# 72# 47# 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD 26. Date First Production: Not on Production Date of Test Hours Tested Flow Tubing Casing Pressure Press. Zero Other 5. Date Comp., Susp., or Aband. 5/15/2004 6. Date Spudded 02/26/1979 7. Date T. D. Reached 03/17/1979 8. KB Elevation (ft): 73' 9. Plug Back Depth (MD+ TVD) 10264 + 9098 10. Total Depth (MD+ TVD) 10895 + 9620 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 24. SIZE N/A TVD .: ~ : ': ....~~. ~~> ;,.:¡\i ;} . ¡'niJ4 1b. Well Class: . " :11 :üevelcipment - tJ ExploratorY 0 Stratigraphic. ,D. Service 12. Permit to Drill Number 178-065 / 304-050 " 13. API Number 50- 029-20328-00-00 14. Well Name and Number: PBU 14-06 15. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028312 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTING RECORD 300 sx Arcticset 5000 sx Permafrost II 1000 sx Class 'G', 300 sx Permafrost AMOUNT PULLED TUBING RECORD DEPTH SET (MD) PACKER SET (MD) ACID, FRACTURE, CEMENT SQUEEZE, ETC. /'- DEPTH INTERVAL (MD) AMOUNT & KIND ÓF MATERIAL USED 9988' P&A / Kick Off Plug/ 1TBbls Class 'G' ./ \ , '......-::- Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 25. GAs-McF WATER-BsL PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A PRODUCTION FOR OIL-BSL TEST PERIOD + CALCULATED + OIL-BsL 24-HoUR RATE GAs-MCF WATER-BsL ¡J1i ~\ '\ ''.\,1 CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessar.¥'t.~. Submit core chips; if none, state "none". ~ 1\) Ó. ~ 1I¡¡;;'.t )J,\,.. None ~~~""'" n 0 1 ~ \ ~,' l\ , . " 27. [" ,; 26. , 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". Sag River 10046' 8916' None Shublik 10060' 8928' Top Sadlerochit 10062' 8930' Base Sadlerochit 10787' 9531' F.'~! (: (~,: F:. ,~ "1 I r,:..~ . ~. .:' .1" j' '.) :.' !~;~) I) \) 4. :','~ . \ ;...: ".: ".. '~ ' . I". ,I' 11 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 Terrie Hubble ~Q/V\i °- "fJ,J ~ Title Technical Assistant Date Ob - 30 --Ot{ PBU 14-06 178-065 304-050 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Dolling Engineer: Dan Kara. 564-5667 Permit NO.1 Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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: 14-06A Prudhoe Bay Unit 50-029-20328-01-00 204-036 Accept: Spud: Release: Rig: 04/19/04 05/1 7/04 OS/21 /04 Nordic #2 03/10/04 DRIFT W/ 4.50 CENT SB / SD @ 2011' SLM POOH. DRIFT W/ 4.50 CENT 5.95 GR. PULL 7" FRAC SLEEVE 4.035 ID THREE SETS OS PKG FROM 2011' SLM. TAGGED SUSPECTED COLLAPSED TBG @ 8761' SLM, M/T SAMPLE BAILER. PRE-RIG WORK 03/29/04 CHEMICAL CUT TUBING AT 8739' MD (MIDDLE OF 1 ST FULL JOINT ABOVE TUBING COLLAPSE). MADE 4 RUNS. TAGGED COLLAPSE AT 8788' MD W/ GR-CCL ON FIRST RUN. 500# OVER PULL AFTER TAG. PUNCHED TUBING FROM 8700' MD-8702' MD. STRINGSHOT FROM 8728.5' MD - 8740.5' MD. BP EXPLORATION Operations Summary Report Page 1 ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hours Task Code NPT Phase Description of Operations 4/18/2004 03:00 - 03:30 0.50 MOB P PRE Held Safety Meeting tor moving off of End 1-65 Well 03:30 - 09:30 6.00 MOB P PRE Move ng off well 09:30 - 00:00 14.50 MOB P PRE Start moving from MPI to SDI and Ice road at 0930 hrS..no problems 4/19/2004 00:00 - 07:30 7.50 MOB P PRE Move rig from Endicott MPI to DS 14 At 0515 hrs. ng between West gate and DS14. On location at 0730hrs 07:30 - 12:00 4.50 RIGU P PRE Start rig-up to raise derrick. Raise and secure lines and equipment. 12:00 - 12:30 0.50 RIGU P PRE Move over well. Accept rig at 1230 hrs 4-19-2004 12:30 - 15:30 3.00 BOPSUP P PRE R/U circulating lines to wellhead. Set-in Tiger Tank and rlu hardlines and PT wI diesel. Take on 140deg seawater. 15:30 - 15:50 0.33 BOPSUF P PRE PJSM with crews. Review plan forward. 15:50 - 17:00 1.17 BOPSUPP PRE Continue filling pits. Circulate SW through manifold lines. Test lines 17:00 - 20:20 3.33 BOPSUF P PRE Check wellhead pressures: IA on vacuum. Tbg on vacuum. Line up to pump down tbg taking returns from IA to Tiger Tank. Start pumping down tubing. Returns after 15 bbls away. Pump at 4-7bpm Pumped 760 bbl around. fluid sample clean 20:20 - 20:45 0.42 BOPSUP P PRE PJSM on SIMOPS, Loading Pipe shed and Install BPV/TWC and PT 20:45 - 23:00 2.25 BOPSUF P PRE RU to monitor lA, set BPV with Test Dart and PT upper tree to 1066 psi.(OK) FilllA SIMOPS. Loading pipe shed with 3-1/2" 15.5 S-135 DP, steaming out ice on every it of 3-1/2. drifting and tailing 23:00 - 00:00 1.00 BOPSUF P PRE ND 7" 5k Tree Filling hole peroidically. BPV/TWC started to leak. while filling the hole with charger pump. Tighten tree back up and called DSM to pull and reset TWC. Still fill pipe shed with DP. 4/20/2004 00:00 - 02:30 2.50 BOPSUP P PRE Finished tighting tree, wait on DSM and loading pipe shed with 3-1/2" DP 02:30 - 05:30 3.00 BOPSUF N SFAL PRE Reset TWC Still getting blow by past the BPV, Pump 5 bbl fluid through the BPV and check to see if it holds IA static and tubing small blow, BPV will not hold anything. Pull BPV to check seals. Bleed wellhead pressure to 0 psi. Increased spring tension on BPV and reset in tubing hanger. Pumped 15 bbl fluid down IA and BPV holding from U-tube effect of well bore. Installed test dart and PT topside to 1154 psi. 05:30 - 09:00 3.50 BOPSUP P PRE Load out TWC lubricator and ND 7" tree 09:00 - 10:00 1.00 BOPSUR P PRE Clean up the tubing hanger. Indentify threads as buttress. Clean up cellar prep to NU 13 5/8" BOP 10:00 - 21 :43 11.72 BOPSUF P PRE Nipple up 13 5/8" 5K stack. Change out lower rams to 7" casing rams. Load rig floor with 7" & 5-1/2" handling tools, Loading pipe shed with 3-1/2" DP. PT BOP's 21 :43 - 00:00 2.28 BOPSUF P PRE PT BOP Witiness by Lou Gramaldi with AOGCC. PT blind and associated valving to 250/3500 psi. Installed 7" 29#/ft BT&C casing test it. screw-in 9 rounds. PT 7" Pipe Rams to 250/3500 psi 4/21/2004 00:00 - 07:30 7.50 BOPSUP P PRE Finish testing BOP stack. Test floor valves. Test H2S/M gas monitors. 07:30 - 08:30 1.00 PULL P DECOMP UD test it. Clean-up floor. Make-up FOSV for 7" casing. Remove surface SSSV control line valve assemblies from wellhead. Prinred: 5/24/2004 10 40 07 AM BP EXPLORATION Operations Summary Report Page 2 - Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 4-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hours Task Code NPT Phase Description of Operations 4/21/2004 08:30 - 10:20 1.83 PULL P DECaMP Pull dart from BPV. Well on vacuum. R/U lubricator extensions and set in annular and close annular. R/U lubncator and retrieve BPV. RID lubricator tools. 10'20 - 12:00 1.67 PULL P DECaMP Fill tbg/annulus. Took 70 bbls. Lot of air coming back from filling. Increase counter balance weights for rotary tongs and rlu tongs and lines. R/u Easy-Torque. Watching well burp air. 12:00 - 13:30 1.50 PULL P DECaMP Close blind rams let well settle down from filling. M/U liner spear BHA. Easy-Torque not putting out enough hyd pressure to m/u tools rec. torque value. Adjust hydraulic regulator. Continue m/u tools. Open blinds. Pump another 40 bbls down tbg Still unable to fill. 13:30 - 14:20 0.83 PULL P DECaMP Talk to town about inability to keep hole full and well work ahead. Opt to pump another CaC03 plug as was previously done to RU. Continue to stili attempt pulling hanger. Contact MI & SLB to move on pumping another pill. 14:20 - 15:30 1.17 PULL P DECaMP PJSM with crews. Clear floor area of non-essential personnel. Pull on hanger in stages to 225k and came free. Pull hanger above table wI 165k. UD hanger and pup jts. 15:30 - 15:45 0.25 PULL P DECOMP PJSM review changes in plan forward. 15:45 - 17:00 1.25 PULL P DECaMP Clean-up floor area and make ready for pumping pill. 17:00 - 18:00 1.00 PULL N DPRB DECaMP Wait for equipment and CaC03 pill. R/U SLB pump truck 18:00 - 19:45 1.75 PULL N DPRB DECaMP Crew change PJSM with oncoming crews and review plan forward. Ordered 4 extra trucks and held operational meeting on way forward 19:45 - 20:30 0.75 PULL N DPRB DECaMP RU to conduct Injective test 20:30 - 21:45 1.25 PULL N DECaMP 0 = 6 bpm Caught fluid at 60 bbl pumped 2200 ft, Cir at 1:1 ratio Confirm with pit straps Cir 30 minutes and no fluid loss. Last 10 minutes lost 3 bbl. Cir at 1.6/0.75 bpm.Changed 0=2.00 returns at 1.40 bpm AD Dow Cement truck, Keep CaC03 on location till AM. Open well and wells is U-tubing. Density in tubing at 8 ppg, diesel still in pit system. 21 :45 - 22:02 0.28 PULL N DECaMP Line up to pump clean 2~oKCL down tubing. 22:02 - 23:05 1.05 PULL N DECaMP Fluid packing well bore with 8.4ppg 2~'óKCL Pumped 290 bbl at 0 = 6.1/5.2bpm. dfopwn tubing Conducted Tabletop meeting on "Well Control While Tripping While Circulating" 23:05 - 00:00 0.92 PULL N DECaMP PUH 150k up wt. 7" IJ4S on top, Called for 7" IJ4S lift nubbins and 150T HYC elevators. 4/22/2004 00:00 - 03:45 3.75 PULL N WAIT DECaMP WO on Nubbins and elvator for 7" IJ4S tubing. Cir the well at 2.39/1.92 bpm caught fluid with 36 bbl pumped 1440 ft down. Nubbins showed up from Tool Service and they are the same aD and the Tubing T J. Found a set of 7" HYC 150T spiders/ elevators on Nordic Rig 3. Tool Ser. is headed there to PU the spiders and longer bails. Found another set at Nabors Yard 125T HYC they are redressing them and will be delivered. 03:45 - 04:30 0.75 PULL N DECaMP PU and LD tubing, LD XO, 1 SJ and one jt 45 ft long and found bird nested control cables. 04:30 - 06:00 1.50 PULL N DECaMP Pulling 7" Dealing with nested control lines. RU Cameo spooler Pumped 35 bbl2% KCL down well. 06:00 - 15:00 9.00 PULL P DECaMP POOH LD 7" tubing. Small problem with pulling 1:1 with control lines. Work pipe and free up bunched lines. Continue pulling adding 10 bbls to backside every 5 its out. After pUlling 35 jts fill-up backside with 30 bbls but not seeing any U-tubing. Pnnled: 5/24/2004 10'40'07 AM BP EXPLORATION Operations Summary Report Page 3. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hours Task Code NPT Phase Description of Operations 4/22/2004 06:00 - 15:00 9.00 PULL P DECOMP Continue pulling to 39 its out while filling backside. P/U FOSV and pump 98 bbls down tubing. Not seeing circulation. Mostly likely bunched control lines and encapsulation material preventing circulation. Remove FOSV and in the process of lifting it with tugger one of the Eckel tongs dies popped out and fell down the tubing. ( 5"L x 1.25"W x 0.4275 T). Hammer over die slots. Continue pulling pipe. Filling backside. Pull to just above SSSV assembly. Remove rat nest of control lines. Total band recovery is 17 out of 28. change out XO on FOSV. Pull and lId SSSV assembly. Note: Update on 5/12/04 Tong die was found at the top of the collapsed it by the Wells Group-Kara has it on his desk and has the details-cis 15:00-16:15 1.25 PULL P DECOMP MIU FOSV fill hole with 56 bbls pumping at 2.5bpm, not circulating but backside staying full. Shutdown for 30 min and finish removing 7" tbg from pipe shed. Refill well with 46 bbls pumping at 6 bpm getting < 1 O~o returns. Remove FOSV 16:15 - 00:00 7.75 PULL P DECOMP Continue LD 7" tubing and 2 GLM wI XO subs. (88jts to the 5 1/2") Recovered control lines and lost encapsulation material. lost 11 cable clamps and 1 tong die at 1900 hrs Filling the hole every 5 jts pulled with 10 to 15 bbl SW. Hole is fulling up to top using 10 to 17 bbll5 jts pulled. Pulled 135 jts 7" tubing, 4 7" GLM 4/23/2004 00:00 - 02:00 2.00 PULL P DECOMP Change over to 5-112" handling tools. PU Test plug with XO and land 5-112" tubing in hanger 02:00 - 03:30 1.50 BOPSUF P DECOMP RU and change out ram blocks to 2-7/8" X 5-112" VBR 03:30 - 05:00 1.50 BOPSUF P DECOMP Conducting BOP test, Test plug leaks, pull out 3-1/2" test jt and test against blins and plug, same leak rate 05:00 - 05:45 0.75 BOPSUPN SFAL DECOMP Pump 34 bbl down backside, Pull test plug O-Ring slightly rooled, Change out test plugs and landed in tubing spool 05:45 - 06:30 0.75 BOPSUF P DECOMP Retest VBR's 250 low 3500 high. 06:30 - 07:15 0.75 BOPSUF P DECOMP UD test plug. Filling hole. Took 75 bbls to fill. 07:15 - 14:00 6.75 PULL P DECOMP Continue with lId of 5 1/2" tbg. Filling hole every 5 jts. taking 15-20 bbls each time. Chemical cut was 21' below collar fairly clean cut 5.83" OD. Filled hole with 35 bbls. 14:00 - 18:00 4.00 FISH P DECOMP Breakout FOSV assembly. Clean-up rig floor. Layout tools and 5 1/2" tbg. Fill hole after 30 min took 36 bbls. 18:00 - 19:00 1.00 FISH N SFAL DECOMP Install 8-15/16" WB, wrong size, wait on CIW Sent out Gen III wear bushing instead of Gen II 19:00 - 20:00 1.00 FISH P DECOMP Install 13-5/8" X 815/16" WB and run in 4 LDS 20:00 - 21 :30 1.50 FISH P DECOMP Clean floor and make ready to bring in remaining 3-1/2" DP Filled hole wI 50 bbl SW Volume total pumped while pulling completion = 1032 bbl minus the tubing displacement 83 bbl = 949 bbl Time total to pull compeltion = 37.25 hrs. Filled hole at approximately 25.4765 bph 21 :30 - 00:00 2.50 FISH P DECOMP Loaded pipe shed. steaming out Weatherford'd I API 3-1/2" DP. plugged with ice & snow. Drift with cable (Nordic Vac system won't work on DP) and tally Filling hole every hr wI 35 bblSW 4/24/2004 00:00 - 08:00 8.00 FISH P DECOMP Loading Pipe shed with 3-1/2" DP. DP plugged with snow and ice. Steaming out. drifting and tailing. Finally got Vac system working. Punt""j 5:2412004 1041) 07 AM BP EXPLORATION Page 4 ~ Operations Summary Report Legal Well Name: 14-06 Common Well Name: 14-06 Spud Date: 2/26/1979 Event Name: REENTER+COMPLETE Start: 4/18/2004 End: 5/21 /2004 Contractor Name: NORDIC CALISTA Rig Release: 5/21 /2004 Rig Name: NORDIC 2 Rig Number: Date From - To Hou rs Task Code NPT Phase Description of Operations 4/24/2004 00:00 - 08:00 8.00 FISH P DECOMP Loaded rig floor with fishing tools. Filling hole every hour with 35 bbl Loading in 16 4-3/4" DC and the remaining 28 jts ot 3-1/2" DP 08:00 - 09:50 1.83 FISH P DECOMP P/U BOT fishing tools. 09:50-10:10 0.33 FISH DECOMP PJSM review plu of DC's and DP 10:10 - 11 :20 1.17 FISH P DECOMP P/U 16- 4 5/8" spiral DC's 11 :20 - 22:00 10.67 FISH P DECOMP P/U 3 1/2" DP PU 227 jts 3-1/2" 15.5#/ft 5-135 DP D= 7708 ft 22:00 - 00:00 2.00 FISH P DECOMP PU kelly, bushings. sock and swivel 4/25/2004 00:00 - 02:40 2.67 FISH P DECOMP RU Kelly and associated equipment Installed 5" LKV and 4-3/4" 55. Torqued 6-5/8" X 8 LD to 30.000 ft-Ib RU kell spinner and test 02:40 - 03: 1 0 0.50 FISH P DECOMP Tested Lower and upper kelly valve. Charted 03: 1 0 - 05:00 1.83 FISH P DECOMP PU & RIH with 3-1/2" DP Ran 259 its Weights @ 143k up and 121 k down wo pumps 05:00 - 07:00 2.00 FISH N RREP DECOMP P/U kelly and start cirulation. Standpipe valve leaking. Repair Demco valve. 07:00 - 08:00 1.00 FISH P DECOMP Pump @ 3bpm and 275psi. Slack off to tag top of tbg stump @ 8732' (7' high of WLM) BHA + 259 jts + 35' kelly down. POH and install a 12' pup to aid in kelly length. 162k up 1137k dn. Rotating wt = 147k w/pump. Rotating torque 200amps @20 rpm. With 3 bpm 275psi slack off to wash and rotate over fish wI max wt of 4k, Stop rotary table and continue to slack off and observe pressure increase to 600psi when pack-off engaged and in grapple. Shutdown pump and continue to slack off to bottom out on extension. Set down 10k to verify jars cocked. Pull up to 175k (13k over) and observed overpull fall off to have an upweight of 162k +1-. Attempt to pump down drill stnng and observed the pipe was packed off and could regain circulation again. We did tag lower on the kelly when attempt to set back down. Suspect fish on although no significant weight increase in upweight. 08:00 - 14:00 6.00 FISH P DECOMP Set back and blowdown kelly. lId pup jt. TOH with 129 stds and X. 14:00 - 17:30 3.50 FISH P DECOMP UD accelerators. Standback 8 stds DC's. UD jars. Fish at surface. Control lines hanging out of OS. Crew change 17:30 - 18:00 0.50 FISH P DECOMP PJSM on handling the OS with fish 18:00 - 19:00 1.00 FISH P DECOMP PUH and recovered 64 ft 5-1/2" tubing Cutoff piece and 1 joint which the last 17 ft casing pulled, 100% collasped. OD of the bottom is 4.30" 19:00 - 21:15 2.25 FISH P DECOMP Break out OS and LD fish. MU 6" grapple and load out fishing tools Filling hole every 60 with 30 bbl SW Due 10 the conditions of the 5-1/2" L T&C ABM pin at surface it was decided to make a drift run and then chem cut above the PBR 21: 15 - 22:00 0.75 FISH N HMAN DECOMP WO Wireline to drift 5-1/2" tubing for chemical cut 22:00 - 00:00 2.00 FISH N HMAN DECOMP RU lubricator in annular and secured with slips and collar clamp. RU Halliburton WL to run TS & TEL. 4/26/2004 00:00 - 02:00 2.00 FISH N HMAN DECOMP RU Halliburton WL to run 3.85" TS & TEL. HWS having trouble with rigging up on Nordic 2. WL rubbing rigs hydraluic hoses on kelly Ran 2 sheaves. Also had trouble with feeding their. 1 08" wire through their packoff 02:00 - 02:45 0.75 FISH N HMAN DECOMP RIH wi 3.85" TS & TEL, Found TT wi TEL at 9820 ft. Fish Pnntea. 51241200~ 10'4007 M./I BP EXPLORATION Operations Summary Report Page 5 ... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hours Task Code NPT Phase Description of Operations 4/26/2004 02:00 . 02:45 0.75 FISH N HMAN DECOMP clean. POOH 02:45 - 03: 15 0.50 FISH N HMAN DECOMP RD Halliburton WL Pump 35 bbl SW mto well 03:15 - 03:30 0.25 FISH N HMAN DECOMP Wait on SWS to make Chemical cut 03:30 - 05:30 2.00 FISH P DECOMP RU SWS to run string shot and chemical cutter 05:30 - 06:55 1.42 FISH P DECOMP RIH with string shot 06:55 - 07: 1 0 0.25 FISH P DECOMP Tie-in to prod CCL. Position SS at 9735' and fire. 07:10 - 08:45 1.58 FISH P DECOMP POH. Recovered 1 1/2 SS control line clamps that were stuck in centrilizer. This make +1- 22 total bands recovered out of 28. Checked the inside of colla sped tubing for junk but found none. 08:45 - 09:00 0.25 FISH N HMAN DECOMP PJSM review procedures for handling SWS chemical cutter. 09:00 - 09:30 0.50 FISH N HMAN DECOMP P/U chemical cutter 09:30 - 10:30 1.00 FISH N HMAN DECOMP RIH wi chemical cutter stopped at 8796' top of fish. 10:30 - 12:30 2.00 FISH N HMAN DECOMP Work numerous times. Slight overpulls toward the end of trying. Stop and POH. Marks on cutter barrel 180 deg apart indicate fairly good restriction. Discuss options with town. RD SWS 12:30 - 15:00 2.50 FISH N HMAN DECOMP Wait for slickline. Plan forward..run 4.25" drift. If successful run 4.185" chemical cutter. 15:00 - 19:00 4.00 FISH N DPRB DECOMP R/U Howco wireline unit. Came with 4.30" drift. Looking for smaller 4.20" Told to run tapered 4.30" while looking or making the other. Same time set in e-free 2 3/8" coil reel #10657 wi 14700' and 400k running ft. 19:00 - 20:00 1.00 FISH N DPRB DECOMP RIH and tagged 8803 WLMD with 4.3" TS. Worked 10 times and was unable to stick. Sometimes it would go down to 8815 ft and clean PU 20:00 - 20:30 0.50 FISH N DPRB DECOMP POOH to look at 4.3" TS and then RU to run 4.2" TS SWS Cutter OD at 4.187" 20:30 - 21 :45 1.25 FISH N DPRB DECOMP No marks on 4.3 TS, PU and RIH with 4.2" TS Tagged at 8803 ft. Worked through to 8815 ft and the finally worked through 8815 and RIH to 4-1/2" XO at 9805' WLMD. POOH to 8788' RIH and tagged again at 8803ft and 8815' Trash in the hole from the previously fishing operation. Not sticky at all, acts junk in the hole POOH, few scratches on the front of TS and bottom gauge side of TS 21 :45 - 00:00 2.25 FISH N DPRB DECOMP PU, RIH with 3.8" JB I GR, Ordered 4.2 from WL building. RIH wI 3.75" X 3.81" JB 1 GR. Tagged at 8803' worked down to 8815' and then fell through. PUH and was unable to get past 8815' again. Acted just like the other two runs. POOH 4/27/2004 00:00 - 00:34 0.57 FISH N DPRB DECOMP POOH to look at JB and make ready to do a outside cut on 5-1/2"casing. Recovered small pieces of control line covenng. Marks on the top 3.8 GR 00:34 - 01 :00 0.43 FISH N DPRB DECOMP RDWL 01:00 - 03:15 2.25 FISH P DECOMP RU BOT External Cutter BHA 03: 15 - 05:00 1.75 FISH P DECOMP RI H with DC 05:00 - 11 :20 6.33 FISH P DECOMP RIH with 3-1/2" drill pipe. P/U single and kelly. 11 :20 . 12:00 0.67 FISH P DECOMP Check wts up= 163k dw= 155k w/pumps. RIH tag top of fish at 8795' DP depth. Rotate over 5-1/2" collar with some torque seen. Continue clean another 12' to have 35' OOK. PJU another 2 singles. 12:00 - 14:50 2.83 FISH P DECOMP Rotate at 20 rpm, pumps at 3 bpm, 375 psi pump pressure. Losing fluid at 65 bph. Begin cutting tubing. 14:50 - 14:55 0.08 FISH P DECOMP Attempt PU to see if we have a cut. Pulled to 170 klbs, 7 klbs Pnnled' 5/24/2004 10 40 07 AM BP EXPLORATION Operations Summary Report Page 6 .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hours Task Code NPT Phase Description of Operations 4/27/2004 14:50 - 14:55 0.08 FISH P DECOMP over normal. Do not apparently have a full cut. 14:55 - 15:30 0.58 FISH P DECOMP Resume cutting. 3 bpm, 20 rpm. 15:30 - 15:35 0.08 FISH P DECOMP Attemp PU again. Pull to 170 klbs. Do no apparently have a full cut. 15:35 - 15:50 0.25 FISH P DECOMP Resume cutting. 15:50 - 16:30 0.67 FISH P DECOMP If cutter has operated properly. the pipe should be cut. Attempt PU. pull to 185 klbs. Still not cut. Rotate pipe, not stuck. able to rotate ok. Fishing hand thinks cutter blades are probably broken, and we do not have a cut. If so, it takes 80 klbs to pull baskets over tubing collar and get off of fish. PU to 200 klbs, no go. Slack off, PU to 200 klbs, bobble in weight at 185 klbs. May be first basket pulling over tool joint. Still not free. Slack off, and pick up to 225 klbs. Still not free. Slack off, rotate pipe ok. Not stuck on debris on outside of washover pipe. PU to 250 klbs, 85 klbs over normal. Not free. Slack off. PU to 200 klbs, and popped free. Fishing hand suspects both baskets have pulled past connection, with no cut. Send fishing hand back to Deadhorse for new cutter. Prepare to trip pipe OOH to inspect/replace cutter. 16:30 - 17:15 0.75 FISH P DECOMP Stand back kelly. 17:15 - 00:00 6.75 FISH P DECOMP POH with drillpipe and cutter BHA. PU weight was 165 klbs. indicating we do not have the fish pulled out of the PBR. 4/28/2004 00:00 - 00:30 0.50 FISH N DPRB DECOMP Continue to POOH with outside cutter BHA 00:30 - 02:00 1.50 FISH N DPRB DECOMP Stab back collars & other BHA components. Inspect cutter assembly. All knives broken. Cutright guide shoe shows signs of having run on junk. This should now be cleared from top of fish. 02:00 - 03:30 1.50 FISH P DECOMP Discuss options. Agree with junk cleared. a second cutter run is plan forward. Hold brief PJSM with floor crew. MU same with shortened guide shoe. No significant metal found in boot basket. Some small chunks of rubber. 03:30 - 05:00 1.50 FISH P DECOMP MU second cutter BHA and drill collars. 05:00 - 10:45 5.75 FISH P DECOMP RIH with 2nd cutter BHA on 3-1/2" DP. 10:45 - 11 :05 0.33 FISH P DECOMP PJSM prior to washing over fish. Discuss technique and plan forward to avoid losing cutters again. 11 :05 - 11 :35 0.50 FISH P DECOMP Ease down with DP. Tag top of fish with guide shoe. Tagged 3 times. Can't get over it, and tool connection is at the rig floor. PU, install 5' pup joint. RIH to l' above fish, rotate the pipe, slipped over fish easily. Continue RIH until last tool joint. 11 :35 - 12:00 0.42 FISH P DECOMP Make up Kelly. 12:00 - 17:10 5.17 FISH P DECOMP Ease down at 140 klbs down weight. Stop with basket 4' below tubing collar. Bring on pumps, begin cutting operations. Rotating at 20 rpm. Pumping at 3 bpm, 350 psi. Rotate for 5 minutes, stop rotation. PU 0.1', rotate again. repeat picking up and rotating in 0.1' increments. Continuing to lose fluid at 70 bbls/hr. Increase in torque at the 7' mark, indicating potential cutting of pipe. Continued to PU in 0.1' increments for 2 additional feet. Then PU 20 clean with no indication of any overpull. All indications are that we have a cut. 17:10 - 17:50 0.67 FISH P DECOMP Stand back Kelly. 17:50 - 00:00 6.17 FISH P DECOMP Pick up first stand above where top of fish was. Slack back down. No weight bobble observed. Good indication that the cut was successful. Continue tripping OOH. Monitor hole fill Pr,ntea 5124 '2004 10'40 07 AM BP EXPLORATION Operations Summary Report Page 7~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hours Task Code NPT Phase Description of Operations 4/28/2004 17:50 - 00:00 6.17 FISH P DECOMP dUring trip. 4/29/2004 00:00 - 01 :00 1.00 FISH P DECOMP Stand back drill collars. 01 :00 - 03:00 2.00 FISH P DECOMP LD fishing tools. LD cut tubing fish. Recovered one 43.27" jt with collar, 2.57' stub with collar below full jt with clean external cut. Cut not egged and should drift to 4.5" ok. Upper collar egged, cut from top down 1"-2". and shaved on od. Would have been very hard to overshot with grapple. 03:00 - 05:00 2.00 BOPSUF P DECOMP Pull wear bushing. Set test plug. RU Hot Oil pump to fill hole down inner annulus valve during BOP test. 05:00 - 11 :30 6.50 BOPSUF P DECOMP Perform weekly BOP test. Witness waived by J. Spaulding. AOGCC. All passed except hydril. Had debris on top of bag. Washed top of bag with a hose and retested. Passed ok. 11 :30 - 14:00 2.50 BOPSUF P DECOMP Pull test plug, set wear bushing. Release Hot Oil pumper and resume keeping hole full with the rig C pump. 14:00 - 14:30 0.50 FISH P DECOMP Safety meeting prior to rigging up slickline unit. New SL employees and unfamaliarity of the rig discussed. Job plan was reviewed. Hazards of job were discussed and mitigations to hazards reviewed. 14:30 - 15:30 1.00 FISH P DECOMP Rig up slickline unit. 15:30 - 18:30 3.00 FISH P DECOMP RIH with slickline BHA with 4-1/2" drift, spang jars, and oil jars. Tag some junk at 8300', well above top of tbg fish. Work past same. Drift to 9775' slickline depth. POOH with drift. 18:30 - 19:30 1.00 FISH P DECOMP RD SWS slickline. Spot SWS e-line unit. 19:30 - 19:45 0.25 FISH P DECOMP Hold PJSM with all hands to discuss rig up, cut,rig down procedures for chemical cutter. Discuss hazards associated with same. 19:45 - 20:30 0.75 FISH N DFAL DECOMP RU SWS equipment. 20:30 - 22:45 2.25 FISH N DFAL DECOMP RIH with 4-7/16" chemical cutter. Five tries to get through top of tbg fish. Bounce through sliding sleeve at 9670'. Log tie in ccl from 9780'. Cut tbg at 9753' Good shot indication. 22:45 - 00:00 1.25 FISH N DFAL DECOMP POOH with e-line. 4/30/2004 00:00 - 12:45 12.75 FISH N DFAL DECOMP Hold PJSM before getting off well. Remove cutter tools from well and remove from rig floor. Continue to RD SWS e-line unit. Left copper cutter head and lower steel centralizer for same in hole. This cannot pass through 4-1/2" tbg tail at 9807'. Will need to mill up or fish before fill clean out. 12:45 - 04:30 15.75 FISH N DFAL DECOMP MU grapple/overshot fishing BHA. 04:30 - 06:00 1.50 FISH P DECOMP Cut and slip drill line. 06:00 - 11 :30 5.50 FISH N DFAL DECOMP RIH with drillpipe and overshot BHA to recover tubing fish. 11 :30 - 11 :45 0.25 FISH N DFAL DECOMP Pick up the Kelly. 11 :45 - 12: 10 0.42 FISH N DFAL DECOMP Kick on pumps. Getting 230 psi at 2 bpm. Weight up=163 klbs, Weight down=135 klbs. Wash over tubing stub. Pump pressure up to 430 psi. good indication. PU slow, String + fish=180 klbs. PU slow to open jars. Pull to 225 klbs (45 klbs over) No movement. Slack off wlo cocking jars. PU to 225, SO. PU to 245 klbs. No movement. Cycle up to 250 klbs (70 klbs over) 6 times. No movement. Fish is not free. We do not have a chemical cut. 12:10 - 12:40 0.50 FISH N DFAL DECOMP Turn to the right to release overshot. Pumping at 100 psi, 1 bpm. Confirmed free of fish. 12:40 - 13:15 0.58 FISH N DFAL DECOMP Stand Kelly back. 13:15 - 13:45 0.50 BOPSUF N DFAL DECOMP Pressure test Kelly as part of BOP test perlormed yesterday. 13:45 - 20:00 6.25 FISH N DFAL DECOMP POOH with overshot BHA. P"nled 5/24,200-1 10 40 07 AM BP EXPLORATION Operations Summary Report Page 8488 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hours Task Code NPT Phase Description of Operations 4/30/2004 20:00 - 22:00 2.00 FISH N DFAL DECOMP Stand back drill collars. LD jars & overshot assembly. Redress overshot. 22:00 - 23: 15 1.25 FISH N DFAL DECOMP Spot Halliburton s-line unit. RU same. Hold PJSM regarding safety. communication, hazards of job. DIscuss fishing strategy. 23:15 - 00:00 0.75 FISH N DFAL DECOMP RIH with 4.125" LIB on 4.5" centralizers. 5/1/2004 00:00 - 12:15 12.25 FISH N DFAL DECOMP Continue to run lead impression block on chemical cutter fish. Unable to get into 5-1/2" tbg top with LIB. 12:15 - 02:30 14.25 FISH N DFAL DECOMP Change to 3.125" LIB with 4.5" centralizers. RIH. Bounce through top of tbg fish. Tag cutter fish at 9776' (top of PBR). POOH. Impression shows small neck split from curter head. Will fish 2.3" od profile just above cutter head with grapple overshot. 02:30 - 06:30 4.00 FISH N DFAL DECOMP RIH with overshot configured optimally to get onto fish. Can't get into top of tubing. POOH and reconfigure BHA. 06:30 - 09:45 3.25 FISH N DFAL DECOMP RIH with same overshot, BHA configured to make it smaller and lighter. Overshot baited with GS. Made it easily past top of 5-1/2" tubing. Made it down to fish. Got several small 30# friction bites on the fish, but could not get the overshot to grab. POOH to reconfigure tool string. Found copper marks inside lip of overshot, but nothing on the grapples. 09:45 - 11 :30 1.75 FISH N DFAL DECOMP Run same overshot on double bowspring centralizers. Could not make it inside the tubing stub. 11 :30 - 14:00 2.50 FISH N DFAL DECOMP Run 1.375" overshot on 1 bowspring centralizer. Made it down I to fish. Set down multiple times with no success. Set down and got a bite 3 times. Each time we jarred down to set the grapple. After setting the grapple, the first time pulled 50# over and lost it. Second time 50# over and lost fish. Third time pulled 100 # over and lost the fish. POOH. Found copper on first 3/4" of the teeth of the grapple. Note fish weighs about 50#. 14:00 - 15:45 1.75 FISH N DFAL DECOMP RU Baker overshot with 2.375" grapple. It's grapple has bigger teeth than the HES grapples. RIH. Set down at top of tubing. Can't get down after repeated attempts. POOH. 15:45 - 16:45 1.00 EVAL N DFAL DECOMP RU SWS eline unit to string shot and chemical cut tubing. 16:45 - 17:05 0.33 EV AL N DFAL DECOMP Safety meeting with rig crews and SWS eline crew re: explosives safety for shooting string shot. Hazards discussed and mitigated. Radio use is ok as these devices are RF safe. 17:05 - 17:10 0.08 EVAL N DFAL DECOMP Continue with SWS rig up. 17:10 - 18:30 1.33 EVAL N DFAL DECOMP RIH with Schlumberger string shot to prep tubing for chemical cutter. 18:30 - 19:00 0.50 EV AL N DFAL DECOMP Log tie in, tag cutter fish at 9776' (tbg talley depth). Fish is in top of PBR seal stem. PUH. Shoot string shot at 9752' to 9764'. CCl tie in showed a clear response at depth of first cut attempt. 19:00 - 19:45 0.75 EVAL N DFAl DECOMP POOH with string shot assy. 19:45 - 20:00 0.25 EVAL N DFAl DECOMP MU chemical cutter e-line tools. 20:00 - 20:45 0.75 EVAL N DFAL DECaMP RIH with chem cutter. 20:45 - 21 :00 0.25 EVAL N DFAL DECOMP Log ccl tie in log. Activate cutter at 9758'. Pull up hole. Hang up in sliding sleeve. Pull through. 21 :00 - 21 :30 0.50 EVAL N DFAL DECaMP POOH with cutting tool. All tools recovered. Cutter fired. 21 :30 - 22:15 0.75 EVAL N DFAL DECaMP RD SWS e-line equipment. 22: 15 - 00:00 1.75 EVAL P DECaMP MU overshot/grapple BHA with jars, accel, drill collars. P"nted 5'241200~ 10'4007 AM BP EXPLORATION Operations Summary Report Page 9 ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Sta rt: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hours Task Code NPT Phase Description of Operations 5/2/2004 00:00 - 05:30 5.50 FISH P DECOMP RIH with fishing BHA on 3-1/2" drill pipe. 05:30 - 06:00 0.50 FISH P DECOMP Kelly Up 06:00 - 06: 15 0.25 FISH P DECOMP Shut down for tour crew change. 06:15 - 08:00 1.75 FISH P DECOMP Check weight, and got 110 klbs down, 145 klbs up weight. Kick pumps on 350 psi at 2.9 bpm. Ease over fish. PP climbs, returns went to O. PU, begin jarring with no movement of fish. Does not look like a good chemical cut. or we are stuck on debris behind pipe. Jarred at 225 klbs for 3 licks. 250 klbs, 3 licks. 260 klbs. 3 licks. 270 klbs. 3 licks. 280 Ibs. 3 licks. 285 klbs, 1 lick. 280 klbs. 9 licks. Kick on pumps 1700 psi with no returns. Confirms either no cut, or packed off behind pipe. 280 klbs, 8 licks. Started getting returns. Pumping 2.2 bpm 1200 psi. Resume jarring while pumping 2 bpm. 280 klbs, 11 licks. Pumping 2.3 bpm, 930 psi. 280 klbs, 17 jar licks. Bring pumps to 4 bpm, 1800 psi. Pump 5 minutes. PU, got jar lick at 260 klbs, and fish started moving. PU hole 20' pulling heavy and packing off. Finally pulled free with PU weight at 163 klbs. Normal up weight was 145 klbs, expected fish weight 17 klbs, new up weight = 163 klbs. Looks like we have most of expected fish. 08:00 - 12:00 4.00 FISH P DECOMP Circulate bottoms up to fluff up any debris behind fish, and to circulate out any potential gas. We did get gas at 400 bbls returned, (back side volume almost 600 bbls). and took returns to tiger tank. Junked a total of 200 bbls of fluid. Take returns to the gas buster. Circulate an additional 200 bbls. Check for flow. Slight amount of flow, continue circulating to clean up the gas. Note able to circulate with full returns. 12:00 - 12:30 0.50 FISH P DECOMP Appears to be no flow. SD for NF check. 12:30 - 17:30 5.00 FISH P DECOMP Confirmed no flow. POH with drillpipe to recover fish. 17:30 - 18:00 0.50 FISH P DECOMP Safety stand down in ops cabin with Paul Hyatt, and the day tour rig crews. 18:00 - 19:15 1.25 FISH P DECOMP Continue safety stand down with night crews. 19:15 - 21:30 2.25 FISH P DECOMP POOH with fishing BHA. 21 :30 - 22:30 1.00 FISH P DECOMP Stand back drill collars. LD jars etc. 22:30 - 00:00 1.50 FISH P DECOMP LD 5-1/2" tbg fish. 5/3/2004 00:00 - 02:00 2.00 FISH P DECOMP Continue to lay down recovered 5-1/2" tbg & jewelry. (18.5 jts tbg, 4 glms w/ pups, sliding sleeve w/ pups). This leaves pup jt and +/- 20' of lowest full joint above PBR. Chemical cut looked very clean. Recovered cut joint length indicates that upper (first) chern cut was good. Exterior of tbg indicates fill up to and above GLM at 9468'. This would help explain overpull required to free tbg fish. 02:00 - 04:00 2.00 FISH N DFAL DECOMP MU overshot/grapple assembly BHA. 04:00 - 06:00 2.00 FISH N DFAL DECOMP RIH with 2 stands of drillpipe, then cut and slip drillpipe. 06:00 - 06:15 0.25 FISH N DFAL DECOMP Crew changeout. 06:20 - 07:30 1.17 FISH N DFAL DECOMP Continue cutting drilling line. 07:30 - 09:30 2.00 FISH N DFAL DECOMP It is 21.8' from collar to Chem Cut on recovered fish. It is possible that there is a 5' fish of 5-1/2" tubing still in hole. There is 4.5' of swallow on current fishing overshot. POH with BHA to re-configure to swallow longer fish. 09:30 - 11 :30 2.00 FISH N DFAL DECOMP Reconfigure BHA. PMted 5124.'2(,¡ú~ 1 0 ~O'07 AM BP EXPLORATION Operations Summary Report Page 10 ... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hours Task Code NPT Phase Description of Operations -- 5/3/2004 11 :30 - 12:30 1.00 FISH N WAIT DECOMP Fishing hand cross threaded one connection on 8-1/8" extension barrels. Wait for him to run back to Deadhorse shop to retrieve new ones. 12:30 - 13:30 1.00 FISH N HMAN DECOMP Change out 2 damaged extension barrels. 13:30 - 21 :00 7.50 FISH N HMAN DECOMP TIH with drill collars and dril pipe to recover fish. 21 :00 - 23:00 2.00 FISH N DFAL DECOMP Tag fill/fish 2 jts early. MU kelly. 23:00 - 00:00 1.00 FISH N DFAL DECOMP PU another single. Wash in 15' increments. Circ sweeps with each bite. 5/4/2004 00:00 - 00:30 0.50 FISH N DFAL DECOMP Continue to wash fill. Circ 40 bbl hi vis sweep evey 15'. Not much for solids back over shaker with sweep btms up. Does not appear to be sand, more like schmoo. Blinding off shaker. Over pulls at 9682'. Difficult to wash. Concerned about guide shoe assy. This is the wrong BHA for this much washing. 00:30 - 01 :30 1.00 FISH N DFAL DECOMP Circulate btms up. Get sweep back, but not much solids. 01 :30 - 02:00 0.50 FISH N DFAL DECOMP Stand back kelly. 02:00 - 06:00 4.00 FISH N DFAL DECOMP POOH with overshot BHA to PU washpipe BHA. 06:00 - 06:30 0.50 FISH N DFAL DECOMP SD for crew change. 06:30 - 10:50 4.33 FISH N DFAL DECOMP Continue POOH with drillpipe. 10:50 - 18:00 7.17 FISH N DFAL DECOMP Stand back collars, layout jars, and lay down overshot. MU BHA #8. 18:00 - 20:00 2.00 FISH N DFAL DECOMP RIH with 3-1/2" DP BHA len = 621.41 ft Slow trip due to fluid coming up the DP with wash pipe on bottom of BHA (open ended). Hole staying full due to fish (chemical cutter) in tubing 20:00 - 21 :00 1.00 FISH N RREP DECOMP Replace hose on spinner tongs (worn hose and questionable crimp) 21 :00 - 00:00 3.00 FISH N DFAL DECOMP Resume TIH w/ 3-1/2 DP 5/5/2004 00:00 - 05:00 5.00 FISH N DFAL DECOMP Continue TIH /w 3-1/2 DP. MU kelly w/ bottom of washpipe at 9608' 05:00 - 07:00 2.00 FISH N DFAL DECOMP Break circ and pump 150+ bbl staging up the rate in 1 bbl increments (3.0/350. 6.0/1290) to break up fill. PVT 363-lost 3 bbls while circ Pumped 530 bbl total 07:00 - 10:35 3.58 FISH N DFAL DECOMP PUH recored string wt, Closed annular and set P at 500 psi, confirmed IA gauge is operative.Set Pp kick out at 800 psi. Rev cir at 3 bpm at 381 psi AV up DP at 450 f/min. Moving DP continously while rev circulating at 3.5 bpm Inc Op to 4.00 bpm IA p = 730 pSI Vp = 655 bbl. fluid back was clean Bio water SD and cir conventional at 6 bpm Pp = 488 psi 10:35 - 12:00 1.42 FISH N DFAL DECOMP W/R 9609 ft to 9648 ft, clean at 6.3 bpm. Pp 498 psi Connection. WR 9648 ft to 9703 ft. Tagged with torque at 9703 ft. WR 9703 ft to 9710 ft @ 6.7 bpm Pp = 920 psi (AV @ 100 ft/min) and 60 rpm Worked kelly 40 ft, WR area twice. PUH to 9667 ft to rev cir. 12:00 - 13:20 1.33 FISH N DFAL DECOMP Rev cir at 9667 ft at 4 bpm, 580 psi. Mixing Biozan pill in pits. Vp = 255 bbl, shaker cleaned up. Called for Geo from Nabor's 9ES to describe samples. Make connection 13:20 - 13:35 0.25 FISH N DFAL DECOMP W/R 9710 ft to 9712 ft and stalled RT. PUH and restarted W/R 9710 ft to 9725'. at 6.7 bpm Pp = 980 psi. Set Pumps triips at 2000 psi. While washing, lost electrical power to shaker. By passed shaker and PUH, 13:35 - 14:45 1.17 FISH N RREP DECOMP Circulate and worked drill string at 4 bpm while working on shaker Electrical problem. 14:45 - 15:15 0.50 FISH N DFAL DECOMP W/R from 9712 ft using 6.8 bpm at 923 psi. Having to rotate Punted' 5124120001 10010 07 AM BP EXPLORATION Operations Summary Report Page 11 ... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hours Task Code NPT Phase Description of Operations 5/5/2004 14:45-15:15 0.50 FISH N DFAL DECOMP through 1111 at 60 rpm At 9715 tt, WR became easier, The problem area in the 9-5/8" could be 9715 ft Not much fill below 9715 ft. W/R down to 9742 ft. at 6.8 bpm and 900 pSI Pp. Worked siring tWice and sWitch to rev circulating. Tarra 9ES Geologist finding: 15°0 CaC03 and 85~0 sand and shale. No fluid lost Contacted Wells group and no Irac sand has been pumped down IA. just flo-pro and CaC03 115:15 - 16:41 1.43 FISH N DFAL DECOMP Rev Cir at 5.00 bpm /773 psi. Pump trips set at 900 psi. Work DP perodically Recovering lots of sand/shale over shaker i.e. at times shaker is covered, patties 16:41 - 17:10 0.48 FISH N DFAL DECOMP Make Connect at 9742 ft Pumped 43 bbl HV sweep, WR 9742 ft and tagged the top of the fish at 9753 ft. PUH. clean. RIH and washed over WO rotary. 17:10 - 18:09 0.98 FISH N DFAL DECOMP Washing over fish. Q = 7.2 bpm at 1041 psi. Wash over fish to 9765 ft. Tagged hard. Inc rotary to 65 rpm, Torque 300 amps = 8000 ft-Ibs Using 5k WOB at 9765 ft. probably the 5-1/2" casing collar above the PBR No fluid loss that this time 18:09 - 19:45 1.60 FISH N DFAL DECOMP Continue to wash over fish at 9766 ft, Q= 6.3 bpm Pp = 890 psi. Rotary at 65 rpm WO shoe at 5k 19:45 - 21 :00 1.25 FISH N DFAL DECOMP Wash to 9769' and progress is slowing and torque increasing from 6k to 10k ft-Ibs 6.3/900/60 rpm/3k wob/350 amps. PU 175k, clean. A few solids over shaker. Assume either on 5-1/2" collar at top of 3.11' pup or more likely working over locator at top of 15.67' PBR 21 :00 - 22:00 1.00 FISH N DFAL DECOMP Wash to 9770' 6.3/900/62 rpm/5k wob/350 amps PU, clean. Ream to btm. clean. Have good 4 ppb biozan system (YP 25) and full returns 22:00 - 22:45 0.75 FISH N DFAL DECOMP Washed to 9774' at kelly down 6.3/970/64 rpm/2k wob/350 amps and penetration rate has picked up. PU, clean 175k, ream to TD, clean. Make connection. Slipped out of top of fish and set down at 9743' several times. Work over TOF on first try and wash down to 9774', clean 22:45 - 23: 15 0.50 FISH N DFAL DECOMP Continue washing from 9774' 5.0/790/60 rpm/1-3k wob/300 amps to 9782.79' easily and progress stopped. Based on TOF at 9743', this confirms that this is the top of packer (K anchor). PUH and intentionally pull above 9743'. RBIH and set down 15k at 9743' 23: 15 - 23:30 0.25 FISH N DFAL DECOMP Discuss and reconfirm that plan is to mill up packer 23:30 - 23:45 0.25 FISH N DFAL DECOMP Work over top of fish and wash to bottom, clean 23:45 - 00:00 0.25 FISH N DFAL DECOMP Mill packer from 9783' 5.0/800/60 rpm/1-3k wob/300 amps 5/6/2004 00:00 - 06:00 6.00 FISH N DFAL DECOMP Mill out packer from 9783' 5.0/800/60 rpm/5-10k WOB/300 amps. Pump 74 bbl hi vis sweep in anticipation of future losses PVT 458 Mill to 9786' by 0600 PVT 458 06:00 - 07:55 1.92 FISH N DFAL DECOMP Milling Slips and rubber element to 9788.29 ft Vp = 487 bbl, no fluid loss at this time. Q = 4 bpm Pp = 630 psi Packer fell down to 9793 ft Milled packer at 9793' PU, pulled tigh due to rubber along side of wash pipe. Pumped 40 bbl sweep (150k LSRV) 07:55 - 09:05 1.17 FISH N DFAL DECOMP Milled Packer to 9794 tt and lost all weight on mill. Packer fell Pr,rlled 5/24/20ü4 10'40:07 AM Page 12'- BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 5/6/2004 07:55 - 09:05 1.17 FISH N DFAL DECOMP 09:05 - 09:57 0.87 FISH N DFAL DECaMP 09:57 - 10:15 0.30 FISH N DFAL DECaMP 10:15 - 10:41 0.43 FISH N DFAL DECaMP 10:41 - 12:00 1.32 FISH N DFAL DECaMP 12:00 - 19:00 7.00 FISH N DFAL DECOMP 19:00 - 21 :00 2.00 FISH N DFAL DECaMP 21 :00 - 23:00 2.00 FISH N DFAL DECaMP 23:00 - 23:30 0.50 BOPSUF P DECaMP 23:30 - 00:00 0.50 BOPSUF P DECaMP 5/7/2004 00:00 - 04:00 4.00 BOPSUF P DECaMP 04:00 - 04:45 0.75 BOPSUF P DECaMP 04:45 - 06:45 2.00 FISH N SFAL DECOMP 06:45 - 07:30 0.75 FISH N DFAL DECaMP 07:30 - 08:00 0.50 FISH N DFAL DECOMP 08:00 - 11 :15 3.25 FISH N DFAL DECOMP 11: 15 - 11 :30 0.25 FISH N DFAL DECaMP 11:30-17:15 5.75 FISH N DFAL DECaMP 17:15 - 18:45 1.50 FISH N DFAL DECaMP 18:45 - 19:45 1.00 FISH N DFAL DECaMP 19:45-20:15 20: 15 - 22:45 0.50 BOPSUP N 2.50 FISH N DFAL DECaMP DFAL DECaMP Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Description of Operations down. RIH to 9803 ft clean. Lossing 1 bpm cir at 9793 ft. PUH and wash 9777 ft to 9803 ft. clean PUH wt = 177k, slack off at 140k circulating wo rotating. LD 1 single 145 std in hole. Tried to rev cir. losses increased. SD after lossing 30 bbl (Qp = 4 bpm at 545 psi) without proper returns. SWitch around and started clr long way at 6 bpm. Cir and work string, (Q= 5.8 bpm at 853 psi). Notified Jeff Jones w/ AOGCC about uncoming BOP test and he wavered witnessing. Vol p = 280 bbl Pumped 50 bbl 150k LSRV pill down DP. Chased and left on top of fish Vpump = 370 bbl SD pumps, set Kelly back. and make ready to POOH. LD a single. 144X in the hole POOH with 5 stands. Gained 1 bbl in trip tank, Install floor valve and HP hose. Break cir, took 30 bbl to fill hole. Fluid not dropping out of DP. Circulated 20k LSRV down DP. POOH w/ DP LD jars/stand back DC's. Hole taking 20 bph static. BOLDS LD junk baskets and washover BHA. Good metal recovered considering minimal milling occurred. No abnormal scars on washpipe. Shoe showed normal wear for the job. Clear floorll,9ad Qut fishing tools Pul,l-wear ring. Fill hole. Set test plug W,èekly BOPE test. AOGCC waived witness Finish BOPE test Pull test plug. Well on vac. Took 25 bbls to fill. Set wear nng. RILDS Replace air boots on riser Rig Services PJSM on Handling BOT OverShot BHA PU BHA #9 Install air slips, wiper rubber RIH with 3-1/2" DP with 146 std (286 jts). D= 9723 ft. Estimated TOF at 9767 ft or 10031 ft Installed floor valve and circulate well. Qp = 3 bpm at 525 psi. Increased to 4 bpm after 30 minutes Vol dp = 63 bbl-Vol ann = 590 bbls Lost 9 bbls in 1.5 hrs at 4.0/740 Incr rate 6.0/980 PVT 300 Returns look like crude. but weigh 8.4+. Assume mung/schmoo has been scraped off 9-5/8" on trips and has gone into solution. Vac 150 bbls of the worst from pits and replace w/ fresh 2# bio. Fin CBU and lost 6 bbls last hour at 6 bpm Service and PT kelly/upper kelly cock 250/3500 PU kelly and mousehole single 182k up, 150k dn. Start pump 0.7/330. Begin washing down picking up singles looking for top of 5-1/2" tbg fish. 5k wt loss at 9767' w/ 10k overpull, but no pressure incr. Continue washing in hole picking up singles w/ no wt losses. Top of fish should be at 10032' if PBD is 10091'. Set down at 10049.7' DPM which if fish is swallowed would have top of fish at 10036'. Rotate to be sure that we are over fish and had sli incr in torque (assume fish is spinning). Stack 25k, but no pressure increase. Best we can do wo getting P"nted' 5l24/2û04 10 40 07 AM Page 13- BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 517/2004 5/8/2004 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase 20: 15 - 22:45 2.50 FISH N DFAL DECOMP 22:45 - 23:00 0.25 FISH N DFAL DECOMP 23:00 - 23:10 0.17 FISH P DECOMP 23: 1 0 - 23:30 0.33 FISH N DFAL DECOMP 23:30 - 00:00 0.50 FISH N DFAL DECOMP 00:00 - 05:00 5.00 FISH N DFAL DECOMP 05:00 - 07:45 2.75 FISH N DFAL DECOMP 07:45 - 09:30 09:30 - 11 :00 11 :00 - 16:45 16:45 - 17:45 1.75 FISH 1.50 FISH 5.75 FISH 1.00 FISH DFAL DECOMP DFAL DECOMP DFAL DECOMP DFAL DECOMP N N N N 17:45 - 18:45 1.00 FISH N DFAL DECOMP 18:45 - 19:45 1.00 FISH P DECOMP 19:45 - 00:00 4.25 FISH N DFAL DECOMP 5/9/2004 00:00 - 00:45 0.75 FISH N DFAL DECOMP 00:45 - 02:00 1.25 FISH N DFAL DECOMP 02:00 - 02:30 0.50 FISH N DFAL DECOMP 02:30 - 03:00 0.50 CLEAN P DECOMP 03:00 - 03:50 0.83 CLEAN P DECOMP 03:50 - 05:15 1.42 CLEAN P DECOMP 05:15 - 06:00 0.75 CLEAN P DECOMP 06:00 - 08:00 2.00 CLEAN P DECOMP 08:00 - 13:00 5.00 CLEAN P DECOMP 13:00 - 13:15 0.25 CLEAN P DECOMP 13:15 - 14:15 1.00 CLEAN P DECOMP 14:15 - 17:45 3.50 CLEAN P DECOMP Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Description of Operations rough and may only have the 5' stub Set back kelly Safety mtg re: POOH Install air slips/DP wiper PVT 381 POOH standing back 151 stds 3-1/2 DP (wet)-no overpulls Continue TOH w/3-1/2 DP. Losing 10 bph over hole fill LD jars/standback DC's. Recovered some fish LD 5 ft cut jt. 3 ft PJ. 15 ft PJ. PBR and K Latch. Length recovered = 41.83 ft Length of fish to recover = 18.51 ft Estimated top of fish at 10073 ft SLM, Bottom of fish at 10092' SLM. Filled hole 11 bbl, The fish and chemical cutter is plugging off some of the losses at this time. Clean floor and service break out OS MU Spear BHA RIH with 4-3/4" DC RIH 151X stds 3-1/2" DP + BHA to 10065.59 ft SLM PU kelly broke circulation, noted up/dwn wts 188/155k RIH, tagged with spear at 10080ft, with 20 ft kelly in. Pp inc. from 390 psi and jumped to 900 psi, PU and pulled to 210k (22k over) Pp fell off to 380 psi. OK. PU and reset spear 5 times Everytime, the TOF was deeper PUH and the btm fish act like it was @ 10,120 ft Set back kelly. RU to POH. LD single. POH w/ 5 stds (wet) and sli dragging up to 4k PJSM. Service rig. Drop p~s bar and open sub w/ 2400 psi. Mix and pump 30 bbl slug Resume TOH (dry) w/ no overpulls PVT 318 Fin POOH w/151 stds 3-112 DP. Losing 4 bph over hole fill LD jars/standback DC's BOLDS LD complete fish. Recovered packer. 5-1/2" tbg pup. XO and 3' of 4-112" tailpipe with chemical cutter sitting in XO. The tailpipe was flared outward on bottom (looks like an ugly jet cut that was not complete and tailpipe broke off at some later date) PJSM. Load out misc fishing tool. Load in casing scraper tools. Clear floor MU casing scraper BHA RILDS MU DC's RIH w/3-1/2 DP to 1180 ft CDL(56') Removed the SLB Chemical Cutter from BHA. The Severing head was parted RIH with 3-1/2" DP and CS BHA NORM inspect all remaining tubulars Crew change RIH with 151 stad 3-1/2" DP Wt check at 10022 ft = 166k up and 137k down PU kell and make up in mouse hole. Break circulation at 6.5 bpm at 800 psi. W /R 10053' to 10093 ft at 6.5 bpm using 2ppb Bio(dirty) Made connection and W/R 10093 ft to 10098 ft. Torque stalled at 400 amp. PUH, clean, W/R back and tagged again at 10,098 ft with low mill weight. W/R the third time and tagged again at PnnlGd. 5'2..I.'200J 10 JO 07 JI.M Page 14'" BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 5/9/2004 14:15 - 17:45 3.50 CLEAN P DECOMP 17:45 - 20:30 2.75 CLEAN P DECOMP 20:30 - 21 :00 0.50 CLEAN P 21:00 - 21:15 0.25 CLEAN P 21:15 - 00:00 2.75 CLEAN P 5/10/2004 00:00 - 02:00 2.00 CLEAN P 02:00 - 02: 15 0.25 CLEAN P 02:15 - 07:15 5.00 CLEAN P 07: 15 - 07:30 0.25 CLEAN P 07:30 - 08: 15 0.75 CLEAN P 08: 15 - 08:50 0.58 CLEAN P 08:50 - 11 :30 2.67 CLEAN P 11:30-12:15 0.75 CLEAN P 12:15 - 17:30 5.25 CLEAN P 17:30 - 19:00 1.50 CLEAN P 19:00 - 20:00 1.00 CLEAN P 20:00 - 21 :30 1.50 CLEAN P 5/11/2004 21 :30 - 00:00 00:00 - 04:45 04:45 - 05:45 05:45 - 09:00 09:00 - 09:05 09:05 - 09:30 09:30 - 19:30 2.50 CLEAN P 4.75 CLEAN P 1.00 CLEAN P 3.25 CLEAN P O.OS CLEAN P 0.42 RUNCOtvP 10.00 RUNCOtvP 19:30 - 19:50 0.33 RUNCOrvP 5/12/2004 19:50 - 00:00 00:00 - 02:45 02:45 - 03:00 4.17 RUNCOtvP 2.75 RUNCOtvP 0.25 RUNCOM\J DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP COMP COMP COMP COMP COMP COMP Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Description of Operations 10098' RT stalled at 400 amps. PUH and pulled tight Set Jars off 220k at 10053 It. Worked free. LD single. PUH and pulling tight every 9-5/S" casing collar. LD 3 singles to 99611t Working kelly between 9961 tt to 9992 tt while Qp = 6.6 bpm Pp = 800 psi w/ clean movement. Pump 330 bbl 01 clean 2# Bio water down DP at 6.7 bpm and 890 psi. Followed with fresh 1 ~"o KCI 6.6/1715 until returns were clean Red rate to 4.0/840 while fin vac off munglschmoo bio water from pits. Fill trip tank. Prep to clean pits. Nearly full returns Safety mtg re: TOH/confined space Set back kelly. TOH wI DP. No overpulls Clean pits Continue TOH wI 3-1/2 DP. Stoodback 150 doubles. LD single wI bad pin. Losing 3.5 bph over hole fill Safety mtg re: LD DC's/BHA LD 16 DC's, junk baskets, casing scraper and mill. JB's had a couple small pieces of control lines and a couple mise steel pieces. Load out BOT tools. DC and clear floor. Pull wear ring PJSM re: PU RTTS with Halliburton Service hand PU 9-5/8" RTTS with Cir Valve and XO. BHA Len = 10.88 ft PU 11 jts DP out of Pipe Shed RIH with stands out of derrick Averaging 3 min per stand due well taking fluid at higer tripping rates Loaded pipe shed with Nabors Tongs while crane was on location. Took lunch RIH with stands out of derrick. Averaging 2.5 to 3 min per stand NU floor valve and cir hose. Install kill line on IA valve in cellar. Work RTTS while cir at 2 bpm. Crew change PT kill line against IA valve. Set RTTS @ 9781'. Close VBRs. PT 9-5/8" casing to 3500 psi for 30 min wI 7.2 bbls KCI. Lost 40 psi. Bleed off press. PJSM. Release RTTS. RD circ head. NU kill line to BOP's and PT POOH LDDP Continue POOH LDDP losing 3 bph over hole fill Break down kelly Finish LD DP LD RRTS intact wI rubber element Clean pipe shed and make ready to bring in 4-1/2" tubing Loading in 4-1/2" 12.6#/ft 13CrSO, remove protector, drift and tally Will load pipe shed with 235 its PJSM and review hazards, procedures and running order for the 4 1/2" 13Cr completion string. P/U and run 55 jts of 227 jts 4 1/2" completion string. Continue running 4-1/2". Galled jt #82. UD jt #82. Rolled jt from pipe skate back onto pipe rack using the hydraulic skate arms. In doing so the joint moved the wood stripping and fell in between joints on the lower row. Using the pipe handler hooks raised one end of the joint and replaced the wood stripping under it. While placing another wood strip under the other end of the joint the person placing the stnpping pinched his right index finger between the stripping and the Printed' 5/24/200.1 1 0 .10 07 AM BP EXPLORATION Operations Summary Report Page 15" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hours Task Code NPT Phase Description of Operations 5/12/2004 02:45 - 03:00 0.25 RUNCOtvN COMP lomts under It. Reported injury to toolpusher and both went to the Deadhorse Clmic to have the finger looked at. 03:00 - 04:00 1.00 RUNCOtvN COMP Reviewed the details leading up to the injury with ng crews. Although procedures were basically sound for handling the damaged joint during it's removal from the pipe shed a safer way was dicussed. Any further galled joints will be removed from the pipe shed utilizing the metal stripping that can be pinned in place with no possibility of movement. 04:00 - 06:00 2.00 RUNCOrvP COMP Continue running 4-1/2" completion string. Injured crew member returned from medic. Injury did NOT require stitches and is considered only as a First Aid. Crew member returned to work after told of new procedures to follow if additional joints needed to be layed out. 06:00 - 06:20 0.33 RUNCOrvP COMP At jt 108. Safety mtg re: reviewed first aid case and procedure for handling same wi new crews-added. 'will also use chain hoist to lift' 06:20 - 15:00 8.67 RUNCOtvP COMP Resume running 4-1/2" tubing 15:00 - 16:30 1.50 RUNCOtv1P COMP MU Gray Gen II hanger on last full joint. BOLDS. Land hanger wi 1 it 3-1/2 DP at 26' KB with WLEG at 9830'/packer at 9741'. Up 123k. dn 105k Had a little trouble hanging up in stack. RILDS. PT hanger seals thru test port at 5000 psi-good. 16:30 - 17:15 0.75 RUNCOrvP COMP RU kill line to INreturn hose to landing jt. Begin fill pits wi fresh 10 a KCI 17:15 - 19:00 1.75 RUNCOM\J WAIT COMP WO vac trucks to displace. Round tripping first KCI truck. waiting on empty's for returns and one for crude. Mix 400 blls 1% KCL with 25g/100bbl of Corexit corrison inhib. Mix up 50 bbl high-vis pill. 19:00 - 19:20 0.33 RUNCOrvP COMP Test reverse lines to 3700psi. 19:20 - 00:00 4.67 RUNCOrvP COMP Reverse circulate at 3/bpm, 50 bbl KCL, 50 bbls high-vis KCL, 300 bbls KCL, 400 bbls corroSion inhibited KCL 5/13/2004 00:00 - 03:00 3.00 RUNCOrvP COMP Continue reverse circ corrosion inhibiter and 130 bbls of Dead Crude freeze protect. 03:00 - 03:30 0.50 RUNCOrvP COMP Bleed off OA which had pressured up from heat expansion of reversed fluids. 03:30 - 05:20 1.83 RUNCOtvP COMP Pressure up tubing to 3500psi and hold for 30 mln to inflate BOT packer..bleed-off to 1500psi. .swap to IA and pressure up to 3500psi and hold for 30 min.. All pressures held good and were charted. Bleed down IA and tbg. 05:20 - 06:00 0.67 RUNCOrvP COMP Back out 3-1/2" DP landing jt. R/U to set BPV. Fill hole 06:00 - 07: 1 0 1.17 RUNCOrvP COMP RU DSM lubricator (can't dry stick this BPV) and set 6" Gray BPV 07:10 - 07:30 0.33 RUNCOrvP COMP Rig evacuation drill-discuss 07:30 - 12:30 5.00 RUNCOtvP COMP ND 13-5/8" BOPE and load out in 3 pieces plus riser 12:30 - 17:15 4.75 RUNCOrvP COMP Set dart in Gray BPV. NU reconditioned 6" CIW tree wI adaptor flange. PT adaptor flange at 5000 psi for 30 min-good. PT tree wi 5000 psi and found 4 leaks. Fixed three 17:15 - 19:10 1.92 RUNCOM\J SFAL COMP WO DSM valve crew to fix leak 19:10-21:10 2.00 RUNCOrvN SFAL COMP Fixing leaks on tree's master and wing valve stems. Test tree to 5000psi. Same time replacing several mud tank equalizing valves and valve seals. 21 :10 - 00:00 2.83 BOPSUF P WEXIT NU 7-1/16" 5K BOP stack, killlchoke lines and hyd. control lines. Pnnted. 5/24'2,)(14 10'4007 AM Page 1648 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 5/14/2004 4.00 BOPSUP P 5 50 BOPSUP P WEXIT WEXIT 00:00 - 04:00 04:00 - 09:30 09:30 - 10: 15 0.75 BOPSUF P WEXIT 10:15-10:30 0.25 CLEAN P WEXIT 10:30 - 12:00 1.50 CLEAN P WEXIT 12:00 - 13:30 1.50 CLEAN P WEXIT 13:30 - 15:15 1 .75 CLEAN P WEXIT 15:15-17:00, 1.75 ZONISO P WEXIT 17:00 - 23:00 6.00 ZONISO P WEXIT 23:00 - 00:00 1.00 RIGU P WEXIT 5/15/2004 00:00-01:10 1.17 RIGU P WEXIT 01 : 1 0 - 01:45 0.58 RIGU N SFAL WEXIT 01 :45 - 02:00 0.25 RIGU N WEXIT 02:00 - 03:10 1.17 RIGU P WEXIT 03: 1 0 - 04:20 1.17 RIGU P WEXIT 04:20 - 04:45 0.42 RIGU P WEXIT 04:45 - 07:00 2.25 STWHIP P WEXIT 07:00 - 07: 15 0.25 STWHIP P WEXIT 07: 15 - 07:30 0.25 STWHIP P WEXIT 07:30 - 07:50 0.33 STWHIP P WEXIT 07:50 - 08: 1 0 0.33 STWHIP P WEXIT 08: 1 0 - 08:30 0.33 STWHIP P WEXIT 08:30 - 09:00 0.50 STWHIP P WEXIT 09:00 . 09:45 0.75 STWHIP P WEXIT 09:45 - 10:05 0.33 STWHIP P WEXIT Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Description of Operations Finish NU 7-1116" BOP stack. Test BOP stack and choke manifold valves. Check N2 bottle precharges, perform acummulator function test. AOGCC rep. John Crisp waived witnessing test. Blind/shear rams leaked. Replace seals (3/4 hr) RU DSM. Dry stick dart. Pull BPV wi lub. RDMO DSM Safety mtg re: RU slickline RU SWS slickline unit and bring tools to floor Fill hole wi 7 bbls RIH w/ 2" RB to 9763' WLM and pull ball and rod RIH w/4-1/2" GS to 9766" WLM and pull RHC plug RIH 3.80" TS wi SWS memory GR/CCL at 100'/min by SWS recommendation. Started losing wt and setting down at 3760'. Get to 3900'+ and give up. Could be shear stock from prior run impeeding progress of drift. POOH (at 100'/min) to put on smaller drift RIH w/ 3.25" TS wi SWS memory GR/CCL at 1 OO'/min to PBD tagged at 10097'. Log fom PBTD back to 9500'. POH. RD slickliners. Install gooseneck and pack-off to Injector. Rig-up to stab injecter with e-free coil. Finish installing gooseneck and pack-off assembly on injector. R/U internal grapple to EOP of coil. Pull coil into injector. Unable to back-oH reellension enough to allow winch lo pull coil off reel. Call out SLB mechanic. Wait on mechanic. Back-off adjustment to reel tension. Continue to stab coil into injeclor. Dress end and install dimple CTC Pump dart coil vol = 53.7 bbls. Continue to flush coil. PT CTC, inner reel valve to 4000 psi. P/U ball/drop cementing nozzle and 5' stinger. (6.50') RIH 10000' 40.3k, 24k. RIH and tag at 0.4/100 at 10104' E counler, 10120' Mech counter PUH to 9800' thru EOT, clean Park at 9950' 0.5/80. Injectivlty test 0.5/200 w/ 5 bbls, bled to zero in one minute. Circ 0.5/.0.3/60, 1.0/0.8/290, 1.5/1.25/650, 2.0/1.811200 while MU RU DS cementers Circ 0.55/0.35nO Safety mtg re: mix and pump cement RIH and retag at OAnO at 10104'. corr to 10080'. PUH and park at 9950'. Flag CT Circ while wo cementers to fin batch up. Cmt to wiat1)"900 hrs PT DS @ 3500 psi. Pump 5 bbls FW. Load Çf"~/ 17 bbls G -- .-- cement at 17.0 ppg 1.3/1.0/470. Displace w/6 bbls FW. 15 bbls KCL. 30 bbls biozan, then KCI2.0/1.7/1120. RIH 28k to 10078', PUH 50k. RIH Park at 10078' five bbls before cmt exited nozzle. Red rate to 1.5/1.4/230 with cement at nozzle. Wait until 4 bbls returned then PUH 44k at 10'/min 1.5/1.35/200. After 7 bbls out. returns declined to 1.0 bpm. red pulling speed to 5'/min. Returns declined to 0.8 bpm temporarily, then caught fluid at 10038' P"nl",1j 5/20.1/200.1 1 0 40'07 AM BP EXPLORATION Operations Summary Report Page 17811 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hours Task Code NPT Phase Description of Operations 5/15/2004 09:45 - 10:05 0.33 STWHIP P WEXIT and returns Increased to 1.3 bpm. Continue PUH 43k 10'/mm 1.5/1.3/430. With 1.5 bbls left, increase PUH speed to max. Red rate to 0.5 bpm at last bbl out at 9950'. PlF to safety 10:05 - 10:45 0.67 STWHIP P WEXIT Park at 9500' circ 0.3/0.3/120 (full returns) while WOC to settle x set TT 3:50 10:45 - 11 :30 0.75 STWHIP P WEXIT Close choke and pressure up to 200 pSI and bled to 110 psi in 10 min. Pressure up to 300 psi and bled to 200 psi in 5 min. Pressure up to 400 psi and bled to 200 psi in 7 min. Retest at 400 psi while SI @ pump. Bled to 300 psi in 5 min. Bleed off pressure. No change to IA thru out 11 :30 - 12:00 0.50 STWHIP P WEXIT RIH from 9500' 0.5/200 w/ full returns and fin circ biozan to nozzle. Dilute any remaining cement wI biozan at 2.0/2.0/900 at 15ïmin from 9875' to 9970' (100' above planned KOP). PUH 2.0/1200 20'/min chasing diluted cement into tubing. Start KCI w/lubetex 2.0/1340 while RIH to 9930'. POH to EOT 40k 12:00 - 14:30 2.50 STWHIP P WEXIT POH jetting jewelry 2.8/1950 and displacing wellbore fluids to KCI wI LT. Got up to 10.3 ppg cement back for 20 bbls, then cleaned up after dumping 80 bbls. FP CT w/ MeOH while POOH. Jet stack w/ the last of it 14:30 - 15:00 0.50 STWHIP P WEXIT lD cementing BHA. Cut off CTC. Install internal grapple 15:00 - 16:00 1.00 STWHIP P WEXIT PJSM. Pull CT back to reel and secure. Prep reel for removal 16:00 - 17:30 1.50 STWHIP P WEXIT PJSM. load out used e-free reel. load in used e-CT reel 17:30 - 18:30 1.00 STWHIP P WEXIT Install reel in bushings. hook up hardline. Install internal grapple to coil. 18:30 - 19:20 0.83 STWHIP P WEXIT PJSM and stab pipe to injector. 19:20-20:10 0.83 STWHIP P WEXIT Cut 500' of coil. 20:10 - 21:00 0.83 STWHIP P WEXIT UD tubing cutter. Install temp CTC. Epoxy and shrink wrap E-line for slack mgmt. 21 :00 - 21 :20 0.33 STWHIP P WEXIT Start pumping down coil 1.3bpm to warm it up. 21 :20 - 22:00 0.67 STWHIP N SFAl WEXIT Stop pumping to re-repair another mud manifold valve. (This would be a great summer shutdown project. Cut-off entire manifold just above the rig floor and replace) 22:00 - 22:25 0.42 STWHIP P WEXIT Continue pumping 1 coil volume of warm KCL. 22:25 - 23:35 1.17 STWHIP P WEXIT Stab injector on well. Swab valve closed. Through Kill line reverse at 3.4bpm. RU cutter. Cut back 37' found e-line. RD cutter. Install dimple connector. Pull test to 35k. 23:35 - 00:00 0.42 STWHIP P WEXIT Install BHI Upper Quick Connect 5/16/2004 00:00 . 02:30 2.50 STWHIP P WEXIT Continue make-up of BHi upper quick connect. PT to 3500 psi. 02:30 - 03: 1 0 0.67 STWHIP P WEXIT P/U BHA #13 for milling cement ramp (65.70') surface test tools - ok 03: 1 0 - 04:45 1.58 STWHIP P WEXIT RIH to 9075'. 04:45 - 06:25 1.67 STWHIP P WEXIT log tie-in at HRZ. Missed it PUH to 9055'. Carr -20' to GR. log CCl. RIH w/o pump 06:25 - 07:00 0.58 STWHIP P WEXIT Tag hard cement at 9984'. PUH to 9900'. PT cement to 2000 psi for 15 min and lost 50 psi. Correlate BHI CCl to SWS CCL dated 5/14/04-add 4.0'. Bleed off pressure 07:00 - 08:00 1.00 STWHIP P WEXIT RIH 0.4/220 and tag at 9988'. PUH 39k. Start motor 2.6/2220. RIH and first motor work at 9988'. Begin drilling LS ramp in firm cement 30-40'/hr 2.6/2220/178R w/ 200-300 psi diff for 8'. Penetration rate increased to 45-50'/hr wI 140 psi diff 3k wob to 10014'. Drill cement 10014'-027' 40-45'/hr w/ 300 psi diff 3.4k wob 08:00 - 08:35 0.58 STWHIP P WEXIT 10027' 'Out' MM partially plugged. Chk FS 2.6/2180. Drill P',nrE-cI 5'24120(¡4 1040.07 AM BP EXPLORATION Operations Summary Report Page 18- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/21/2004 Date From - To Hou rs Task Code NPT Phase Description of Operations 5/16/2004 08:00 - 08:35 0.58 STWHIP P WEXIT firmer cement from 10027' 40'/hr 2.6/2180/1 75R/250 psi diH/3.5k wob. Drill to 10050'. All cement drilling has been consistent (no pockets) 08:35 - 09:20 0.751 STWHIP P WEXIT Wiper back to 9650' 39k 2.6/2150. Relog CCl before turning TF to HS. No correction. RBIH Note: ElMD EOT = 9824' vs 9830' DPM 09:20 - 09:40 0.33 STWHIP P WEXIT Resume drilling w/ lS TF to planned HS pOint at 10056' 2.64/221 0/175R/300 psi diHl2.8k wob at 25-35'/hr and let it drill off 09:40 - 10:05 0 42 STWHIP P WEXIT Orient to HS. Drill 2.65/2250/1 U250 psi dlff/3.7k wob 25-30'/hr from 10056' to 10068'. No obvious signs of casing contact 10:05 - 11:30 1.42 STWHIP P WEXIT Wiper thru pilot holes, clean 39.4k POOH for window milling assy 11:30-12:15 0.75 STWHIP P WEXIT lD 1.25 deg motor and 0331 mill. MU 3.0 deg motor and window mill 12:15 - 14:10 1.92 STWHIP P WEXIT RIH wI BHA #14. Set down at SSSV nipple and GLM's 6.5.3 and 2 14:10 - 14:45 0.58 STWHIP P WEXIT log tie-in wI CCl down from 9650-9920' Corr -16' 14:45 - 15:00 0.25\ STWHIP P WEXIT RIH from 9930' 0.3/100/10R and clean to tag at 10068'. PUH 5' start motor 2.64/2370/1 OR Ease in hole and first motor work at 10068', flag yellow. Pull back l' 15:00 - 00:00 9.00 STWHIP P WEXIT Begin milling window by standard timed procedure from 10067' 2.64/2380/5R. Seeing a little formation and a lot of CaC03 very little metal after drilling to 10071.1' continue with time milling. Toollaces have been acting as expected while milling the window. Not much torque but a reverse TF to the right after crossing what appeared to be the center of pipe. 5/17/2004 00:00 - 02:00 2.00 STWHIP P WEXIT Continue milling to 10072.7' Drilling off like formation would. Drill from 10072.7' to 10080'. Samples still showing the same very little sand or metal. P/U and dry tag back at 10080'. No hang-ups or bobbles around "window" area. 02:00 - 02:40 0.67 STWHIP P WEXIT Mix and pump 30 bbls hi-vis pill to flush 160' of 9-5/8" annulus below tbg tail. Seeing sand in the bottoms up samples but very little metal. Metal on magnets is very fine. 02:40 - 04:55 2.25 STWHIP P WEXIT POH 04:55 - 05:50 0.92 STWHIP P WEXIT Window mill has charactenstic wear pattern in the center of passing through the casing. Gauged 3.75 go 3.74 no-go. P/U window dressing milling BHA. 05:50 - 07:25 1.58 STWHIP P WEXIT RIH w/ BHA #15 (2.25 deg motor, 3.78" tapered mill) 07:25 - 08:00 0.58 STWHIP P WEXIT log tie-in down to CCl from 9650' Corr -15' 08:00 - 08:20 0.33 STWHIP P WEXIT RIH 0.3/120/5R and tag at 10074'. PUH 40k, start motor 2.6/2520/5R. RIH and motor work and 3 stalls at 10074.4' (assume this is BOW and we're probably a couple feet off depth) Calling TOW 10068' BOW 10073' 08:20 - 09:30 1.17 STWHIP P WEXIT Finesse ream down in mini tenths to clean up window from 10074.0' 2.7/2600/5R wI 50-100 psi diff 09:30 . 10:30 1.00 STWHIP P WEXIT 10075.0' Appear to be thru. Ease in hole and tag at 10082'. Backream at HS TF, clean. Backream at various other HS TF's, clean. Dry tag, clean 10:30 . 12:00 1.50 STWHIP P WEXIT POOH for drilling assy 12:00 . 12:20 0.33 STWHIP P WEXIT lD tapered mill, gauged at 3.78" w/ no wear 12:20 - 13:00 0.67 DRill P PROD1 MU drilling assy Pun red 5'201/20(14 104007 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date Page 19" BP EXPLORATION Operations Summary Report 14-06 14-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase 5/17/2004 13:00 - 14:35 14:35 - 15:00 15:00 - 15:20 15:20 . 15:30 15:30 - 15:40 15:40 - 16:00 16:00 - 17:45 17:45 - 19:25 19:25-21:20 21 :20 - 22:00 22:00 - 22:20 22:20 - 00:00 5/18/2004 00:00 - 02: 15 02:15 - 02:30 02:30 - 03: 1 0 03: 1 0 - 06:30 06:30 - 09:55 09:55 - 10: 1 0 10:10 - 10:20 10:20 - 11 :50 11 :50 - 12:00 12:00 - 13:15 13:15 - 13:45 13:45 - 15:10 15:10 - 16:15 RIH wi BHA #16 (DS100 bit, 2.7 deg motor) Log tie-in down from 9650'. Carr -15' RIH at min rate and tag at 10080' PUH 39.5k, start motor 2.6/2500. Ease in hole to first motor work Unll tram lUU¡jU-1UU/:H:f bUtnr 2.6/.2500/10l wi 150 .J:::.i I..hrl PUH thru window after MWD tool quit. BHI try to restart, but has a short Swap to mud since trucks here, window is good and sho ge of trucks in field. Recip above TOC ramp while send d down CT 2.64/2580 POOH Diagnose problems. Trace down to flow-sub. ange out. P/U BHA all test good. Stab-on injector. Notice all of coil wicker's just inside of lubricator. Swapping to FI ro may have brought this up. Previous runs without Flo-Pr In hole may have caused this damage to coil. RIH check orienter - ok. Open rc sub to allow high rate pumping to clear hole of m wickers and to stiffen coil while RIH. Stop at 9650'. Clos. circ sub. Log tie-in down from~50'. Corr -16'. RIH highside no prp6lems at window. Directionally dr~~head f/1 0088' 2.6/3380 3-400psi MW to 10128'. /ç' PROD1 Continue ectionally drilling build section II 10128' to 10225'. PROD 1 Wiper back to window. 43k up wt 16k dwn PROD1 Co' ue directionally drilling build section fl 10225'. 2.6/3350 OOpsi MW 2-3k wob 40-60'/hr Drilled to 10260'. Start Hi-VIs / pill. PRODY TOH inspect last 200' of coil. LD BHA ZR 1 Pump slack back. Cut oft 60' CT for chrome management. Rehead. PT 42k. Test continuity. PT 4k. MU lateral assy ROD1 RIH wi BHA #18 (1.5 deg molor/DS49 bit) to 1000' 0.5/1000 DF~ PROD1 POOH after tool short OfAL PROD1 Found e-line had pulled out of head. Had circulated before // start RIH, but obviously not enough / Rehead. Pump thru CT DFAL PROD1 RIH wi BHA #18rr 2.5/2760 thru EDC one CT volume. PROD1 RIH to 10060' PROD1 Log Gr tie-in -24' PROD1 Mad pass to bottom. PROD1 Directionally drill f/1 0260'. 36k up st 21 k dwn 2.6/3530 2-300psi MW 2-4k wob 60'-100'/hr Drilled to 10317' seeing declining charge pressures. Stop to trace down provlem Looking for problems in mud charging system. Drilling ahead f/1 0317'. (aired up mud system) Free spin 3400 psi at 2.6 bpm. Pit vol=250 bbls, mud swap asap when trucks arrive location. IAP=760 psi, OAP=239 psi. Drilling at 2.6/2.613800 psi. On a hard stringer. Make wiper trip to window, and catch bottoms up sample to see what we are dnlling on. Resume drilling. Still hard, but getting drilloffs, and making slow progress. PU off bottom to orient. 1.58 DRILL P 0.42 DRILL P 0.33 DRILL P 0.17 DRILL I-' 0.17 DRILL N 0.33 DRILL N 1.75 DRILL N 1.67 DRILL N 1.92 DRILL N 0.67 DRILL N 0.33 DRILL N 1.67 DRILL P 2.25 DRILL P 0.25 DRILL P 0.67 DRILL P 3.33 DRILL P 3.42 DRILL P 0.25 DRILL P 0.17 DRILL N 1.50 DRILL N 0.17 DRILL 1.25 DRILL 0.50 DRI 1.42 0 LL 1.08 RILL ,,/ / 18:50 - 18:55 18:55 - 19:00 0.25 DRILL N 1.83 DRILL P 0.50 DRILL P 0.08 DRILL P 0.08 DRILL P PROD1 PROD1 PROD1 PHOU1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 PROD1 SFAL PROD1 PROD1 PROD1 PROD1 PROD1 Start: 4/18/2004 Rig Release: 5/21/2004 Rig Number: Spud Date: 2/26/1979 End: 5/2112004 Description of Operations / Pr,nt.,.d 5'2J/2004 104007 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 \Þ.l ~ A- 1-/ z.. ~ 11- () C}'/- ~~ IJ' 'e/'G /5\ 1. Type of Request: IS! Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 73' 0 Suspend 0 Repair Well IS! Pull Tubing 0 Operation Shutdown 0 Perforate IS! Plug Perforations / 0 Stimulate 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: IBI Development 0 Exploratory 0 Stratigraphic Test 0 Service 0 Waiver 0 Time Extension 0 Annular Disposal 5. Permit To Drill Number 178-065 /' 6. API Number: / 50- 029-20328-00-00 0 Other 99519-6612 9. Well Name and Number: PBU 14-06 / 8. Property Designation: 11. Total Depth MD (ft): 10895 CasinQ" ",.,.".., "" ,""","" . ~tnldIJr;:¡1 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENTWELLGONDITIONSLJMMARY ~-~ "..,,', "',' ','. ~ ", ,',,' '," Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9620 10264 / 9098 10264 10091 "Lenath ,',., """,~é- ',Size, ."', ",.,""" ."" 'MD, ,"".,.,"'",., '.',',' ",', "WD ,'".",',' BÜr$(, , 'Collapse .c:- ADL 028312 - . ( .ruulI u:n r ~llrf;:¡r.A . . 115' 2717' 20" 13-3/8" 115' 2717' 115' 2717' 1530 520 53 0 2670 '~r-A~"'~ 6ö rLT ,-~~:g~/U1RJÐ -~ rF ~ ~ ." '- J l{lDIJ. ð'f/tiJgiäC!:& r.:... ^ Tubing Grade: ~~ 'w, L-80 / N-80""."~\)' Packers and SSSV MD (ft): 9801' 2035' '"1n fft): 9817" . . Proch ,,,.finn Linp.r 10881' 9-5/8" 10881' 9609' Perforation Depth MD (ft): T Perforation Depth TVD (ft): 1 10062' - 10205' I 8930' - 9048' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'SAB' packer; 7" Otis SSSV Tubing Size: 7" 29#; 5-1/2" 17#, 4-1/2" 12.6# 12. Attachments: IBI Description Summary of Proposal 0 BOP Sketch 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 Dan .!S:a~ Title CT Drilling Engineer " ~ ' 7. l.. Prepared By Name/Number: SiQnature t\ ~ J)"" '--' Phone 564-5667 Date 2./,,0 )01 Terrie Hubble, 564-4628 I Sundry Number: Þ7lt1 (I j<;-O April 1, 2004 / Date: 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 0 Plugged DWINJ IBI Abandoned 0 WDSPL Contact Dan Kara, 564-5667 Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ";,..,,- Other: :::::::n~ti1 '~A ~tA~~~ MA~ C:~~::NER Form 10-40~sed ~ ~ I,:, (":; ~ t\J ,!~ I,' ! '-" II ~ ~ /,:'-\ RiI1I88fl Date rJ;&,3 /fJ¥ Submit In ~6uplicate fiB. 29 . BY ORDER OF THE COMMISSION To: Winton Aubert Sr. Petroleum Engineer Alaska Oil & Gas Conservation Commission From:Dan Kara, BP CTD Engineer Date: February 20, 2004 Re: CTD Tubing Swap and Sidetrack of Prudhoe Bay well 14-06 Well 14-06 is scheduled for a through tubing sidetrack with coiled tubing drilling rig Nordic 2. Prior to CTD sidetracking, the 7" x 5-1/2"(collapsed) L-80 production tubing will be replaced with 4-1/2" 13-Chrome tubing. // The perforations will then be P&A'ed with 17 ppg cement in preparation for window milling, The sidetrack, 14- 06A, will kick off from a window milled off the 17 ppg cement plug. Upper Zone 4 will be the target for the /' sidetrack. Approximately 1920' of 3-3/4" to 4-1/8" open hole is planned to access the target. The well will be completed with a pre-drilled 3-3/16" x 2-7/8" liner, Pre- rig Prep work. 1, MIT outer annulus to 2000 psi, 2, Chemical cut tubing - 1 joint above collapse at 8768' md. 3, Circulate well over to kill weight fluid, Nordic 2 RWO - Tubing Swap. 1. RU Nordic 2 with 13-5/8" BOPE, Test stack. 2. Pull 7" x 5-1/2" L-80 tubing, 3, RIH with drill pipe, fish out collapsed tubing stub, 4. RIH with casing scraper run, 5. RIH and set RTTS at -9750' md, test 9-5/8" casing to 3500 psi. 6. Complete well with 4-1/2" 12,6# 13Cr-80 tubing with new packer, Stab tailpipe into old PBR. 7. PT completion, RD 13-5/8" BOPE. NU tree and 7-1/16" CTD BOPE, Test. Nordic 2 CTD -~ perfs, Mill window, Drill and Complete sidetrack: 1. Pum~J.s-'bf 17 ppg Class G cement to P&A exis!ing perfs and provide a cement ramp for window milling. Lay in cement from last tag of 10166' md:-Squeeze up to 12 bbls behind pipe. Jet to 9900', -l\ 0 ,- ~o",2, Mill 3,8" window at 10080' md, through the 9-5/8" casing, So. \ t "'3, Directionally drill -1920' of 3-3/4" to 4-1/8" open hole to a planned TD of 12000 md, 8871' TVD. "1'proí.(Ç,.... 4, Run 3-3/16" x 2-7/8" pre-drilled liner from TD up to 9750' md (no cement) 5, RD Nordic 2, We would like to begin the prep work operations by April 01, 2004. Please let me know if I can provide you with additional information. ~...~ Dan Kara CTD Drilling Engineer cc: Well File Terrie Hubble . TREE = ' GRA Y GEN 2 WELLHEAD = MCEVOY ÂCTuÄ TOR'; '-" -, -, ÒTlS KB~ËlEV-; - ---"_.__.-,,-----,, 73; . . .. .......~... h"""" . .. SF. ELEV = ---¥---'-"'-'-''''''''------'--- KOP = 3100' _~~n'--___,' ........_.h'_~ 'n..',__,'-"------ Max Angle = 38 @ 6000' 5ãtum MO;-'----'---99!34; --'.-'"''''-'''--''''''''' ,-"'_...'._n.... _.~._..._... .... ,-. .. Datum 1V 0 = 8800' SS SAÆTY NOTES: T X IA COMM, FTS. T X IA PO LEAKS, NEEDS DSSSV IN NIP FOR COMM (NRfW). DSSSV REQ. OVERSIZE PACK-SEE 01122/99 WSR 14-06 <8 I 13-3/8" CSG, 72#, N-80, 10 = 12.347" I ST MD 1 2857 2 2928 3 4970 4 5042 5 5808 6 5880 7 6626 8 6701 9 7729 10 7792 11 8427 12 8492 13 8897 14 8968 15 9402 16 9468 Minimum ID = 3.958" @ 9814' 4-1/2" TU B IN G TAIL I 7" TBG-NPC, 29#, L-80, 0.0371 bpf. 10 = 6.184" I ITOPOF 5-1/2" TBG-NPC I 5713' -1 7" X 5-1/2" XO I 9669' - 5-1/2" OTIS SLIDING SLV I -1 5-1/2" SOTPBRASSY I -1 9-5/8" X 5-1/2" SKR SAB PKR I -1 5-1/2" X 4-1/2" XO I 9790' 1-1 ELMO TT LOGGED 02/23/91 I 15-112" TBG-NPC, 17#, L-80, 0.0232 bpf, 10 = 4.892" I I TOP OF 4-1/2" TBG-NPC I 14-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, 10 = 3.958" I PERFORA~ONSUMMARY REF LOG: SHCS ON 03/15/79 ANGLE AT TOP PERF: 34 @ 10062' Note: Refer to Production DB for historical perf data SIZE SPF INlERVAL OpnlSqz DATE 3-3/8" 4 10062 - 10089 S 05124/86 3-3/8" 4 10062 - 10108 0 06130/90 3-3/8" 4 10089 - 10108 S OS/24/86 3-3/8" 4 10120 - 10157 S 05124/86 3-3/8" 4 10120 - 10157 0 06130/90 3-318" 4 10157 - 10162 0 06130/90 3-3/8" 4 10162 - 10205 S 05124/86 3-318" 2 10162 - 10205 0 06130/90 3-1/8" 4 10205 - 10209 S 05104/86 3-3/8" 4 10310 - 10420 S 08113/82 IPBTD I 19-5/8" CSG, 47#, N-80, 10 = 8.681" I OÐ DATE REVSY COMMENTS DATE REV BY COMMENTS 03/26179 ORIGINA L COMPLETION 12/24/02 JM'TP C/O GLVs 12113/82 LAST WORKOVER 02/08/03 A TDITP CUT ISPITT CORRECTION-12/82 12182 CUT ISPIlT 03/22/03 JMPlKK SAFETY NOTE REVISION 12/20/00 SIS-QAA CONVERTED TO CANVAS 02/22/01 SIS-LG REVISION 01/07/02 RNITP CORRECTIONS FRAC SLV SET 12/25/02 WI?" G FN W/4.625" 10 GAS LIFT MANDRELS lVD DEV lYPE VLV LATCH PORT DATE 2857 3 O~S/RLX DMY 12 12124/( 2928 5 O~S/RLX RA 4765 34 O~S/RLX RA 4825 34 O~S/RLX RA 5455 37 CAJ DMY RK 5512 37 CAl RKP 6109 36 CAl RK 6170 36 CAJ RK 7007 35 CAJ DMY RK 7058 35 CAl RK 7580 34 CAl RK 7634 34 CAl RK 7969 34 CAl RK 8027 34 CAl RK 8384 35 CAl RK 8438 35 CAJ DMY RK 12/24/( 12/24/( 12/24/( 1-1/2" GL V 03/10/91 ELM CMT CAP (SET OS/24/86) SHOT OFF TUBING TAIL PRUDHOE SAY UNIT WELL: 14-06 PERMIT No: 1780650 AA No: 50-029-20328-00 SEe 9, T10N, R14E. 1731' FNL & 1129' FEL BP EJcploratlon (Alaska) ¡ TREE = , GRAY GEN 2 SAFETY NOTES: WAlVERED WELL- T x IACOMM, FTS. NL REa FOR WAIVER CONDo TxlA PO LEAKS. NEEDS DSSSV IN NIP FOR COMM (NRFW). DSSSV REa. OVERSIZE PACK-SEE 01/22/99 WSR. Proposed RWO/CTD Sidetrack WB..LHEAD = MCEVOY ACTUA TOR = OTIS KB. B..EV = 73' BF. B..EV = KOP= 3100' Max Angle = 38 @ 6000' Datum MD = 9994' Datum TV 0 = 8800' SS 14-06A I 13-3/8" CSG, 72#, N-80, 10 = 12.347" I Gas Lift Mandrels 9700' 1-1 9-5/8" x 4-1/2" PKR 9725' 1-1 Top of 3-3/16" Liner I 9750' ~3-1/2" X NIP, 10=2.813" 1 9m' ~ 5-1/2" BOTPBRASSY I -1 9-5/8" X 5-1/2" BKR SAB PKR -1 5-112" X 4-1/2" XO I 9790' 1-1 B..MD TT LOGGED 02/23/91 I Minimum ID = 3.958" @ 9814' 4-1/2" TUBING TAIL 14-1/2" TBG, 12.6#. CR. .0152 bpf, 10 = 3.958" 15-1/2" TBG-NPC. 17#, L-80, 0.0232 bpf, 10 = 4.892" TOPOF 4-1/2" TBG-NPC I 14-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, 10 = 3.958" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 03/15/79 ANGLEATTOPÆRF: 34 @ 10062' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10062 - 10089 isolated proposed 3-3/8" 4 10062 - 10108 isolated proposed 3-3/8" 4 10089 - 10108 isolated proposed 3-3/8" 4 10120 - 10157 isolated proposed 3-3/8" 4 10120 - 10157 isolated proposed 3-3/8" 4 10157 - 10162 isolated proposed 3-3/8" 4 10162 - 10205 isolated proposed 3-3/8" 2 10162 - 10205 isolated proposed 3-1/8" 4 10205 - 10209 isolated proposed 3-3/8" 4 10310 - 10420 isolated proposed -1 Top of Cement -i Cement Ramp Window -13-3/16 x 2-7/8 X-over I 3-3/16" X 2-7/8"pre-drilled liner 1-1 12000' I 10091' 10264' 10699' 19-5/8" CSG, 47#. N-80, 10 = 8.681" I ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 03/26/79 ORIGINAL COMA..ETlON 12/24/02 JM'TP ClO GLVs 12/13/82 LAST WORKOVER 02/08/03 A TDfTP ClIT IBPm CORRECTlON-12/82 12/82 CUT IBPm 12/20/00 SIS-QAA CONVERTED TO CANVAS 02/22/01 SIS-LG REVISION 01107/02 RWTP CORRECTIONS 1-1/2" GLV 03/10/91 B..M CMT CAP (SET OS/24/86) SHOT OFF TUBING TAIL PRUDHOE BA Y UNIT WB..L: 14-06 ÆRMIT No: 1780650 API No: 50-029-20328-00 SEC9, T10N, R14EUM 1731' FNL & 1129' FB.. BP Exploration (Alaska) BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp March 6, 2003 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 14-06 (PTD 1780650) Application for Sundry Cancellation Dear Mr. Maunder: Attached is the Application for Sundry Cancellation form 10-404 for well 14-06. This request is for approval to cancel the existing Sundry for this shut in producer. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or me at (907) 659-5102. Sincerely, e Anders, P.E. Well Integrity Engineer Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ CANCEL 10-403 Pull tubing _ Alter casing _ Repair well_ Other_X CANCEL t0-403 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1732' FNL, 1129' FEL, Sec. 09, T10N, R14E, UM At top of productive interval 4191' FNL, 3957' FEL, Sec. 09, T10N, R14E, UM At effective depth 4244' FNL, 4059' FEL, Sec. 09, T10N, R14E, UM At total depth 4400' FNL, 4376' FEL, Sec. 09, T10N, R14E, UM 5. Type of Well: Development ._X Exploratory_ Stratigraphic._. Service_ (asp's 675356, 5938612) (asp's 672591, 5936088) (asp's 672490, 5936035) (asp's 672178, 5935869) 6. Datum elevation (DF or KB feet) RKB 73 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-06 9. Permit number / approval number 178-065 / 399-083 10. APl number 50-029-20328-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 115' Surface 2685' Production 10849' 10895 feet Plugs (measured) 9620 feet 10264 feet Junk (measured) 9098 feet CMT Cap @ 10264' (05/24/1986) 1-1/2" GLV @ 10091' (03/10/1991) Size Cemented Measured Depth True Vertical Depth 20" 300 sx AS 147' 147' 13-3/8" 5000 sx Perma II 2717' 2717' 9-5/8" 1000 sx Class 'G' 10881' 9609' Perforation depth: measured Open Perfs 10062'-10108', 10120'-10205', Sqzd Perfs 10205'-10209', 10310'-10420'. true vertical Open Perfs 8930'-8968', 8978'-9048', Sqzd Perfs 9048'-9052', 9136'-9227' l'ubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 7", 29# L-80 TBG-NPC @ 5713'; 7" x 5-1/2" XO @ 5713'; 5-1/2" 17# L-80 TBG-NPC @ 9807': 5-1/2" x 4-1/2" XO @ 9807'; 4-1/2" 12.6# L-80 TBG-NPC @ 9814'. 9-5/8" x 5-1/2" Baker SAB Packer @ 9801'. FRAC SLV SET (12/25/2002) W/7" G FN W/4.625" ID @ 2035' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation SHUT-IN Subsequent to operation SHUT-IN OiI-Bbl Representative Da y Avera.qe Production or Iniection Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __X Gas __ Suspended Title: Well Integrity Engineer II Inte~rity Engineer 8CANNED 0 t uuo Form 10-404 Rev 06/15/88 · Questions? Call Well Integrity Engineer 659-5102 Date 5/~1 IO'"'~ Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 14-06 Sundry Cancellation Request 02/21/03 PTD# 1780650 Sundry# 399-083 dated 05/12/99 This is a request to cancel the AOGCC Sundry dated 05/12/99. The well is currently shut in. Reason for cancellation: The Sundry approved continued production of 14-06 with T x IA communication and capable of flow to surface. The well is SI pending repair of the tubing leak or the well returning to a non-flow to surface condition. SCANNED MAR 0 7 2003 TREE= GRAY GEN 2 WELLHEAD = MCEVOY !ACTUATOR = OTIS KB. ELEV = 73' B F. ELEV = KOP = 3100' Max Angle = 38 @ 6000' Datum MD = 9994' Datum TVD= 8800' SS 14-06 SAFETY NOTES: WAIVERED WELL- T x IACOMM, FTS. A/L REQ FOR W.NVER COND. TxlA PO LE.N(S. NEEDS DSSSVIN NIP FOR COMM (NRFW). DSSSV REQ. OVERSIZE PACK-SEE 01/22/99 WSR. 2035' I'-1 FRAC SLV SET 12/25/02 I WI7" G FN W/4.625" ID GAS LIFT MANDRELS 13-3/8" CSG, 72#, N-80, ID = 12.347" Id 2717' IMinimum ID = 3.958" @ 9814' 4-1/2" TUBING TAIL 7" TBG-NPC, 29#, L-80, 0.0371 bpf, ID = 6.184" 5713' [TOP OF 5-1/2" TBG-NPC Id 5713' 9807' 9807' 4-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID: 3.958" Id 9814' ~- -- PERFORATION SUMMARY REF LOG: BHCS ON 03/15/79 ANGLE ATTOP PERF: 34 @ 10062' Note: Refer to Production DB for historical perf data SI7~ SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10062 - 10089 S 05/24/86 3-3/8" 4 10062 - 10108 O 06/30/90 3-3/8" 4 10089 - 10108 S 05/24/86 3-3/8" 4 10120 - 10157 S 05/24/86 3-3/8" 4 10120 - 10157 O 06/30/90 3-3/8" 4 10157 - 10162 O 06/30/90 3-3/8" 4 10162 - 10205 S 06/24/86 3-3/8" 2 10162 - 10205 O 06/30/90 3-1/8" 4 10205 - 10209 'S 05/04/86 3-3/8" 4 10310 - 10420 S 08/13/82 19-5'8"csG,47#,N-8°,'D=8'681.' I-t 10881' 1o895'; 5713' 1-1 7"x5-1'2"x°l 9669' 5-1,2" o'r,s SL,D, NG SLY I 9777' H 9801' 1-1 9807' 1-1 I9790, 1-1 ~ 10091' [.1 o2-'H L 10699'H 5-1/2" BOT PBRASSY ] 9-5/8" X 5-1/2" BKR SAB PKR [ 5-1/2" X 4-1/2" XO I ELMD q-l' LOGGED 02/23/91 1-1/2" GLV 03/10/91 J ELM CIVIT CAP(SET 05/24/86) [ SHOT OFF TUB ~G TA L [ o3/26/791 IOR~NAL COM~_ET,ON 12/13/82 1ILAST WO~OVER 12/82 I pUT,~- 12/20/00 [ SIS-QAA [CONVERTED TO CANVAS o2/22/OlI s~s-L~ IREV~ION ol/o7/o21 R~TP ICORRECTIONS COMMENTS CIO GLV s CO RRECTION- 12/82 PRUDHOE BAY UNIT WELL: 14-06 PERMIT No: 1780650 APl NO: 50-029-20328-00 SEC 9, T10N, R14E UM 1731' FNL & 1129' FEL BP Exploration (Alaska) ARCO Alaska Inc. Post Office Box 1003§0 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 May 12, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: 14-06 Sundry Notice and Waiver Request Dear Mr. Wondzell: Attached is a Sundry application for ARCO well 14-06. The application requests waiver approval for resumption of production of the well with known tubing x annulus communication. The 9 5/8" casing continues to demonstrate integrity as shown by Combination MIT (Tubing x Inner Annulus) tests, and we believe control can be maintained by proper monitoring of production, and with continued annular monitoring and testing. Details of the proposed monitoring and testing routines to assure isolation are included as attachments to this letter. If you have any questions please contact Jerry Dethlefs or Joe Anders at 659-5102. Sincerely, Joe Anders Problem Wells Specialist Attachments: Sundry Form 10-403 Sundry Discussion and Action Plan 07:03 F r om-EOC $07659591 ?' . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS T-?01 P.02/02 F-399 1. Type of Request: Abandon -- Alter casing -- Change approved program __ Suspend __ Operalion shutdown Re-enter suspended well Repair well -- Plugging __ Time extension Pull tubing -- Variance X Perforate __ Stimulate__ Other 12, 2, Name of Opera~°r ARCO Alasl(a. lac 3, Address P,O, BOx 100360 Anchorage Ak 99510.0360 Location of well at surface 173'1' FNL. 1129' FEI., Sec, 9, TION, R'14E, UM At top of productive interval 1089' F6L. 1323' FWI., See, 9, T10N, R14E, UM At effective depth 882' FSI., 912' FWL, Sea, 9, TION, R14E, UM At total depth Present well condition ,~ummary Total depth: measured true vertical Type of Well Development ~x Exploratory ~ Strafigraphie Service .. 6. Datum of Elevation (DF OR KB) 73' RKB 7, Unit or Property Prudhoa Bay UMt 8. Welt number 14-06 9- Permit number 78-65 10. APl number $0.029-20328 11, Field/Pool Prudhoe B,a.¥ Oil Pool 10,895 feet Plugs (measured) Top of Fill @ 10,127' MD (12/21/96) 9,621 feet Effeotive depth: measured 10,264 feet tree vertical 9,09§ feet Junl~ (measured) Casing Length Size Cemented Measured depth True vertical depth Condu=tor 115' 20" 300 ax AS 115' 115' Surface 2644' 13-318" 5000 sx Pen~a II 2717' 2717' Production '10808' 9-5/8" 1000 sx CI 'G' 10881' 9696' true ve~cal 892~8968'; 8978-90t2'; 9012-9048' Tubing (size, Grade, and measured depth) 7", 29# I..-80, NPCT @ 5713' MD; 5-1/2". 17#, L-80, NPCT {~ 980 4-112". 12.6#, N-80, NPC ta~l ~ 9814' MD PeGkers and SSSV (type and measured aepth) Baker SAB pa~er @ 9801' MD; 7" Otis SSSV @ 2035' MD 16. 17. 13, Atlacllments Description summary of proposal X De. led epistlers program BOP sketoh . .. 14. Estimated date fo~ ¢x3mmencln9 operation '15. Status of well classification as: Date of Sundry approval If proposal was verbally approved Name of al~prover Date approve_d I hereby ce~llfy that the foregoing is true and correct to the best of my knowledge, Signed ~_(~ ~ Title FOE COMMISSION USE ONLY Condition of approval: NOtify Commission so representative may witness Plug integrity ~ BOP test ~ Location clearance Oil x Gas Suspended Service Problem Wells ~pecialist echanical Integrity Test -- Ap.l~mV~..b_¥ o~er of ~ne Commissioner ul3sequem form required 1o- riginal Signeo By David W. Johnston Commissioner Focm I0-403 Rev08/15~88 J, Dethlef$ / J. A~ders - g07-659-5102 - PRB 24 Original Signeo ~, David W. Johnston DS t4-06 SUNDRY NOTICE 10-403 APPLICATION 5/12/99 DISCUSSION Well 14-06 is an oil-producer that exhibits tubing x 9-5/8" annular communication. The well is capable of unassisted flow of hydrocarbons to surface (tested on 3/27/99). On 12/29/98, a Leak Detection Log showed a singular leak at the SSSV. There is apparently some sort of problem with the SSSV profile as 7 attempts to run dummy SSSV's have failed to repair the leak. Approximately $70,000 has been expended since 8/98 to diagnose and attempt to repair the SSSV leak. Based on the remaining reserves, the well is not a rig workover candidate. There are no sidetrack targets from this wellbore The well has been shut-in since 11/98 because of the flow-to-surface condition. Forecasted remaining reserves are 110 MBO, with a remaining life through 2002. The well is currently responding to offset MI injection. Responses have typically lasted two to three months. This waiver request is to allow resumed production (with artificial lift) for an indefinite period. The request is supported by the following: · A passing combination MIT (T x IA) was performed on 5/10/99 to 3000 psi against an inflatable bridge plug. This shows that the 9-5/8" casing and packer have integrity. · The maximum IA pressure will be limited to 2000 by the ARCO internal waiver process. · The 9-5/8"x13-3/8" hanger packoff has integrity per positive pressure testing on 4/26/99. · The Tubing x 9-5/8" hanger packoff does not have integrity per positive pressure testing on 5/9/99. · The 13-3/8" casing also has integrity based on a passing MITOA on 5/11/99 to 2000 psi. · The IA will not be exposed to wellbore fluids while on artificial lift. ACTION PLAN 1. Allow well to resume production, with artificial lift rates as required. 2. Perform a CMIT T x IA to 3000 psi every 2 years. 3. Perform an annual MITOA to 2000 psi. 4. Record wellhead pressures daily. 5. Shut-in the well should MIT's or pressures indicate further problems. ARCO Alaska, inc. PRB 14-06 SQZ (10062-10700) Size Size 7OOO 55OO 4 5OO 38 deg@6100 Comment 34 deg@10062 34 de9@10895 Set SSSV bylmO Thread Thread Comment Description 7" ot RPB Land Nip Tx9 Leak @ SSSV Nipple pu!led dummy SSSV 1/22/99 385" ~D; two sets oversize package 1/22/99 5-1/2" Otis Sliding Sleeve 4-1/2" Tubing Tail Comment FO @ 2348' FO @ 2469' :4-1/2" TT) 14-06 Well Test Plot ' 14-06'F'TS Sundry Request Subject: 14-06 FTS Sundry Request Date: Thu, 13 May 1999 07:46:55-0900 From: "PRB Problem Wells" <P 1041 ~mail.aai.arco.com> T o: B lair_Wondzell~admin, state, ak.us Hi Blair. We have another well capable of unassisted flow of hydrocarbons to surface with tubing x IA communication. It appears to be a good candidate for a sundry/waiver and we are submitting it for your review. Well 14-06 is a gas lifted producer making 300 BOPD, 200 BWPD, 8000 GOR with 2500 MCFD AL. It has been shut-in since 11/98 with tubing x 9-5/8" communication and is capable of unassisted flow of hydrocarbons to surface. Pertinent information: - A leak detect log and a video log both indicate the leak is at the SSSV nipple. - We have installed 7 DSSSV's in various configurations attempting to stop the leak since 8/98, all unsuccessful. - Leak rates with the DSSSV out of the well are around 2 BPM at 1330 psi. With the DSSSV in the nipple, leak rate is approximately 1 BPM at 3000 psi. - A combination tubing x 9-5/8" pressure test passed to 3000 psi on 5/10/99. - The 13-3/8" passed a pressure test to 2000 psi on 5/11/99. - There is no communication between the 9-5/8" x 13-3/8". - Remaining reserves of 110 MBO don't justify a rig workover to pull and replace the tubing. There are no sidetrack targets accessible from this wellbore. - 14-6 was apparently responding to MI injected into an adjacent injector when it was shut-in. Attached to this email is a wellbore schematic, production plot, form 10-403 and a 10-403 discussion. I faxed the signed 10-403 to 276-7542, hard copies of everything will be mailed today. If possible, we would appreciate you giving the well a fairly high priority on your work list. It is ready to be brought back on line and was undergoing an EOR response when SI. Please call if you have any questions. Thanks! Joe Anders Problem Well Specialist 659-5102 (See attached file: 14-6 Sundry Attach.doc) (See attached file: 14-06 10-403.xls) (See attached file: 14-06.pdf) (See attached file: 1406prod.bmp) 14-6 Sundry Attach.doc Name: 14-6 Sundry Attach.doc Type: Winword File (application/msword) Encoding: base64 Description: Mac Word 3.0 l'~l ] Name: 14-06 10-403.xls ] Type: Microsoft Excel Worksheet (application/vnd.ms-excel) 4-06 10-403.xls Encoding: base64 Description: Microsoft Excel 97 ..................................................... Name:. 14_06~'pdi~ Type: Acrobat (application/pdf) ~ 14-06.pdf Encoding: base64 Description: Adobe Portable Document 1 of 2 5/13/99 8:39 AM 14-06 F-*I'S Sundry Request ~ 1406prod.bmp Name: 1406prod.bmp Type: Windows Bitmap (image/x-MS-bmp) Encoding: base64 Description: Windows Bitmap 2 of 2 5/13/99 8:39 AM GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATI'N: Sherrie NO. 9720 Company: 9/12/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 7-6 7 %// I I-~ PACK OFF GAS LIFT MANDREL 950826 I I - D.S. 7-6 0-[ TUBING PUNCHER RECORD "' 950825 I 1 D.S. 7-19 ~ ~ ~-- I'~ PRODUCTION PROFILE 950822 I 1 D.S. 9-1 -7 ~-~ O ~ (O LEAK DETECTION LOG 950822 I I - D.S. 9-29 ~;-- ~/C~ ~ ... PRODUCTION PROFILE 950820 I 1 D.S. 14-5A ~-')..~ oo t PRODUCTION PROFILE 950826.' I 1 D.S. 14-6 -7 ~ (.0 fo ~'~ .... STATIC pRESSURE SURVEY 950 e 25 I I .. D.S. 14-31 ~'-~ ill PRODUCTION PROFILE 950821 I 1 D.S. 15-14 ~ I 1'70 PRODUCTIONPRORLE 950824 I I ,,, SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well~: 1 4-06 I RECEIVED MAR 1 1 Date:J 1/~a~t~J Commentsto Well has been SI since 7/93 (high watercut). Being evaluated for ST. I Well will not be produced until rig arrival (not scheduled) Well did produce in LP CL at = 250 psi ftp. Designed to dump at FTP = 600 psi using Mechanistic model. · Attempted to use WPS, but PH2 model caused program to bomb ttoo light a gradien Previous Settings: Dome Pres. (PSIG) Closure FTP (PSIG) 180 245 Date 9/14/93 135 180 11/17/93 Production Data: ROR = 218 BOPD @ 9 0 Deg choke CFR = BOPD @ Deg choke Swing Well (very high or Iow GOR): No Choke Priority Well: No Design Parameters: Basis (one only): Actual well test and date. Flowing-pressure survey and date. Rates used with hydraulics program Rates (if needed): Oil Rate 2 46 BOF~ Watercut 7 9 % Formation GOR I 157 SCF/STB · Gas Lift Gas Rate 3003 MSCF/D Total GLR 2758 SCF/STB Flowing Tbg. Pressure 246 PSIG Flow. Wellhead Temp. 105 Deg F Choke Setting . 85H Deg only): JPH2 Conditions at Valve: Temp. @ SSSV 138 Deg F Pres. @ SSSV 44 7 PSIG Pres. Adjustment @ SSSV -415 PSIG Notice: This adjustment is at the valve, not surface. Calc. Dome Set Pres. 288.0 PSIG @ 60 Deg F Actual Dome Set Pres. 2 9 0 PSIG @ 60 De9 F FTP at K-valve Closure 6 0 0 PSIG @ Surface K-valve Type A (A, B, or C) cc: Cooper/Lance SmartJShoemake (2 copies) State of Alaska (cover only) cc: D.S. Eng: D.S.M. Prep. by.' R. J. Reints (w/o attachments) vaughn/Campbell (cover onlY) R. T. Bumo ATO- 1560 PRB-15 PRB-24 ARCO Alaska, Inc. Date: Feb 25, 1994 P.O. Box 100360, %~./iorage, AK Transmittal #: 94024 99510~ ~, Subject: ARCO Static Pressure Surveys From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution fwellNumber iL°g Date(M-D-Y) Tool Type i RUn,Scale Contractor T0-- ql ~ 2-3 t 6-5-93 Static Press Surv. I 1, 5" Sch -- E:o ! 2-5 i 7-21-93 Static Press Surv.i " Sch :7~- ~ I 3-8 I 11-22-93 Static Press Surv. ~ " Sch ~bc[o ~:~ 7?-- ~ 3-19 l 1-3-94 Static Press Surv. I " Sch ~5 f 3-34A ! 11-22-93 Static Press Surv'i " Sch Cl[ ~ ~ 3-35 I 12-7-93 Static PressSurv. " Sch =ri ,, ! 3-36 I 7-24-93 Static PressSurv.! " Sch ~-' t~ ~ 4-12 i 11-17-93 Static Press Sun/.i " Sch -~ I 4-31 1-3-94 Static Press Surv..I " Sch -. 4-32 9-8-93 Static Press Surv. " Sch c~t..- ~ t 4-41 11-21-93 Static PressSurv. ~ " Cch -;lu~* I 5-12 j 7-21-93 Static Press Surv.I "' Cch ~Z.---~l{q . 6-19 . 11-28-93 I StaticPressSurv. ~ " Sch , - ¥'~ . 7-7A 7-21-93 Static Press Surv. I " Sch t i l~ 7-8 9-2-93 Static Press Surv.t " Sch ClZ...- !)~q 9-49 9-14-93 Static Press Surv. " Sch "" 11- 9-5-93 Static Press Surv. " Sch ~ ;~ 16ST1 ) \0c2 0---' ~ :~ 11-17 11-26-93 Static Press Surv. " Cch cfS_ Iq8 , 12-16A 11-8-93 Static Press Surv. " Sch ~ 13-14 7-2-93 Static PressSurv. " Sch 13-14 7-2-93 Static Press Surv. " Cch ~- ~'0 i 14-01 11-25-93 Static Press Surv. " Sch ~ I 14-6 11-25-93 Static Press Surv. " Sch C~ 14-18 11-26-93 Static Press Surv. " Sch c~ 1.0;5 14-38 12-4-93 Static Press Surv. " Sch ~- [~ 14-39 12-4-93 Static Press Surv. " Sch cji: ...ot~ctc ~ 15-6 5-28-92 Static Press Surv. " Sch ~ t ~-~';z,~DO 'gt--- t~t 15-15 7-5-93 Static Press Sun/. " Sch 1~({- ~-~ 15-16 8-26-93 Static Press Surv. " Sch ~O [ 15-18 10-26-93 Static Press Surv. " Sch c~.t-!"55 I 15-23 9-23-93 Static Press Surv. " Sch Or- "~ I 16-12 7-21-93 Static Press Surv. " Sch Z?.c> ~ 16-17 I12-29-93 Static Press Surv. " Sch 2.q2~ ~ 16-18 ! 7-18-93 Static Press Surv. " Sch ~o-"St .~ [ 16-22 I 7-18-93 Static Press Surv. " Sch ~,!:. ,O0--'t~O~O ¢~ { 17-1 11-23-93 Static Press Sun/. " Sch t'~ ~ 17-13 8-27-93 Static Press Surv. " Sch [/0 I 18-29A 5-19-93 Static Press Surv. .. '~ ..... Sch ARCO Al,Mm, Inr.. I~ · ~ub~ldla~ of AtientlcRIchfleldComl~ny ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 1-28 ~'? ~-18-93 3-25A }~'23 6-17-93 3-31 ~V-?z 6-16-93 3-32 ~ ~/-/i~ 6-15-93 3-33 $ ¥- ;'o 6-16-93 4-8 ?~-,o 6-11-93 5-14 ??'~3 6-12-93 6-22A ~ ~.~6-6-93 6-22A - 6-10-93 7-25 ~l-y ~. 6-6-93 9-44 f ~ - ~ z~6.6.93 11-18 f~-I~z6-7-93 14-6 ~ ~- ~Y6-8-93 14-8 ?~-/,~ 6-10-93 14-13 ~']d 16-13-93 14-15tFt~ 6-8-93 16-4A ~z-W~6-9-93 16-17 ~' zza6-14-93 16-31 ~-~i 6-7-93 17-4 ~0~ 6-14-93 AGI-5 5~- ~ ~-6-13-93 AGI-6 [/$-d~ 6-14-93 AGI-7 · _6-8-93 AGI-7 } ~rt6-15-93 AGI-7 6'17'93 Prod Profile Completion Record Plug Setting Record Plug Setting Record Plug Setting Record Perf Record TBG Cutter Record Leak Detect Leak Detect Perf Record Perf Record Production Log PITS/Leak Detect. Leak Detect Inj Profile Completion Record Prod Profile Perf Record Production Log Completion Record Completion Record Completion Record Perf Record Run 1, 5" Run 1, 5" R~m 1, 5" Rl1~ 1, 5" Run 1, 5" Rim 1, 5" Run 1, 5" Rim 1 2" Run 1, 5" R!~n 1, 5" Run 1, 5" Rim 1, 5" Run 1, 5" Run 1, 2"&5" Run 1, 5" R!~r~ 1, 5" Run. 1, l"&5" Run 1, 2"&5" Run 1, 5" Run 1, 5" R~_m 1, 5" Run 1, 5" R!!n 1, 5" Elm 1, 5' Ru_n 11, 5" 5" 5" 5" AGI-8 ?~-~ ~/6-9-93 GR/CCL Run 1, AGI-9~ ~,}.~ 6-9-93 ~~ R~m 1, AGI-9/-t 6-17-93 Peff Record R~ 1, ~e~e si~ ~d ret~ ~ceipt of ........... RECEIVED B' Have A Nice Sonya W~ace ATO-1529 # CENTRAL FILES # CHEVRON #BPX # STATE OF ALASKA Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch · Sch Sch The correct API# for 3-32 is 50-029-21141~. The cor~ct wen name for t_ht~ log is 6-22A. Drill Site: 14 Well: 6 Sat Dec 12 07:24:11 1992 K-VALVE DESIGN o. ,. CC: DOME SET PRESSURE: 185 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 245 PSIG K-VALVE CLASS (A,B,C): B J.E. FAUSE~ / C.W. ~U~Y P~ 13 nESZ~ BY: ~ STATE OF ALASKA ~' -~ ALASKA, .AND GAS CONSERVATION CE; /IlSSlON REPORT OF SUNDRY WELL OPE'RATIO 1. Operations pedorm~: O~ration shutdown Stimulate X Plugging Perforate Pull tubing Alter casing 2. Name of Operator ARCO Alaskar Inc. 3. Address P,O. Box 100360, Anchorage, AK 99510-0360 Repair well Other 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-6 9. Permit number/approval number 78-65 10. APl number 50 - 029-20328 11. Field/Pool Prudhoe Bay Oil Pool Plugs(measured) Fill @ 9860' MD (3/28/92). 5. Type of Well Development , X Exploratory Stratigraphic Service 4. Location of well at surface 1731' FNL, 1129' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 1089' FSL, 1323' FWL, Sec. 9, T10N, R14E, UM At effective depth At total depth 882' FSL, 912' FWL, Sec. 9, T10N, R14E, UM 12. Present well condition summary 10895 feet 9621 feet feet 14. 15. Attachments 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure Perforation depth: measured 10062-10108'; 10120-10162'; 10162-10205' true vertical 8929-8968'; 8978-9012'; 9012-9048' Tubing (size, grade, and measured depth) 7", 29#, L-80, NPCT @ 5713' MD; 5-1/2", 17#, L-80, NPCT @ 9807' MD; 4-1/2", 12.6~, N-80, NPC tail @ 9814' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9801' MD; 7", Otis SSSV @ 2035'MD RECEIVED JUN 2 1992 Reore~entative Daily Averaqe Production or In!ection Data N~ch.0.0r.age OiI-Bbl Gas-Md Water-Bbl Casing Pressure ~uo~ng Pressure Prior to well operation Shut-In Subsequent to operation 222 638 915 -- 262 16. Status of well classification as: OilX Gas Suspended....._ Service. Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 115' Sudace 2644' Production 10808' Date 845/9 DRR cc: SW, JWP SUBMIT IN DUPLICATE 10264 feet 9096 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 300 sx AS 115' 115' 13-3/8" 5000 sx Perma II 2717' 2717' 9-5/8" 1000 sx Cl "G" 10881' 9696' 14-06 DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF ZONE 4 2/22/92: MIRU & PT equipment to 4000 psi. RIH w/CT & jetted out fill down to 10120' MD. Pumped 6 bbls CaCO3 slurry to spot an isolation plug over the lower perforation intervals located at: 10120 - 10162' MD (Z4) 10162 - 10205' MD (Z4) Top of plug estimated at 10100' MD. Ref. Log: BHCS 3/15/79. POOH w/CT. Rigged down. 2/23~92: RIH & tagged top of CaCO3 Plug at 10100' MD. 2/24/92: MIRU & PT equipment to 9300 psi. Pumped a Hydraulic Fracture Treatment, using 16/20 mesh & resin coated proppants, through the perforations above the CaCO3 plug at: 10062 - 10108' MD (Z4) Ref. Log: BHCS 3/15/79. 400 bbls Pre Pad @ 45 bpm, followed by Shutdown. ISIP @ 3390. pumping: 1200 bbls Pad w/ESL @ 45 bpm, followed by 700 bbls Crosslinked Slurry w/proppant stages @ I - 10 ppg, followed by Pumped: a) b) Resumed c) d) e) 319 bbls Flush, followed by f) Shutdown. Placed a total of 148,900 lbs of proppant into the formation. Rigged down. 2/28/92: Performed a CaCO3 plug / proppant fill cleanout down to 10118' MD. 3/16/92: Performed a fill cleanout down to 10204' MD. 3/24/92: Performed a fill cleanout down to 10200' MD. Returned well to fulltime production w/gas lift & obtained a valid production test. A coil tubing string is to be installed in the near future to improve hydraulics. RE£EIV£D JUN 2 2 ~992 Alaska Oil & 6as Cons. Anchorage // ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS ?~/-/ 14-2 ~_r2- 14-3 ?~'? 14-4 4-SA * ~14-5A ?~'~14-6 ~ *~* ~16-9A /~ ~ 16'9A ~/~ 16-13 ~-~ 16-15 ~-~/~ 16-21 ~~/ 16-22 ~/-f/ 17-8 3-3-92 PITS R-n 1, 5" Camco 2-10-92 Le-~k Detect Run 1.5" Camco 2-11-92 Prod Prof R,_n 1.5" Camco 2-29-92 Prod Prof R,_n 1.5" Camco 3-17-92 PITS R,_n 1.5" Camco 2-13-92 Jewelry R.n 1, 5" Camco 3-12-92 PITS Run 1, 5" Camco 2-24-92 Jewelry R,_n 1, 5" Camco 3-16-92 Prod Prof R;m 1.5" Camco 2-25-92 Prod Prof R~_m 1, 5" Camco 2-24-92 Prod Prof R,_n 1, 5" Camco 3-8-92 PITS Run 1.5' Camco 2-26-92 InJ Profile R-n 1.5" Camco 2-20-92 PITS R,n 1, 5" Camco Pleue sign and return the RECEIVED BY ~ Have A Nice Day! 8onya Wallace ATO-1529 attached copy as receipt of data. R E C E IV £ D APR 3 0 1992 Alaska Oil/& ~.a$ Con~. G~.mmi~.~i.on APPROVED~ffz~__ Anchorag, ~s~ 92080 # CENTRAL FILES # CItEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO The correct well name for this log is 14-5A. The correct well name for this log is 16-9,s_ ARCO Alaska, Inc. P.OJ3ox 100360 Anchorage, Alaska 9~510 DATE: 2-21-92 Perforation Tmcer-Chek Temp l~m3, ~' 5ch '~,,_ ~ r' Camc° Pleue. ~ and return the attached co~py u receipt of data. RECEIVED BY~ __~-~_~ Have A Nice Deyt ATO-1529 # CENTRAL FII, ES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLU~ PB WELL FILES R&D # STATE OF ~KA RECEIVED FEB 2 5 1992. Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-31-92 REFERENCE: ' / ~5-24 ~/~ ~~. 1-11-92 Prod Profile ~ 1, 5" Camco 1-11-92 Prod Profile Run 1, 5" Camco 1-10-92 Prod Profile Run 1, 5" Camco 1-10-92 Prod Profile Run 1, 5" Camco 1-15-92 CNL Run 1, 5" Sch 1-18-92 Collar Log Run 1, 5" Atlas 12-27-91 Prod Profile Run 1, 5" Camco 1-12-92 Jewelry Run 1.5" C_~mco 1-20-92 Tubing Cutter Run 1, 5" Atlas 1-13-92 Leak Detect Run 1, 1" Camco 1-12-92 Prod Profile Run 1, 5" Cnmco 1-17-92 CNL-GR Run 1, 2"&5" Atlas 1-9-92 -Prod Profile Run 1, 5" Cnmco 1-19-92 CCL/Perf Run 1, 5" Atlas Please sign and return the at,ached copy as receipt of RECEIVED By__~~~/~ ~~_________~ Have A Nice Da]ri · Sonya Wallace APPROVED .~w -' · ATO-1529 Trans# 9202~-' j # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL #PHILLIPS PB WEI~ FILES R&D # BPX # STATE OF ALASKA TEXACO * The correct tPI# for 13-2A is 50-029-20324-01. RECEIVED Alaska Oil & ~]as Cons. Commission Anchorage ARCO Alask~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-24-92 REFERENCE: ARCO CASED HOLE FINALS 12-29-91 12-31-91 12-31-91 1-3-92 12-2~01 Prod Profile Run 1, 5" Temp Survey & Tag Run Run.l, 2" InJ Profile Run 1, 5" Perf Breakdown/Temp/Sptnner Run 1, 5" Perf Breakdown Run 1, 5" Leak Detect Run 1, 5" Prod Profile Run 1, 5" Leak Detect Run 1, 5" InJ Profile Run 1, 5" InJ Profile Run 1, 5" PITS Run 1, 5" Prod Profile/Gas Lift Run 1, 2"&5" Prod Profile Run 1, 2"&5" Leak Detect Run 1, 2"&5" Leak Detect Run 1, 2'&5' Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Please sign and return~ .~ __~the attached ~p,y as receipt of data~ RECEIYED BY_~~~~_~ _ ~~- Have A Nice Day! _~~'~~/~ Sonya Wallace APPROVED ATO- 1529 Trans# 92016 / # CENTRAL FILES # CHEVRON D&M ~ # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL ~ # PHILLIPS PB WELL FH, F~ R&D # BP1/[ # STATE OF ALASKA TEXACO RECEIVED FEB 0 3 7992 A/aska Oil & ~ ~n$ Corn~i~:~a ARCO ALASKA, INC. ~- F'. 0 · BOX t (~0360 :'~_.~' ~-.~ ANCHORAGE, ALASKA 995t0 DATE' 9-~3-9~ REFERENCE: ARCO CASED HOLE FINALS 3-4° 8-25-9t TUBING CUTTER RUN t 3-3t~ 9-t-9t PERF RECORD RUN i, 4-t 5/ 8-28-9~ COLLAR RUN i ~-3~ 9-4-9i COMF'LETION RUN i, 7-6- 7-27-9t PROD PROFILE RUN t, t3-4- 7-25-9t PROD PROFILE RUN i, t 3-34- 8-29-9t COLLAR-PERF RUN t4-6- 7-27-9t GA~ LIFT RUN i t4-7~ 9-2-9t F'ERF RECORD RUN t, t4-i8' 8-3i-9t COLLAR-PERF - RUN i, t4-2~ 8-29-9t PERF RECORD RUN i, t8-t6- 8-3t-9t F'ERF RECORD RUN i, i 5" 5" 5" 5" 5" 5' 5' 2"&5' 5' 5' PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY ~__~ HAVE A NICE DAY! .$ONYA WALLACE ATO-t 529 ATLAS ~'CI-t ATLA~ $CH $CH ~CH CAMCO CAHCO AI'LA~' CAMCO $CF! ATLAS $CH ~CI-! DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON - MOBZ'L'. ... - F'HILLIP£ PB WELL FILES R & D · ,--" BF'X ~ STATE OF ALA~'KA TEXACO STATE OF ALASKA ALASKA' '. AND GAS CONSERVATION CC,_.,/IISSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1731' FNL, 1129' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 1089' FSL, 1323' FWL, Sec. 9, T10N, R14E, UM At effective depth At total depth 882' FSL, 912' FWL, Sec. 9, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-6 9. Permit number/approval number 78-65 10. APl number 50 - 029-20328 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10895 feet 9621 feet Plugs(measured) 10264' MD; 9096' TVD Effective depth: measured 10264 feet true vertical 9096 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 115' 20" 300 sx AS 115' 115' Surface 2644' 13-3/8" 5000 sx Perma II 2717' 2717' Production 10808' 9-5/8" 1000 sx Cl 'G' 10881' 9696' Perforation depth: measured 10062-10108'; 10120-10162'; 10162-10205' true vertical 8929-8968'; 8978-9012'; 9012-9048' Tubing (size, grade, and measured depth) 7", 29#, L-80, NPCT @ 5713' MD; 5-1/2", 17#, L-80, NPCT @ 5713-9807' MD; 4-1/2", 12.6~, N-80, NPC tail @ 9807-9814' MD Packers and SSSV (type and measured depth)Baker SAB packer @ 9801' MD; 7", Otis 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure JUL 1 ? t J91 Alasl{a 0il & 6as Cons. C0m~'tss'~0t~ ~nnhnra08 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Shut in. 378~ 305 586 Tubing Pressure 255 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 Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 728 DRR c: D. Warner, ATO-1479 Date SW JWP SUBMIT IN DUPLICATE DS 14-06 FRACTURE TREATMENT OF ZONE 4 DESCRIPTION OF WORK COMPLETED I/1 9/91: RIH w/CT to bottom & pumped 32 bbls of gelled sand slurry containing 5586 lbs of 20/40 sand & 300 lbs of 100 mesh sand. Flushed CT w/Meth-Water. Rigged down. 1/21/91: RIH & tagged top of sand at 10154' MD. Determined that additional sand was required. 2/21/91: RIH w/CT to bottom & pumped 30 bbls of gelled sand slurry containing 2800 lbs of 20/40 sand & 200 lbs of 100 mesh sand. Flushed CT w/Meth-Water. Rigged down. 2/22/91: RIH & tagged top of sand at 10096' MD. covered by sand placement, located at: 10062 - 10108' MD (Z4) 10120 - 10162' MD (Z4) 10162 - 10205' MD (Z4) Open perforations covered, or partially Ref. Log: BHCS 3/15/79. 2/24/91: MIRU & PT equipment to 8500 psi. Pumped a Propped Fracture Treatment, using carbolite proppant, through the partially uncovered perforations at: 10062- 10108' MD (Z4) Ref. Log: BHCS 3/15/79. Pumped: a) b) 374 bbls 50# Pre Pad, @ 48 bpm, followed by Shutdown. ISIP @ 3846. Resumed c) d) e) f) pumping: 2500 bbls 50# Pad, @ 55 bpm, followed by 716 bbls Slurry w/proppant concentrations of 0 to 8 ppg, followed by 315 bbls Flush, @ 55 bpm, followed by Shutdown. Placed a total of 126,400 lbs of proppant into the formation. Rigged d°wr~ ~~ IV ~ 3/2/91: JUL 1 ? t991 Performed sand / proppant fi{{ c{eanout. Alaska 0ii & Gas Cons. ;Anchorage Returned well to fulltime production & obtained a valid production test. A new gas lift design is scheduled to be installed in this well in the near future. L. Iii: :"::',, l<: ):) :i"]" E C: 'F .[ [) N F:. U :"-.! 'i , ::!.: :: Z N ,.J E C 'T' ]i C) N F:' R U F: ]] l... E !::'.: U N '! , 5. :: C C) !... L. :':':',. F..' i:~:..'...i N 'i., '.!i:: ~' !20 J... L. F'~ F;.'. /!::' E F;..' F' h..' i..j N i .: 3 :' C: il)L.. L.. A F;:./F: Iii. F;..' F:' i:,:: ~ i',.i :i : ~:..,,,: : ,; ,...' ']" E H F:' E F;.: A "f' U F;.'. E h.:,'-...,' r...~ 'J , 5: :' j::, i:;.., r') i() l.J C: ","' .i. r'i N F-" F;: f') F' i[ ~ '::' "' ,...t... Fi:i.jN 'i ,.:::: :' .............. C O I... L. A i;.'. /F:' E F;..' F' F.: U i',! 'i: '.ii: ": F' ! "i' ,? F;:. i,J N i ...5. :' 1:~` J::. h.: t.. ,,3 .< K .0 W N / T E M J:-' E F.: A T t.j R [il / ,'<..: F:' I N iN E F,' i;.." LJ iH i , i:.!;" C: i.')L., i... :'-"."~ !:L: J:,: U N'!: ii::. :' ill; C 1... i.,.: ~ ' .,-,t 'i '5 :' 'T' !iii i"i F' Iii] F;..' A ]" LJ FL'. Iii] / S F' I N N Iii: I:;,' F;.: U Ni: 5-" i[ i".] J E (]: "J" :[ [i) i"-.! W /Ii]~. ]:;.: C: [} J:~ F,' E L A T .[ O N t;,' U N'i :.'.!!::" iii N,..I E E:'i" ]: ~':) N W / C.; F.'. C: O R F: E L. A T I O N F;..' LJ i'-.4 i , 5. '"' i...EAK DETECTI[)N F..'UN 'i, 2" (:;. A ::-.; I... I F'"i" ;ii,' LI R V l:i: Y R U N :i , :i::" ...'.':,... 5:" F'L. EA,~.'Ii~ ,?IGN AND I";,'Iii;TUF;,'N THE A'Ti"ACHIZD COF'Y A,~2 IRECEIF'T (]F' DA'i"A~ :',, i::. C: iii] I V E I) B Y . ..................... 1'-t A V Iii: A N I C; E ]() ::.': Y ! ,?;HARON WII...,S'ON AT'O .... 1111::29 L. A:~ i'l L., i...~ C :~:'~ ~.."~ C U {l; ,~:', !v:. C' C. A 'i" J... Fi':.' ,1':.' A i i... A J ~ ,..: .. . ...... i"! i !...i"{d:. L; A ('.'~ L.; ~'::'~ i' i... :':':'~ ,'i{." ,.....~ ..... ~ .... i.... !;4 f"i L.- {.J ...... :...~ ...... i.... i";i PI L: U :':':',, ~ L A "" ~':':',' r'"i C r'. A h i"l: !"i l..: .... I) I ,S' "1" I:;.: I BLJ 'T' ]1 ON ? ..,I:__Nri~AL I: I..E,',; .11. l' J' .... J ~,. ...l'-iE'. VRE]N D & M · .,.'"' r:i:XTEN~'ICJN FXF'LORAI"ION · ,,"-EXXON H ~'::~ I','. A T' H CJ N :,~: i"i (:] E-: :1: I... F:' i..i I L L ! f:' ;"::.! F'B. 'IAiEi_..L. F ]:LES I;: & · ~: B F: X ST'AlE Ul:: AL_A,?:.'KA 'J' E: X A C [3 RECEIVED Alaska Oit & GaS Cons. commission Anchorage ANCHORAGE, ALASKA F,' E F Ii:. F,' E N C E ' A R C 0 C: A S E D H 0 L E F: I N A L. S' .._t .... i B 2-25 .... 9t "-3-.. '.S 3'-" 3'- 9 t · -4-' t :? 2-" '2 4 .... 9 -4? .... 3 3 '"-'.ii: "- 5" i "9 .... 4 0 3-'- t -' ~? i '"'4'~ .... 4 '? 2 - 2'7'- ~ "'~:~ 47 ".~"""~ '?- ° t · .... n.. .,.'.,,.' -"~'~, '"' 4 '?~..."~" ~~., ''~ '7 .... o · ~.9 .-.47 .3-4-9t --4~; ..... 48 ~-.."~ .... ~... ''> P.,, "" "? "~':J;' ..... 4 :i!i'. ,:.."~ '"' ~... ''~ iii .... "? ~' i :i!:'.--98'2'.'. 2'5 .... c,;'. ~l 3 .... "?F.~ 2--25- ..... '"..,'t · ' "Y t"~ · ""I, ,:~ .... ;' 8 ~:"~. '"' ,..: ''~ .5. "" o, '--4 4 .... /, "~ .... 23 .... ~.? ... "'-t 4"":.13 t ..... t""~7t '"4 z ..... :iii "~ ''~' ~ -.,. '"' ,... .... '~ i ,,..j F:' D K -' t O 0 ,,..' G R / C.' C I... I) I !::' F:' Ii"' I::: [il N'l" I A I... T Iii] N F:' Iii R A T LJ i::: lei F:' D K "" t 0 (~ / D I F:' F., CCI !:<' i:( .? I () f-tA & F:' 0 Ii:,' C) C[]LLAI;: CCL C 0 !_ L. A F:,' / F:' El F: F:' CCL. GF:/CL')L.L. AR 'CBT C E T F'F::ODLJOl'I[.tN F:'ACKER CBT C liil T C; F:: / C: 0 I... !... A F:,' C N L - T H E] I:;,' ivi A I... C: N L. '"' lie F:' 11" t"t E F;: H A !... D LJ A L. I N ID U C 'i" I 0 N C 0 I... I... A F.'. CCL RUN t, *~'.,." H, Uf,! t , ., RUN t , ., lq:UN t,., RUN t, 5" R U N RUN i , 5" RUN f, 2"&5" R UN t , 2" & 5" 'RUN RUN t ~ 5" RUN' t ~ ' RUN t, 2"&5" .,. RUN 35, 5 RUN 35, '5" I;:UN t , ., R U N RUN I::'I...E:A:i';E: S:[(:~H AND F;..'Iii:"f'LJF~N 1"FIE: ATi"ACHEiI) C:[)i::'Y AS' F~E:C;EJlF'I" CJI::' DATA. I"! A V F.!: ('.1 N I C I!i: I) A Y ! A I::'F:'l:~rJ V E. I) ~~ A TL. AS' A'I'I_A:9 A'T'L. AS' Afl_AS ATLAS A '1" I.. A ,S' A'I'L.A,S' 5' C H SCF! S C !.-I SCH SCH S C: H SCFI S C !-.I SCH ATLAS FIL.,S; Al'LAS I) I S 1' R I B U 1' I 0 N · ..'"' CE:N'¥RAI... FILES :I~ C I"11E V I:( 0 N I;, & Fi .,,.'" E X 'T' E: N S I 0 N EL X F' L. £)I:~ A 1' I 0 N · ~ EXXON HAI:~:~I'I..ION .,.'"' l't [3 B I i.. *.' T'FIE: AI::'I~ F'OR t6-8 :[$ 50-029-20549. ~: F' I"1 ]: L L I P S F'B WELL F ]:LES F,' & I) ~: BF'X · .- :~l'Al'E OF ALASKA TEXACO RECEIVED '~AR 1 8 1991 Alaska 011 & GaS Cons. commission Anchorage A N C t.-i 0 F::. F.':'; [; E, A L. A S I< A !:~: ti!: F:' E R Iii: i",! C Iii: ' A R C 0 C A,S' E D I"10 I... !ii: I::' I N A i... F:' R 0 0 U C 1"I 0 i'.~ R U N .t , !5" C C I... F;',,.. ,,:~ I ~,' i , ..,':~" I::'t:;..' [) ¥) t I F'.' T ][ f'i i,,I I:;.:t I fq .i , ,:~', C 0 I... !... A F;.:/'" F:' Iii: :.:;.: F:' R U N i , '.ii'" t:.; R I:;.: U N. i , ....-'="" F:' Iii: F;..' F:'.'~ F;: A T' ]: i'i N R t t i',..! i '::"" ........... j D 5' N / G F;.:,.'" C C t... I:,..' U N i !5" D S N i:;.'. U N :i , '.5" ~;' il D,%' N R U i",! '~ , ...., 'i"BG CLIT'TIi-:p. . ., F;:UN i, "~'".., I... Iii: A I< D E'Ti!i: C': T' :1:0 N R U N i, 2 :~ F:' F;..' C) D U C 'i" I 0 N 1-..'. U N ~ , .5" I::' F;..' 0 D U C 1" i 0 F! i:,.'. U N i , 5" D£N RUN i, 5" F' D I< --. i ~.':~.. ~':~,, ..,': D :t: I::' I::' . C 0 I:;,' R ,.~.'~" ]: C M A iL... .l:-' O. R 0 R U N i , !5-" F:',':;', F,.... D U C T' I 0 N · R U N i , '"~'..;" .., :': ii:" .. N 'T' i--I Ii.:. A T T A C I--I Ii!: D C:: 0 F' Y A $ R E C E. I P T 0 F D A I'A. F:' I... Ii!: A,S' ii: c, I C; N A N D I, I l I J R F;:.E:c.r:i:!VE:D B'T' :~~. ......... '~"'"~ !..!AVE A NIC:E DAY! D I ,~ ! F. I B U T ]: 0 N C E N T R A I.. F I L E S '"' C H E: V R 0 N 11' EXT£NSION E:XF'L. ORAT I Oi'l .- ExxOn' 'Ir MARATHON :~ HOB'ri-' F' I..! :!: L L I F' S F-'B WEt...L. F'ILE:S R & D :~: B I::' X · '~ STA1E DF ~-~LA,','I<A TEXACO C 0 R R Ii!: C T E DA F:' I ~ F' 0 R 9- 4 i I S 5 ;3' "" ':':') 2 9'"' 2 2 ~ 5 4, "l I ~"l .... CC) RI;,'EC'FE:.D RLN I>AI'E FOR t,::. t IS t2'-'i'-9~, CORI:;,'EC::I'ED BO'T'TOH LOG INTERVAL FC)R i2--26 ]:5' RFCEIVED FEB 2 7 1991 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ;ION ALASKA~ .AND GAS CONSERVATION CQ /IISS REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 9951O-O36O 4. Location of well at surface 1731' FNL, 1129' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 1089' FSL, 1323' FWL, Sec. 9, T10N, R14E, UM At effective depth At total depth 882' FSL, 912' FWL, Sec. 9, T10N, R14E, UM 5. Type of Well Development X~ Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-6 9. Permit number/approval number 78-65/90-400 10. APl number 50 - 029-20328 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10895 feet Plugs(measured) 9621 feet Effective depth: measured 10264 feet true vertical 9096 feet Junk(measured) Casing Length Size Cemented Conductor 115' 20" 300 sx AS Sudace 2644' 13-3/8" 5000 sx Perma II Production 10808' 9-5/8" 1000 sx CI 'G' Measured depth 115' 2717' 10881' True vertical depth 115' 2717' 9696' RECEIVED Perforation depth: measured 10062-10108'; 10120-10162'; 10162-10205' AUG 2 71990 true vertical 8929-8968'; 8978-9012'; 9012-9048' AJaS~ ~0,JJ & Gas Cons' Tubing (size, grade, and measured depth) 7", 29#, L-80, NPCT @ 5713' MD; 5-1/2", 17#, L-80, NPCT @ 5713-9807' MD; 4-1/2", 12.6g, N-80, NPC tail @ 9807-9814' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9801' MD; 7", Otis SSSV @ 2035' MD 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 Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Shut in. 261 129 205 Tubing Pressure 191 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 Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date ~/Z. ~/~ SUBMIT IN DUPLICATE ~nR I~I. IR ~...I ~n~h~.r_ ATO-1478 SH DS 14-06 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER SHUT-OFF 6/10/90 : MIRU CTU & Stimulation Equipment. PT equipment to 4000 psi. Loaded wellbore w/251 bbls Crude, then RIH w/CT & washed perforations at: 10062 - 10089' MD Ref. Log: BHCS 3/15/79. 10089 - 10108' MD 10120 - 10157' MD 10162 - 10205' MD Pumped: 59 bbls 12% HCI w/10% Xylene. Flushed w/Diesel & Meth-Water. POOH. Rigged down. 6/11/90 : RIH & pulled GLV's. Installed DGLV's. POOH. RD. 6/13/90 : A CTU Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/540 bbls of seawater. Pumped 122 bbls of cement squeezing perforations at: 10062 - 10089' MD Ref. Log: BHCS 3/15/79. 10089 - 10108' MD 10120 - 10157' MD 10162 - 10205' MD Placed 90 bbls of cement behind pipe, at 2250 psi maximum squeeze pressure. Contaminated cement w/Biozan, and jetted cement out of wellbore. POOH. RD. 6/22/90 : RIH & pulled DGLV's. Installed GLV's. POOH. RD. 6/30/90 : Reperforated: 10062 - 10108' MD 10120 - 10157' MD 10162 - 10205' MD Added perforations: 10157 - 10162' MD Ref. Log: BHCS 3/15/79. Ref. Log: BHCS 3/15/79. Placed well on production and obtained a valid production test. ARCI3 ALAZ'KA, INC. F'.O. BOX iOOf60 ANCHORA(;E, ALAS'KA 995i0 DA'rE ' 7-'7-9(.3 I.';.~F.~F'EI.';..'Ei".~.CE' ARCO CA~';'Eb HOLE FINALS' i --j '"' ..,: -..':~a-..~t.~ COI_.LAR RLIN J , i-28 6"-ii--90 D;~'N (2 i/8') F..'UNi, i-'28 6--i i-9(') DgN (.'3 ~/8" ) RUN i , 2-25 ,:'S-9"-9(:~ D.'~N (2 i/8') RUN i, 2-26 6-9'-90 D:i:N (~.~ 3/8' ) RUN i , ..,~"-i 4 '?-2-96; COLLAR RUN i , 9--i 6 6--2~$-9'3 F'FRF' RECORD RUN i , t 2- t '7--i --ge COLI. AR RUN t , t4-6 6-~0'"90 CCL/F'ERF' RECORD RUN i, i4'-i6 6-29'-9G CCL/F'ERF RECORD RUN i ~ i 6""6 6-25-9G COLLAR RUN t , F'I_EA,'~E $IC:N AND RE"FtJRN THE ~OF'Y A£' RECEIP'F OF DATA. REE:'EIVED BY HAVE A NICE DAY! ,JUL. 1~0 1990 SALLY I'iOF'F'ECI<[-:R Alasim Oil & 6as Gofis. APPROVED ~. A'F 0-- t ~ 2 9 Anchorage 'r R A N ~;' :; 9 (~." '?' L~ A f' L.A 5.' H I_ ::--: H L.,?;' I.'i i._ :i".: A f'l..Ag R f't_ A;2' A'I'LAS' A T L A g A'f'LAZ I) I ~'TR I BU1 I ON CENTRAL FILE&" .I~ PHILLIPS CHEVRON F'B WELL FILE,.',? D & M R & D EXTENSION EXPLORATION ~ BPX EXXON ~ ,~IATE OF ALAS'I<A MARATHON TEXACO MOBIL P.O. BOX ~,.':}6'360 ANCHORAGE, AL.A~KA - DATE' 5/25/9'3' R E F' E R E N C E · A R C 0 CASED HOLE FINAL.~ RECEIVED 4-:-t.;.:: .,~".-7,- o~.'.~, .. IN...IEC'I"I ON. F. ROI- ].LIE RUN t 5-2 .'5- 7-- 9 ~.~ 'I'EMF' ,~ C-/R F;:UN D-.:,.'..~5 t"2--t .3-89 TVD BHC'. ACf. jLI,, K./R RUN i., "' '~' 2- ;]-9'3' ~ ........ ', .::>'r',...5 t t '¥VD ..,UMI- NEU'f'RON G/R RUN 5-.25. t2-t;!-90 'l'VI) DUAl_ INDUCTION G/R RUN t, 6-.-.t 8 5-6-90 F'RODtJCT£ON PROFILE RUN 'J., 7'"'~t .7, 5-t 9--90 PERF REC'.C~RD RUN i , 9..-38 5-4-90 STATIC 'I"E MI:' RUN i~:.6 ._ 6 ..,':"~ -' 7 - o, C,. F' U H F:' - I N T E M P f:,. U N I 3-5 5-4-90 PRO..,,UC 1 ION F'ROFII_F-' F:UN 13,--9 5-3-96, INJECTION PRCIFILE~ RUN 'i , t3-t2 '3-3-90 PF:OD,. F'F:.'OF'I_'I_E P'.[T3." RUN t 3-29 .5-5-90 F'RODLICTION F:'ROFIt...IF RUN t , t4-6 4:-29-90 PRODUCTION F'I~OFII_E RUN i, f7--t 2 ~:--'o-~A LEAK DE£TIECTIrlN RUN t 8'-7 5-4-96; F'UMP-IN I'EMF' RUN ~ , 5' 5' 5' CAMCO (]ANCO A'f'LA.~ ATtzA~ AFL. AS CAHCO ~CH CAMCO CAMCO (]AMC() C A M C 0 (]AMC(] CA~CO CA~CO CAMCO ''' ,' C; F'I..EA,~E ,~IGN AND RETUEN THE ATTA HED COPY A~ REC;EIF'T OF DATA RE~,EIvED BY 14AVE A NICE DAY! 3ALLY HOFFECKER A'I'O- ~t ':~9 APPROVE~ 'FRAN$:~ 9020,I-) DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL '"' I"' H I 1_ L I F' $ 1::'}3 WELl_ FILE,S' R & D · ,,- BPX &"f'AI"E OF ALASKA TEXACO STATE OF ALASKA ALAS; ~ILAND GAS CONSERVATION~, ~MMISSION 0 ~ APPLI 'ATION FOR SUNDRY APPROVALS Abandon ~ Suspend ~ Operation shutdown Re-enter suspended well 1. Type of Request: Alter casing Repair well Plugging , Time extension Stimulate Change approved program Pull tubing Variance Perforate X Other , X 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O, Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1731' FNL, 1129' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 1089' FSL, 1323' FWL, Sec. 9, T10N, R14E, UM At effective depth At total depth 882' FSL, 912' FWL, Sec. 9, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 12. Present well condition summary Total depth: measured true vertical 10895 feet Plugs(measured) 9620 feet Effective depth: 6. Datum of elevation(DF or KB) 73 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1'4-6 9. Permit number 78-65 10. APl number ~ 50 - 029-20328 Perforation depth: 11. Field/Pool Prudhoe Bay Oil Pool measured 10264 feet true vertical 9096 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 115' 20" 300 sx ,AS 115' 115' 2717' 2717' Sudace 2644' 13-3/8" 5000 sx Perma R E (~ E IV E D10881, Production 10808' 9-5/8" 1000 sx Cl 'G' 9696' MAY 1990 ~as.~.Oil & 6as Cons. Comm~iQ~ measured 10062-10089'; 10089-10108'; 10120-10157'; 10'162-10205' true vertical 8929-8952'; 8952-8968'; 8978-9008'; 9012-9048' Tubing (size, grade, and measured depth) 7", 29#, L-80, NPCT @ 5713' MD; 5-1/2", 17#, L-80, NPCT @ 5713-9807' MD; 4-1/2", 12.6#, N-80, NPC tail @ 9807-9814' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9801' MD; 7", Otis SSSV @ 2035' MD 13. Attachments Description summary of proposal Detailed operations program X I 15. Status of well classification as: Oil X Gas Suspended Service 14. Estimated date for commencing operation June 1990 16. If proposal was verbally approved Name of approver Date approved BOP sketch X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~''' ~ Title Sr. Area Operations Engineer FOR {~OMMI~ION U~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance .... Mechanical Integrity Test Subsequent form required 10- ~': ~ ORIGINAL SlGNEO BY LONNIE C. SMITH Date Approval No. Fo...~~) P1{14-6)W1-3 ,~ ....,.C.,o..F~_,i~s~p n e r Retprned Approved by order of the Commissioner Form 10-403 Rev 06/15/88 RRq M.IR ~.~: J. Gruber. ATO-1478 Date SUBMIT IN TRIPLICATE DS 14-6 Non Rig Workover Water Shut Off Work Scope Workover e . Objective · Repair a confirmed channel down to the aquifer. Make a slickline tag to verify PBTD. Obtain production test. Acid wash the perfs and channel. Obtain second well test. Perform a high pressure (3000 psi) squeeze with 80 bbls of cement to isolate the perforations from 10062'-10205' (BHCS). Reverse out the contaminated cement. Spot TEA accelerator across perforations. Reperforate after 4 days as follows: 10062'-10108' 10120'-10157' 10157'-10162' 10162'-10205' Other Well Information Current status: Shut in. Expected static bottomhole pressure: 3800 psi. @ 8800' SS Expected fluid in wellbore at reperforation: seawater. RECEIVED 2 z; 1990 Alaska Oil & Gas Cons. Commission ~ ~chorage 2 C0~L£D TUBtNt3 UNIT BOP E0U l PMENT 1. 5000 PSI 7" WELLHEAD CONNECTOR IrLANOE 2. 5000 PSI4 1/16" PIPE RAHS 3. 5000 PSI4 1/6" HYDRAULIC SLIPS 4. 5000 PSI4 1/6" SHEAR RAMS 5. 5000 PSI4 1/6" BLIND RAHS 6. 5000 PSI4 1/16" STUFFING BOX H]REL]NE BOP EOU]PHENT _ 1. 5000 PSI 7" WELLHEAD CONNECIOR rLA~G£ 2. 5000 PSI WlRELIN£ RAuS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE P^CK-Olrlr ARCO ~.,,I_~KA, INC F'. O, BOX ANCHOF,'AGE, ALA2KA ,~'i DATE · ._~- 7.- o ~, REFERENCE~ ARCO CASED HOLE FINAL~ 3-t6 t-7-9(:~ INJECTION F'ROFILE RUN 4-27 1~-~8-~, INJECTION P!~:OF'rLE RUN i, ..~. 7-')~ t-q:-oO PRODUCTION PROFILE RUN i q" 9-~ ~ -8-o0 PRODUCTION PROFit_E RUN ~5-2~A ~-~-9,~ INJECTION F'ROFILE RUN ~ ~' ~ 4-6 ~ -4'-9~.~ F'ITZ RUN ~4-2~ 1-~'-~:~:~ I~.JEUTION PROFILE RUN ~4-36 ~-,~'-9~ INJECTION F'ROFILE RUN t., 5" ~5"-~ ~-~(~-90 PRODUCTION P~OFIi_E RUN ~, '5" ~8-24 ~-i~-9(~ F'RODUCTiON F'ROF'ILE RUN PI..EA,~E ,~IGN AND RETURN ]?'HTi ATTACHED COPY AZ RECEI'F'T OF DATA, SALLY HOFFECKER~_EB_gl~90 .-. ATO-~ 529 ,lmi~--or&Gas~~s'~°~s~'~ -' .DISTRIBUTION AF'F'ROYED _~__ CENTRAL FILES CHEYRUN EXTENSION EXPLORATION EXXON MARATHON MOBIL · F'HILLIF'E - F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO THE CORRECTED WELL NUMBER I$ ~-23A, NOT CAMCO (.· *...*x .- ..~rlL;U CAMCO C A M C 0 CAMCO CAMCC'; CAMCO CAMCO L:AMCO ARCO Alaska, Inc! Prudhoe Bay ¢ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 30, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re' DS 14-6, Approval No. 9-908 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/RAC/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 14-6)W1-3 RECEIVED ~k~.Oil.&,.Gas Cons° "~nchor~. Commi, sio[~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKL AND GAS CONSERVATION REPORT'OF SUNDRY WELL OPERATIONS 1. Operations performed: operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1731' FNL, 1129' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 1089' FSL, 1323' FWL, Sec. 9, T10N, R14E, UM At effective depth At total depth 882' FSL, 912' FWL, Sec. 9, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-6 9. Permit number/approval number 78-65/9-908 10. APl number 50 - 029-20328 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10895 feet Plugs(measured) 9620 feet Effective depth: measured 10264 feet true vertical 9096 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 115' 20" 300 sx AS 115' 115' Sudace 2644' 13-3/8" 5000 sx Parma II 2717' 2717' Production 10808' 9-5/8" 1000 sx CI 'G' 10881' 9606' Perforation depth: measured 10062-10089'; 10089-10108'; 10120-10157'; 10162-10205' true vertical 8929-8952'; 8952-8968'; 8978-9008'; 9012-9048' Tubing (size, grade, and measured depth) 7", 29#, L-80, NPCT @ 5713' MD; 5-1/2", 17#, L-80, NPCT @ 5713-9807' MD; 4-1/2", 12.6#, N-80, NPC tail @ 9807-9814' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9801' MD; 7", Otis SSSV @ 2035' MD 13. Stimulation or cement squeeze summary ~'~ E C E iV E D Intervals treated(measured) See attachment Treatment description including volumes used and final pressure Aiaska .0il & Gas Cons. C0mmissir~ 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae Production or In!action Data Anch0ra~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 405 134 73 -- 209 359 596 5785 -- 244 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 ~¢:~-)~d~~ Title Operations Engineering Manager Form 10-404 Rev 06/15/88 277 R.A. Clausen Date SUBMIT IN DUPLICATE Sequence of Events STIMULATION SUMMARY''~'~ DS 14-6 1 1/29/89 , Pull K valve HCl tubing wash with 200 bbl hot water and 48 bbl 15% HCl pumped at 7 bpm. with 240 bbl crude. Flush 12/1 thru 3/89 1. Changeout gas lift valves for dummy valves and load annulus with crude and diesel. 12/5/89 , 2. 3. 4. 5. 6. . 8. 9. 10. 11. 12. MIRU Dowell. Pressure test to 7200 psig. Pressure annulus to 3000 psig. Pump 50 bbl diesel at 9.6 bpm, 1950 psig. Pump 23 bbl xylene at 5.9 bpm, 2000 psig. Pump 10 bbl 15% HCI Start dropping 5/8" diam. ball sealers 1.1 Sp. Gr. Drop one every 2.5 seconds. Pump 270 more bbl of 15% HCI. Dropped total of 600 ball sealers. Pump rates were 10 bpm with pressure fairly constant at 1950 to 2000 psig. Pump 100 bbl of scale inhibitor solution at 12 bpm, 2500 psig. Pump 75 bbl of 2% NH4Cl water at 12 bpm, 2500 psig. Pump 192 bbl crude oil at 12 bpm, 2550 psig. Shut down pumps and surge well twice at the surface to remove balls from perfs. Pump 120 more bbl of crude at 8 bpm, 2600 psig. Pump 10 bbl diesel and shutdown. Wellhead pressure 1012 psi after 15 minutes. 12/25 and 26/89 1. Changeout dummy valves for live gas lift valves. Based on the high post treatment PI and water rate, the acid treatment created a channel to the water. CTU squeeze needed to correct water production. STATE OF ALASKA ALASK,~ 'LAND GAS CONSERVATION CL JVIlSSIO'N APPLICAwlON FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program 99510-0360 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 4. Location of well at surface 1731' FNL, 1129' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 1089' FSL, 1323' FWL, Sec. 9, T10N, R14E, UM At effective depth At total depth 882' FSL, 912' FWL, Sec. 9, T10N, R14E, UM Operation shutdown Plugging Pull tubing Variance 5. Type of Well Development X Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate Perforate x Other 6. Datum of elevation(DF or KB) 73' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-6 9. Permit number 78-65 10. APl number 50 - 029-20328 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10895 feet Plugs(measured) true vertical 9620 feet Effective depth: measured 10264 feet true vertical 9096 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 115' 20" 30 Sx AS 115' 115' Su dace 2644' 13-3/8" 5000 Sx Perma II 2717' 2717' Production 10808' 9-5/8" 1000 Sx CIG 10881' 9606' Perforation depth: measured 10062-10089'; 10089-10108'; 10120-10157'; 10162'-10205'; true vertical 8929-8952'; 8952'-8968'; 8978'-9008'; 9012'-9048' ,Aru::h0ra~ Tubing (size, grade, and measured depth) 7", 29#, L-80, NPC Tubing @ 5713' MD; 5-1/2", 17#, L-80, NPC Tubing @ 5713'-9807' MD; 4-1/2", 12.6#, N-80, NPCT Tail @ 9807-9814' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 9777' MD; 7" Otis RPB SSSV @ 2035' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x feet 14. Estimated date for commencing operation 15. Status of well classification as: December 1989 16. If proposal was verbally approved Oil x Gas Suspended Name of al)prover Date approved Service 17. I hereby,g~ertify that the foregoing is true and correct to the best of my knowledge. Signed /. ~'~ .~~:~~ Title Operations Engineering Manager Date FOR COMMISSION Ual= ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. /~..., Plug integrity BOP Test Location clearance ~ Mechanical Integrity Test Subsequent form required 10- '~/-+ ~,pproved COPY Returned,~ - Approved by order of the Commissioner LONNIE C. SMITH Comm ss/~"m'5~er Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE PROPOSED PERFORATING DS 14-6 ARCO Alaska proposes to add perforations in the DS 14-6 producer in the Sag River formation of the Prudhoe Bay Unit. All wire line work will be done through 5000 PSI working pressure BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The purpose of the proposed perforating will be to provide effective drainage of the Sag River reserves. Ref: BHCS 3/15/79 Proposed Perforation Interval' 10046-10058' MD 5 ! ! 1. .5000 PSI 7" WELLHEAD CONNECTOR FLANOE 2. .5000 PSI WlRELINE: RAMS (VARIABLE SIZE) 3. .5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE'PACK-OFF H I REL I NE BOP EOU 1 PHENT ARCO Alaska, Inc. Prudhoe Ba~'~,~igineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager O R I G I IV li [. October 10, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-6, Permit No. 78-65 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/RAC/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 14-6)W1-3 as/ a 0il Oas Cons. ~nCflorage C°~lSeloe ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK,~ 'iLAND GAS CONSERVATION C¢ MISSION 0 R I G I N A [ APPLICATION FOR SUNDRY APPROVALS 1. Typeof Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well - Plugging Time extension Stimulate X Change approved program Pull tubing Variance Perforate Other 5. Type of Well Development X Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1731' FNL, 1129' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 1089' FSL, 1323' FWL, Sec. 9, T10N, R14E, UM At effective depth At total depth 882' FSL, 912' FWL, Sec. 9, T10N, R14E, UM 6. Datum of elevation(DF or KB) 73 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-6 9. Permit number 78-65 10. APl number 50 - 029-20328 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10895 feet Plugs(measured) 9620 feet Effective depth: measured 10264 feet true vertical 9096 feet Junk(measured) Casing Length Size Cemented Conductor 115' 20" 300 sx AS Surface 2644' 13-3/8" 5000 sx Perma II Production 10808' 9-5/8" 1000 sx CI 'G' Measured depth 115' 2717' 10881' True vertical depth 115' 2717' 9606' RECEIVED Perforation depth: measured 10062-10089'; 10089-10108'; 10120-10157'; 10162-10205' ocr ~, 1_ ~989 true vertical 8929-8952'; 8952-8968'; 8978-9008'; 9012-9048' Alaska 0|i & Gas Corls, Comllll$$brl Anchorage Tubing (size, grade, and measured depth) 7", 29#, L-80, NPCT @ 5713' MD; 5-1/2", 17#, L-80, NPCT @ 5713-9807' MD; 4-1/2", 12.6#, N-80, NPC tail @ 9807-9814' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9801' MD; 7" Otis SSSV @ 2035' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation October 1989 16. If proposal was verbally approved Oil x Name of approver Date approved Service 17. I hereby,,~ertify that the Loregoing is true and correct to the best of my knowledge. Signed ,~¢P'~~~~ Title 15. Status of well classification as: Gas Suspended Operations Engineering Manager Date FOR {~OMMIS~ION URI= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commissioner Commissioner Form 10-403 Rev 06/15/88 195 R. A. Clausen. 263-4538 J Approve, .o. Approved Copy Returned Date SUBMIT IN TRIPLICATE DS 14-6 Perf Breakdown Procedure ARCO 1. 1 e 1 Si Si Alaska Inc. proposes the following procedure: Perform a tubing wash with 3000 gal. of 15% HCI, 250 gal. of xylene, and 0.4% corrosion inhibitor. Pump the acid and xylene followed by 240 bbl of crude. Flow well back to the production manifold. Changeout gaslift valves for dummy valves. Load 7" x 9 5/8" annulus with seawater and diesel. MIRU pump trucks and transports. Pressure 7" x 9 5/8" annulus to 2000 psig. Pump the following fluids at 10 bpm. Maximum expected pressure is 2500 psig. 1. 20 bbl diesel to establish rate and treating pressure. 2. 24 bbl. xylene. 3. 10 bbl. 15% HCI. 4. 300 bbl. 15% HCI. Drop total of 600 ball sealers. 6. 113 bbl scale inhibitor blend 7. 100 bbl 2% NH4CI water. 8. 192 bbl crude flush. 9. Shut down pumps for 5 minutes to allow ballsealers to fall. 1 0. 120 bbl of crude at 6 to 8 bpm. 1 1. 10 bbl diesel flush. Immediately produce well. COILED 1UBIN0 UNIT BOP E0U ! PHENT 1. ~C)O0PSI ?" W£LLH[.AD CONNECTOR FLANG£ 2. 5000 PSI4 1/16" PIPE RAMS 3. ~)C)OPSI4 1/6" HYO~LK~ SLIPS 4. 5000 PSI4 1/6" SHEAR RAMS ~).5000 PSi4 1/6" BL. IHD RAMS 6. 5000 PSI4 1/16" STUffING BOX 4 HIREL]NE BOP EOUIPHENT i 1. 5000 PSI ?" W[LLHCAD CONN£CIOR £LANG[: 2. 5000 PSI WIR[LINE RAIDS (VARIABLE SIZE:) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF DATE: ?-i~-~ REFERENCE: ARCO CAMEO 1401..IE FINAl... ~ ..'?.--t e '~ ,ct ..... , 6-~...7-,...8 F';[T,.? RllN 4 , 5- t 7 7-4-B,.q. CNI... I;,'!..IN 2. 5 · FRT. "- ' II.,E./F;AMMA R'.AY R'!.IN o ~,9-,"l,'..~ ,6-25-88 TF]MF' "I , . ..o...~ . ,~i2-i6 .,Z:,-2,.'S-Sfi3 PRf)DIICTT. ON PROI:'T!...E RIIN 2, ~" 11t":'-":'9 ,4-26.-8~ F'I:;,'FIDIIr;TI.F. IN F'R(.')F.T.I..tF/.F;.AMMA RAY RIIN '') "'--" ..;., ..." ............... o~-,. ,~ .~" :.'f,-i R. .A-24-RR ~AMMA RAY./CFII..I...AI-i~ R!!t'~ i · 4-6 A-~5-8!!l COI...I..AR LOG RUN 'i , 5" .... '...N J: .. 4-6 6-'~ 6- 8 8 F' :[ '1',? . I-~ll %" r-~E ,?,T. GN AN[) RETURN THE ATTAI]I.,IF'.T.) C,R..F'Y A,.~ RECE.I.'PT OF. DATA,. RECE:F. VED BY FIAVE A NI..,F. DAY! FEG.F,Y BENNETT .. ," .,.:. ! TR A N..S' ~884A4 ..11 T 2 T R T ~ !.1T :[ 0 N '"'.,.CENTRAl... .....F.TI..E,S' "' ri '.,,-'"' CNEYR. N E×TEN..S' '1: RN F'XPI..ORAT T ON M AF,' ATI.~6.1N ~",: MO}'.', I I... P !--! l: !.. t.. T F' ~7 F'B WFt...!., FT.I..I.-'..,?.. " ~.,,." ,.~TATE 01:".. ALA~I<A ~.'" ('.'. A M Iq F1 CA M r.'..Fl.. CAMCO r.,AMCFI CAMr..R CAMCO T') .1' ,~ T !:;: T 1:'{ ! IT T I':] i',J fi 'T' '1'.% f-.' ~ H f'.' f'i fi T T,? f"l 'T' 'r .~' f'l 'T' 'r ~..'.' ARCO ALASKA, INC. P.O. BOX tGOJCG ANCHORAGE, ALASKA DATE: t-t2-88 REFERENCE: ARCO CASED HOLE FINAL i-22 t2-t~-87 ---- 5-t4 i2-t6-87 -~- 6-8 i 2- t i -87 ~ 6-tS t2-t2-87 ~6-t8 i2-t ----9-2 t 2-i 9-87 ~ 9-~ t 2-24-87 ~ 9-J t 0-~-87 ~ 9-~ i ~-~-87 ~ 9-5 i-5-88 ~9-14 t 2-t 9-87 ~it-t7 t2-t7/i8 ~ti-27 i2-i4-87 i~-2 t2-2~/24 ~t~-29 12-2~-87 ~i~-~ t2-i~-87 ~t~6~ t 2-28-87 ~ t4-1i t2-28-87 ~ 15-9 t2-27-87 ~t ~ ~ ti ~-87 t6-7 t2-26-87 t7-~2 ~ ~-~ ~-87 F'UMF'-IN TEMPERATURE SURVEY L. EAK DETECTION PRODUCTION PROFILE F'RODt.iCTION F'ROFII_E PRODUCTION PR~]FILE PRODUCTION F'ROFIi_E PRODLICTION PROFILE PFC LOG VERTILOG F'RODUCTION LOG ~TEF' RATE INJECTION PROFILE F'IT~ FLOWMETER PRODUCTION PROFILE F'RISM PRODUCTION F'ROFILE F'RODUCTION PROFILE F'RODUCTION PROFILE FLOWMETER SURVEY F'RODUCT~ON-PR~FT~ VERTILOG PRODUCTION PROFIL. E DIFF/TEMF'ERATURE/GR F'RISM RI!N RUN RUN RUN RI.IN RUN RL.IN RIJN RIJN RUN RUN RIJN RI.IN RUN RUN RIJN RUN RUN RUN RI.IN RUN RUN RUN RUN 11 5' 5" 5" 5" 5" _5' 5' 5' .5' 5:' .5:' 5' .5' 5' .5' 5' .5' 5' 5' 5' PLEASE RECEIVED BY HAVE A NICE DAY! PEGGY BENNETT AT0-t529 SIGN AND RETURN COF'Y AS RECEIPT OF DA'FA~ ~ 011 & G~ Cons. Co~i~ioD TRAMS ~88026 ~ AF'F'ROVED DISTRIBUTION CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO WAI WAI $CH CAMCO CAMCO CAMCO CAMCO ATLA~ CAMCO CAMCO CAMCO CAMCO CAMCO WAI CAMCO WAI ATI. A~ CENT" .,. RAI_. I-" I I.. E.9 " F'H I l..l_ I F',? CHEVRON F'B WELL FIL..F.? I) & M R & I) EX'TEN.? I ON EXF'LORATION -". .?AF'C EXXON . ~ ,~TATE OF AI._A,~KA MARA'FHON ,.'"' TEXACO MOB I I... ARCO Alaska, In[ Prudhoe B~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 5, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-6 Permit No. 78-65 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/PVL/jp Attachment cc: Standard Alaska Production Company Pi(DS 14-6)W1-3 RECEIVED Alaska 0il & Gas Gens. Commission Anchorage WELLS/93 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAk,_,A OIL AND GAS CONSERVATION COI~..~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1731' FNL, 1129' FEL, Sec. 9, TiON, R14E, UM At top of productive interval 1089' FSL, 1323' FWL, Sec. 9, T10N, R14E, UM At effective depth At total depth 882' FSL, 912' FWL, Sec, 9, T10N, R14E, UM 11. Present well condition summary Total depth: measured 10895 ' feet true vertical 9620 ' feet 5. Datum elevation (DF or KB) 73' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 14-6 8. Approval number g. APl number 50-- 0?9-?0328 10. Pool Pr~dhoe Bay Oil Pool Effective depth: measured 10264' feet true vertical feet 9096' Casing Length Size Structural Conductor 115 ' Surface 2717 ' Intermediate 10881 ' Production Liner Plugs (measured) Junk (measured) Cemented Measured depth 20" 30 Sx AS 13-3/8" 5000 Sx Perma II 9-5/8" 1000 Sx C1 G Perforation depth: measured 10062-10089'; 10089-10108'; 10120-10157'; 10162-10205' true vertical 8929-8952'; 8952-8968'; 8978-9008'; 9012-9048' ~bing(size, grade and measured depth) 7" 29# @ 5713, 5½" 17# @ 5713-9807, 4½" 12.6# @ 9807-9814 Packers and SSSV(type and measured depth) Baker SAB Packer @ 9777' MD; Otis SSSV @ 2035' MD Feet True Vertical depth 115' 115' 2717' 2717' 10881' 9606' 2. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Alaska 0il & 8as Cons. C0mmjssj0f? Anchorage Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operation Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 830 402 110 800 266 1596 265 376 840 265 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] is true and correct to the best of my knowledge 15.1 hereby certify that the foregoing Operations EngineeringDaM~na¢~_/~ Form 10-404 Rev. 12-1-85 WELLS/93 P. V. Lantero, ATO-1504, 263-4312 Submit in Duplicate DRILL SITE 14-6 HC1 MATRIX/AMINE PHOSPHONATE TREATMENT On June 6, 1987, the following operations were performed: 1. MIRU pump truck and transports. 2. Pump the following: a. 2000 gals xylene b. 12,000 gals 15% HC1 w/additives (blended w/1500 lbs oil soluble resin) c. 20 bbls diesel w/50% EGMBE d. 320 bbls of dead crude 3. Return well back to production and obtain new capacity. On June 18, 1987, the following operations were performed: 1. MIRU pump trucks and transports for scale inhibitor treatment. 2. Pump the following: a. 2000 gals EDTA w/additives b. 5500 gals of scale inhibitor blend c. 720 bbls of clean crude d. 320 bbls of dead crude e. 5 bbls of clean diesel 3. Shut well in for 12 hours. 4. Put well back on production. WELLS/93 RECEIVED Alaska Oil & Gas Cons. Commissio~ Anchorage ARCO Alaska, Inc~ Prudhoe B;~"Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 6, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-6 Permit No. 78-65 Dear Mr. Chatterton: Attached is the Application for Sundry Approval performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/PVL/jp Attachment cc: Standard Alaska Production Company Pi(DS 14-6)W1-3 detailing work to be RECEIVED Alaska 0il & Gas Cons. Commission Anchorage WELLS/93 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA , / ALA~rA OIL AND GAS CONSERVATION CO~'I~]~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P, 0, Box 100360. Anchorage. AK 99510 4. Location of well at surface 1731' FNL, 1129' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 1089' FSL, 1323' FWL, Sec. 9, T10N, R14E, UM At effective depth At total depth 882' FSL. 912' FWL. Sec. 9. TION: R14E; UM 11. Present well condition summary Total depth: measured 10895 ' feet true vertical 9620 ' feet 5. Datum elevation (DF or KB) 73' ~B 6. Unit or Property name Prudhoe Bay Unit 7. Well number 14-6 8. Permit number 78-65 9. APl number 50-- 029-20328 10. Pool feet Plugs (measured) Prudhoe Bay O~1 Pool Effective depth: measured 10264 ' feet true vertical feet 9096' Casing Length Size Structural Conductor 115 ' Surface 2717 ' Intermediate 10881 ' Production Liner Perforation depth: measured 20" 13-3/8" 9-5/8" Junk (measured) Cemented 30 Sx AS 5000 Sx Perma II 1000 Sx C1 G 10062-10089'; 10089-10108'; 10120-10157'; 10162-10205' true vertical 8929-8952'; 8952-8968'; 8978-9008'; 9012-9048' ~bing(size, grade and measured depth) 7" 29# @ 5713, 5½" 17# @ 5713-9807, 4½" 12.6# @ 9807-9814 Packers and SSSV(type and ~easured depth) Baker SAB Packer @ 9777' MD; Otis SSSV @ 2035' MD Measured depth 115' 2717' 10881' True Vertical depth 115' 2717' 9606' RECEIVED MAY- $1987 Alaska 0il & Bas Cons. Commission Anchorage 12.Attachments Description summary of proposal M~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation June 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby,~ertify that the foregoing is true and correct to the best of my knowledge Signed ,~,,,/,f,~,~;)~~ Title Operations Engineering Manager Commission Use Only Date Conditions of approval Notify commission so representative may witness / ApProval No. [] Plug integrity [] BOP Test [] Location clearanceI /' '" Eet~d ~l~t $1t1[~ '"*, ~-/~~ by order of Approved by ~ L~[ ~. ~l~ ~Commissioner the commission Date Form 10-403 Rev 12-1-85 WELLS/93 P. V. Lantero, ATO-1504, 263-4312 Submit in triplicate DRILL SITE 14-6 HC1 MATRIX/AMINE PHOSPHONATE TREATMENT 1. MIRU pump truck and transports. 2. Pump the following: a. 2000 gals xylene b. 12,000 gals 15% HCl w/additives (blended w/1500 lbs oil soluble resin) c. 20 bbls diesel w/50% EGMBE d. 320 bbls of dead crude 3. Return well back to production and obtain new capacity. 4. MIRU pump trucks and transports for scale inhibitor treatment. 5. Pump the following: a. 2000 gals EDTA w/additives b. 5500 gals of scale inhibitor blend c. 720 bbls of clean crude d. 320 bbls of dead crude e. 5 bbls of clean diesel 6. Shut well in for 12 hours. 7. Put well back on production. RECEIVED MAY- 8 I':~"~ Alaska Oil & Gas Cons. Co.mmissio~ WELLS / 93 ARCO ALaska, Inc. P.O. Box tGG360 Anchorage, ALaska 995i~ DATE: July t t,t986 REFERENCE: ARCO Cased Hole Final 9-20 5-25-86 Co l lar/F'erf Run t 5' t4-4 5-24-86 (~io t tar/F'er f Run L i nd~ H~ ~TO-~ ~29 TR~N$ ~86428 Gear Gear Gear Gear DISTRIBUI'ION Central Fi le~ $ F'hillip~ Chevron PB Well Fi lez D & M R &D Extension Exploration $ Sohio Exxon ~Sta te~ of-~ Alaska- . ,::: .: , ,.. Marathon $ Texaco Mob i [ ARCO Alaska, Inc. Post Office B~)t~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 4, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 14-6 Permit No. 78-65 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS:JEB:dp Attachment cc: SOHIO Alaska Petroleum Co. File Pi(DS 14-6)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CC-~,--M~ ISSION SUNDRY NOTICES AND REPORTS ON'.WELLS 1. DRILLING WELL [] COMPLETED WELL I~X OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, AnChorage, Alaska 99510 4. Location of Well 7. Permit No. 78-65 8. APl Number 50-- 029-20328 9. Unit or Lease Name Prudhoe Bay Unit At Surface: 10. Well Number 1731' S & 1129' W of NE cr. Sec. 9, T10N, R14E, OM DS 14-6 At Total Depth: 882' N & 912' E of SW ct. Sec. 9, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 73' RKB I ADL 28312 12. Check Appropriate Box TO Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate ;[}[ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ][][ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. intends to convert DS 14-6 from a source water producing well to an oil producing well using a coiled tubing unit (CTU). After the squeeze the well will be cleaned and reperforated. These operations wilI be performed in the following manner: 1) 2) 3) 4) 5) 6) 7) Shoot squeeze perforations from 10205-1020~'. MD. Cleanout well and load with formation water and diesel. _%~ Pump in cement and squeeze the following perforation intervals:~ 10088-10107' MD 10512-10532' MD 10652-10678' MD 10119-10156' MD 10542-10560' MD 10690-10700' MD 1020S-1020~' MD- · 10570-10580' MD 10310-10420' MD 10588-10596' MD Ref: BHCS 3-15-79 10430-10470' MD 10600-10620' MD 10474-10492' MD 10630-10646' ~ ECEIVED Contaminate the cement to 10290' MD. Wait 12 hours and reverse out the contaminated cement. ~erforate the following intervals: OCT !71985 10062-10108' MD Alaska0il & Gas Cons. Commission 10120-10157' MD Ref: BHCS 3-15-79 10162-10209' MD Test the well. 14. I hereby ~'~tify that the forgoing is true and correct to the best of my knowledge. Regional Operations Engineer Signed ~q~x' [,' -/ ~ . _ ___~--- Title The space below for Commission use Conditions of Approval, if any: Approved by COMMISSIONER .a~pproveCi Co~¥ teturne~d 8V Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inf Post Offid~-~,,.~0x 360 Anchorage. Alaska 99510 Teieohc,"'~ 907 ?77 5537 July 20, 1983 Reference: Arco Cased Hole Finals D.S. 6-19 4-27-83 GR 5" DA D.S. 6-21 4-28-83 GR/CCL 5"' DA D.S. 13-29 5-8-83 Sonan Run 1 2" DA * D.S. 14-6 4-21-83. Production Logging Service Run 1 5" * please note that this is a corrected log and the previous . /~g should be discarded.~ se sign and return the attached copy as receipt, of data. Kelly McFarland ATO-1429D Trans. # 437 Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North Geology. Phillips Prudhoe Bay R & D Caroling Smith SOhio State of Alaska ARCO Alaska, Inc. / Prudhoe Bay En~ineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. $cheve Regional Operations Engineer June 9, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 14-6 DS 14-9B DS 14-11 DS 14-26 DS 14-29 Permit No. 78-65 Permit No. 82-34 Permit No. 80-131 Permit No. 81-110 Permit No. 81-168 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/TKKW/lmi Enclosures cc: Sohio Petroleum Co. RECEIVED Naska Oil & ~as Co,,'is. b0~,imi~sj0, ARCO Alaska, Inc. I- a Subsidiary of AllantlcRIchfleldCompany STATE OF ALASKA ; ~, ALASK/~---~L AND GAS CONSERVATION (.~ '~MlSSlON WELL COMPLETION OR RECOMPLETION EPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ i,-- 2. Name of Operator 7. Permit Number ARCO Alaska, ]:nc. 78-65 3. Address 8. APl Number P.O. Box 360, Anchorage., AK 99510 5o-029-20328 4. Location of well at surface 9. Unit or Lease Name 1731' FNL, 1129' FEL, Sec. 9, TION,.R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1089' FSL, 1323' FWL, Sec. 9' TION, R14E, UM 14-6 At Total Depth "~ 1. Field and Pool 882' FSL, 912' FWL, Sec. 9, TION, R14E,'UM Prudhoe Bay Field 5. Elevation73,in feetRKB(indicate KB, DF, etc.) I 6.ADLLease 28312Designation and Serial No. Prudhoe Bay 0il Pool I 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore 116. No. of Completions 02/26/79 03/17/79 03/26/79I ) N/A feet MSL 1 17. Total Depth(MD+TVO) 18. Plug Back Depth (MD+TVD)19. DirectionalSurvey [ 20. DopthwhereSSSVset I 21. Thickness of Permafrost 10895'MD,9620'TV[) 10700' WLM YES[~] NOD 2035 feetMD 1900' (approx) 22. Type Electric or Other Logs Run DIL/BHCS/Cal/GR, FDC/CNL/Cal/GR, GR/CNL/CCL, PAL, CAT .... 23. / CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,, 20" 94. O# H-40 Surf 115' 30" 300sx AS cmt ..13-3/8" 72.0# N-80 Surf 2717' 7-1/2" 5000sx Permafrost II 9-5/8" 47.0# N-80 Surf 10881' 12-1/4" lO00sx Class G S00-95 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) 10310'-10420' MD 10630'-10646' MD 5-1/2"/7" 9931 ' 9801 ' 10430'-10470' MD 10652'-10678' MD 10474' - 10492' MD 10690' - 10720' MD 26. ACID, FRA'CTURE, CEMENT SQUEEZE, ETC. 10512' - 105 32'MD 9136' -9475' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATER IAL USED 10542' -10560' MD N/A 10570'-10580'MD Ref' BHCS 3-15-79 10588'-10596' MD 4 spf 10600' -1 n6?n' Mn .. 27. PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) 17-24-R2I Gas lifted for water production.* Date"of Test Hours Tested PRODUCTION FOI~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE tGAS-OILRATIO TESTPERIOD I]~ 150 214 3,750 90°I 800 , Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) ' Press. 24-HOUR RATE I~ 600 855 15,00~ 27 28. CDR E DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RE¢[IYED JUN 1 Alaska 0il & Gas Cons, Cornl~issl0~ Anfherag~ *Water source well for FS 3 Injection Project. Originally comp] t~ld. 8_~27~ as an oil well. Well did not flow until reperforated as water source we/~ 2 . ,,, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ! 29. ' ' 30. GEOLOGIC MARKERS FORMATION TESTS ; NAME Include interval tested, pressure data, all fluids recovered and 9rarity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Safllerochit 10071' 8937' N/A Base Sadlerochit 10787' 9530' 31. LIST OF ATTACHMENTS 32. I hereby certify that the f~regoing is true and correct to the best of my knowledge I I Signed ........ Title Regional Eng. 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 well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" ARCO Alaska,· Inc. Prudhoe Bay Engineering Post office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer · May 25, i983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: D.S. 2-20 Permit No. 82-29 D.S. 2-24 Permit No. 82-71 Permit No. 82-96 Permit No. 78-65 D.S. 14-9B Permit No. 82-34 D.S. 14-11 Permit No. 80-131 D.S. 14-22 Permit No. 82-75 D.S. 14-26 Permit No. 81-110 D.S. 14-28 Permit No. 82-12 ~,~..m~--Z~ Permit No. 81-168 Enclosed are Completion Reports for work done on the above- mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/cl Enclosures cc: Sohio Petroleum Co. ARCO Alaska, Inc. ~ Post Office B~60 Anchorage. Alaska 99510 Telephone 907 277 5637 May 26, 1983 Reference: Arco Pressure Data D.S. 7-6 ~' 4-9-83 D S 9-6 / 4-17-83 4-17-83 D.S. 14-6 ~/ 4-3-83 4-3-83 D.S. 14-11/ 3-24-83 D.S. 14-17 J. 3-27-83 D.S. 14-21 j 3-25-83 D.S. 15-3../ 5-6-83 Static Survey DA Pressure Build-up Camco Pressure Build-up Survey Report Pressure Build-up DA Pressure Build-up Survey Report Pressure Gradient Survey Otis Pressure Build-up Sch Pressure Build-up Sch Static Survey DA Please sign and re%urn the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 351 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL. GETTY D &M ~~._ ~9,,~/ DALLAS CAROLINE ARCO Alaska, Inc. Post O Ifice Anchorage. Alaska 99510 Telephone 907 277 5637 May 18, 1983 Reference: Arco Pressure Data moSo DoS, D.So 4-5'~ 5-4-83 14-6 3-21-83 Otis Static Survey Pressure Build-up 14-13 4-23-83 Pressure Data Sch 15-12~ 4-24-83 Pressure Build-up Camco 4-24-83' Pressur. e Build-up Survey Report Please Otis sign and return the at.tached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 344 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOB I L GETTY D&M STATE OF ALASKA DALLAS CAROL_INE SMITH ARCO Alaska, Inc. Post Office B(~x~60 Anchorage. Alaska 99510 Telephone 907 ."77 ,5637 May 11, 1983 Reference: Arco Cased Hole Finals D.S. '~-~.5 ,~-~)-83 D.S. 7- 7A'"" 3-30-83 .D.S. 7-22-- 3-21-83 D.S. 13-20~''~3-20-83 ~.s. ~.3-~~ 3-~3-~3 ]:). s~.~, ,~-~,/ ~-2:L-~3 --- 3-27-83 D.S. 14-11,./' 3-25-83 CH CNL ACBL/VDL/Sig/GR/CNL ACBL/VDL/Sig/GR/CNL EPL EPL PLS GLV Temp Survey GLV Temp Survey Run 1 5" GO Run 1 5" DA Run 1 5" DA Run 1 5" Sch Run 1 5" Sch Run 1 5" DA Run 1 5" Otis Run 1 5'" Otis sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 322 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY STATE OF ALAS~~~ DALLAS , ~"'"'~'"; - "~ CAROLINE SH!TH ARCO Alaska, Inc. Post Office Bg~.,/360 Anchorage. Alaska 99510 Telephone 907 277 5637 March 24, 1983 Reference: A~¢o Cased Hole Finals D.S. 6-12~/ 3-16-83 D.S. 7-17/ 12-19-82 12-25-82 · D.S. 12-4AC/ 3-11-83 D.S. 13-26~'~3-17-83 D.$. 14-6~ 12-12-82 CPL/TDT-M w/Listing ACBL/VDL ACBL/VDL CPL/TDT-M w/Listing CPL/TDT-M w/Listing C .A.T. 5" Sch Run 1 5" DA Run 5 5" DA 5" Sch 5" Sch Run 1 5" DA Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. 9 242 NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS CAROLI Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Prudhoe Bay ~nngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 7, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: D.S. 14-6 Permit No. 78-65 D.S. 14-9B Permit No. 82-34 D.S. 14-11. Permit No. 80-131 D.S. 14-26 Permit No. 81-110 D.S. 14-29 Permit No. 81-168 D.S. 14-30 Permit No. 81-166 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned'wells.. Very truly yours, D. F. Scheve DFS/TKKW/kn Attachments cc: Sohio Petroleum ARCO Alaska, Inc. Is a Subsidiary of AflanflcRIchfleldCompany STATE OF ALASKA ALASK/~"~IL AND GAS CONSERVATION C~I(/IMISSION / SUNDRY NOTII ,AND REPORTS ON WELLS DRILLING WELL [] '~'E~ -- 9 ~[91~OMPLETED WELL'El OTHER [] 2. Name of Operator ARCO Alaska, Inc. Alaska Oil & Gas Cons. Commission Anchorage 3. Address ?.0. 30× 360, Anchorage, Alaska 99510 4. LocationofWell Surface: 1731'S & 1129' W of NE Cr SeC. 9~ TION, R14E, UM TD: 882'N & 912'E of SW cr Sec. 9, T10N, R14E, UM 5. Elevationinfeet(indicateKB, DF, etc.) 73' RKB 6. LeaseDesignationandSerialNo. ADL 28312 7. Permit No. 78-65 8. APl Number 50- 029-20328 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 14-6 11. FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations }[Fl Altering Casing Stimulate Fl Abandon Fl Stimulation [] Abandonment Repair Well ' Fl Change Plans [] Repairs Made Fl Other Pull Tubing Fl Other [] Pulling Tubing Fl (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 12/22/82. RU perforating unit,, pressure tested surface equipment. RIH with gun #1 shot 10651'-10671' MD 4spf (20'. Tel CBL 3/25/79) POH - gun did not fire. RIH with gun #lA, shot 10651'-10671' MD 4spf (20' ref CNL 3/25/79). POH - all shots fired . RIH with gun #2, shot 10599'-1061~9' MD 4spf ( 20' ref CNL 3/25/79) POH - all shots fired. RIH with gun #3, shot 10_~511'-10531' MD 4spf ( 20' ref CNL 3/25/79) POH - all shots fired. RIH with gun #4, shot 10449'-10469' MD 4spf (20' ref CNL 3/25/79) POH, all shots fired. RIH with gun #5,' shot 10587'-10595' and 10569'-10579'MD 4spf (8' and 10' ref CNL 3/25/79). POH - all shots fired RIH with gun #6, shot 1067 ~-~' and ~' MD 4spf (6' and 16' ref CNL 3/25/79) POH - all shots fired. RIH with gun ,#7, shot 10541'-10559' MD 4spf (18' ref CNL 3/25/79). POH '- all shots fired. RIH with gun #8, shot 10473'-10491' MD 4SPF (18' ref CNL 3/25/79). POH - all shots fired. RIH with gun #9, shot 10689'-10699' MD and 10309'-10319' MD 4spf (10' and 10' ref CNL 3/25/79) POH - all shots fired. IRH with gun ~0, shot 10429'-1044_~9' MD 4spf (20' ref CNL 3/25/79). POH - all shots fired. RIH with gun #11, shot 1~399'-~04_l~' MD 4spf (20' ref CNL 3/25/79). POH - all shots fired. RIH with gun # 12, shot 10379'-1_~' MD 4spf (20' ref CNL 3/25/79). POH - all shots fired. RIH with gun #13, shot 1~0359'%10__~' MD 4spf (20' ref CNL 3/25/79) POH - all shots fired. RIH with gun #14, shot 10339'-10359' MD 4spf (20' ref CNL 3/25/79) POH - gun did not fire. RIH with gun #14A, shot 1D339'-10359' MD 4spf (20' ref CNL 3/25/79) POH - all shots fired. RIH with gun #15, shot 1~0319'-10339' MD 4spf (20'ref CNL 3/25/79) POH - all shots fired. Secured well 12/24/82. 14. I hereby certify t;t~e fo~oing is true and correct to the best of my knowledge. ~~~~;~ Regional Operations Engineer Signed j Title The space below for Commission use Date -7 / Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. post office Anchorage, A..4a 99510 Telephone 907 277 5637 January 20, Reference: 1983 Arco Cased Hole Finals . . D.S.i~i4:-6 : 12-22-82 Completion Record Run 1 5" D S,~'~4'6 12-12-82 P.A.L. .. Run 1 5" D.S. 14-28 12-25-82 Completion Record R%n 1 5" D.S. 18-1 12-15-82 Perforating Record Run 1 5" D.S. 18-3 12-17-82 Perforating Record Run 1 5" 'D.S. 18-7 12-19-82 Completion Record Run 1 5" Sch Sch Sch Sch Sch Sch Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans.' # 060 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBILE GETTY D&M STATE OF ALASKA .jAN2 z, 1983 Aias~ Oil & Gas Cons, Commission Ansho~a~e ARCO Alaska. Inc. IS a Subslcli~fv of AtlanticRichfse~d£omDanv ARCO Alaska, Inc. Post Office~,,,,~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 13, 1983 Mr. C. V. Chatterton Commi sSi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- State Reports Dear Mr. Chatterton' Enclosed are monthly reports for December on these drill sites' 1-24 13-14 1G-7 2;1'1 13-98 1G-8 7-16 1E-22 WSW-8 7-17 1E-23 WSW-9 7-18 1E-24 WSW-IO 12-18 1F-2 Tract Well 24-11-14 12-19 1F-3 CIRI Wolf Lake Well #1 13-11 1F-4 Also enclosed are well completion reports for: 1-22 13-13 1-23 14-6 6-24 1C-1 7-15 1C-IOGI 12-20 1E-25 13-6 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 7-17, 13-6, 14-6 and 1C-1. Since the information on the Wolf Lake and Tract wells is of a confidential nature, we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JGL28'llm Attachments ARCO Alaska, Inc. is a subsidiary of AllanticRIchfieldCompany N i 4 Gas Cons, Oommissio~ ,- ..... -" STATE OF ALASKA ALASK~L AND GAS CONSERVATION C~,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILY~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 78-65 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20328 4. Location of well at surface 9. Unit or Lease Name 1731' FNL, 1129' FEL, Sec. 9, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1089' FSL, 1323' FWL, Sec. 9, T10N, R14E, UM 14-6 At Total Depth 11. Field and Pool 882' FSL, 912' FWL, Sec. 9, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 73' RKBI ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 02/26/79 03/17/79 03/26/79I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10895'MD,9620'TVD 10700' WLM YES [] NO []I 2035 feet MD 1900' (approx) 22. Type Electric or Other Logs Run D IL/BHCS/Cal/GR, FDC/CNL/Cal/GR, GR/CNL/CCL, PAL, CAT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE!WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 Surf 115' 30" 300 sx AS cmt 13-3/8" 72.0# N-80 Surf 2717' 17-1/2" 5000 sx Permafrost II 9-5/8" ~r Surf 10881' 12-1/4" 1000 sx Class G 47.0# N-80 S00-95 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) 5-1/2"/7" 9931 ' 9801 ' None Tapered Assy 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH. INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 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 GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA None ',, JAN 1 41983 Alaska 0it & Gas Cons, Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 GRU1/WC13 CONTINUED ON REVERSE SIDE 29. ' 3O. · GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10071 ' 8937' N/A Base Sadlerochi t 10787' 9530' · · 31. LIST OF ATTACHMENTS Workover History I 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ___ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". DS 14-6 WORKOVER RIH to 9833'; set plug in no-go nipple w/1850 psi. Perf'd tbg f/9700'-9702' WLM w/4 spf. Disp ann & tbg w/NaC1. Accepted rig @ 1000 hrs, 12/09/82. Disp hole w/9.7 ppg, brine. Set BPV; ND tree; NU BOPE. RU CSRS; POH & LD 5-1/2" completion assy. Tagged SBR @ 9744~; rotate out K-anchor. Ran CAT log f/9784'-surf. Ran PAL 10g f/9784'-surf. Latched into pkr @ 9795' DPM. Tstd 3-1/2" x 9-5/8" & pkr to 2000 psi - ok. Unlatched f/K-anchor. Ran 5-1/2" and 7" tapered completion assembly. Tstd ann to 1500 psi & tbg to 2500 psi - ok. Set BPV. ND BOPE. NU tree & tstd to 5000 psi - ok. Opened SS @ 9670'. Disp tbg & ann w/treated diesel. Tstd tbg to 2900 psi & ann to 1900 psi - ok. Cut tailpipe @ 9814'. Attempted to log w/CCL; lost the signal & POOH. Left junk (centralizer bows, CCL & tubing cutter = 7') in hole. New PBTD = 10700' WLM. Secured well & released rig @ 0600 hrs, 12/17/82. JG' llm 01/07/83 GRU1/WH4 JAN i ]982 Oil & Gas Coils, Commission Anchorage STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION C~ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 78-65 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20328 OTHER [] 4. Location of Well Surface: 1731' S & 1129' W of NE Ct, Sec. 9, TION, R14E, UN 5. Elevationinfeet(indicate KB, DF, etc.) 73' RKB 12. I 6. Lease Designation and Serial No. ADL 28312 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-6 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [~X (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached Workover History. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED J AN 1 4 !983 Alaska Oil & G~s Oons, Gornmission Anchorage Signed ~ ~'~~~ The space below for Commission use Title Area Drilling Engineer Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU1/SN14 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate DS 14-6 WORKOVER RIH to 9833'; set plug in no-go nipple w/1850 psi. Perf'd tbg f/9700'-9702' WLII w/4 spf. Disp ann & tbg w/NaC1. Accepted rig @ 1000 hrs, 12/09/82. Disp hole w/9.7 ppg brine. Set BPV; ND tree; NU BOPE. RU CSRS; POH &. LD ! 5-!/2" completion assy. Tagged SBR @ 9744; rotate out K-anchor. Ran: CAT log f/9784'-surf. Ran PAL log f/9784'-surf. Latched into pkr @ 9795' DPM, Tstd 3-1/2" x 9-5/8" & pkr to 2000 psi - ok. Unlatched f/K-anchor. ~,an 5-1/2" and 7" tapered completion assembly. Tstd ann to 1500 psi & tbg to 2500 psi - ok. Set BPV. ND BOPE. NU tree & tstd to 5000 psi - ok. Opened SS @ 9670'. Disp tbg & ann w/treated diesel. Tstd tbg to 2900 psi & ann to 1900 psi - ok. Cut tailpipe @ 9814'. Attempted to log w/eCL; lost the signal & POOH. Left junk (centralizer bows, CCL & tubing cutter = 7') in hole. New PBTD = 10700' WLM. Secured well & released rig @ 0600 hrs, 12/17/82. JG.11m 01/07/83 GRU1/WH4 JAN 1 4 Alaska Oil & Gas Cons, Commission Anchorage MEMORA'NDUM StaTe of Alaska TO: Thru: FROM: ALA~ AND GAS CONSERVATION COMMISSIONDATE: C. ~. ~h~tJ~rton December 17, 1982 Ch~~''''~' FILE NO: 108/I~ Commissioner ~ . Ben LeNorman Petroleum Inspector TELEPHONE NO: SUBJECT: Witness BOPE Tests on · ARCO's DS 14-6 Wo rkover Sec. 9, T10N, R14E, UM Thursday, De.c.e.mbe.r.....9.,' 1982 - I departed my home at 12:20 p.m. for a 12:50 p.m. showup and 1:50 p.m. departure via Alaska Airlines flight #61 for Deadhorse arriving at 3:30 p.m. Weather: +2°F, high overcast, no wind. F~riday, Dece__m_ber 10.___. _1~.82 - BOPE tests on ARCO's Kupar~ WSW-9 w~re completed, the subject of a separate report. BOPE tests on ARCO's Kuparuk 1F-4 were completed, the subject of a separate report. BOPE tests on ARCO's DS 1,4-6 workover began at 12:00 noon and ~re completed at 2:45 p.m. BOPE inspection report is attached. Saturday, December 11, 1982 - Witnessing of testing of low pkiots, sSV's,' s~-V's-i and recording of annulas pressure on fourteen Sohio w~lls was completed, the subject of a separate' report. SUnday, ~December!~, 19..8...2.. - BOPE tests on ARCO's DS 13-8 were Completed, the subjct of a separate report. I departed Deadhorse at 4-.10 p.m. via Alaska Airlines flight #56 arriving in Anchorage at 5.:50 porn. and at my home at 6~20 p.m. N_onday,_ December !3,_ 1982 - Pegg"y Fisher, drilling forewoman, 6'al led and advised-a d~'{ type inside BOP ~as obtained for the rig floor and the deficient N2 bottle was replaced with one of 2000 psig. 02.001,A( Rev.l O/79) Time //" ~ WHILE YOU WERE OUT // Phone Area Code Number Extension i -- TELEPHONED ~' PLF~£ CALL CALLED TO SEE YOU WILL CALL AGAIN WANTS TO 'SEE ¥0IJ URGENT U6KJ ~'~ 4/8~ ~STATE OF ALASKA ALASKA OIL & ~AS O0NSERVATION CCMMISSION B .O.P.E. Inspection Report Date ~~, /dP/ /~ ~ Representative ~ _~ ~j~-~/~-F~ Operator, Well Location: Sec ~ T/O~ ~-~M Dril linq Contractor Casing Set @ Rig ~/'~ Representative~ ~ ft. Location, Genera~ Well Sign~ Ceneral Housekeeping Reserve pit ACCL%]UIATOR SYSTEM Ful 1 Charge Pressure ~ O O ~ Pressure After Closure / ~ ~ ~ Pump incr. clos. pres. 200 psig psig psig min/~,,, sec, Rig BOPE Stack Annular Preventer Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves, Check Valve Test Results: . Failures Test Pressure Full Charge Pressure Attained: / min~ sec. N2 ~O~ .%a~': ~:u~.. ~~psig Controls: Master ~P Remote (Q/~_ Blinds switch cover' Kelly and Floor Safety Valves - Upper Kelly · Test Pressure Lou~r Kelly Test Pressure Bal 1 Type _~) ~ Test Pressure Inside BOP /~D Test Pressure Choke Manifold ~. valves .._/3 No. flanges Adjustable Chokes ,,Test Pressure . Hydrauically operated choke Test Time' ~~~hrs. Repair or Replacement of failed equipment to be made ~i'~'*~in_ ~ ,, days and Inspector/Ccmmission office notified. Remarks: 7~ c~' .~s:~ ..L~ ~;;~ J~ ,*(D ¢~ ~/O ~ ~~ __ .:7",~,,~ ,x'~ ,..,.., .. ~.,,, ' Distribution orig. - AO&6CC cc - Operator cc - Supervisor Inspector ' ARCO Alaska, Inc. ~ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 2, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 14-6 Sundry-Notice Dear Mr. Chatterton' Enclosed is our Sundry Notice of intent to pull the 5-1/2" tubing string and install a combination 7" - 5-1/2" tubing string in the subject well. Since we estimate starting this proposed work on December' 7, 1982, your earliest approval will be appreciated. If you have any questions, please call me at 263-4965. Sincerely, rq. A. Ma&or ~ Area Drilling Engineer MAM/JG: sm Enclosure GRU2/L46 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ~,.~' STATE OF ALASKA ALASKA ~IL AND GAS CONSERVATION C~r~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 78-65 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20328 4. Location of Well Surface: 1731' S & 1129' W of NE Cr Sec. 9, T10N, R14E, UM Target: 1089' N & 1323' E of SW Cr Sec. 9, TION, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 73 ' RKB 6. Lease Designation and Serial No. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 14-6 11. FieldandPool Prudhoe Bay Field Prudhoe Bay 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ][~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to pull the 5-1/2" tubing string on DS 14-6 and install a combination 7";- 5-1/2" tubing string. A bridge plug will be set in the tailpipe below the packer~ The tubing will be perforated above the packer. The Nabors I-ES rig will be moved in and the well Circulated to NaC1 brine. The tubing will be pulled and the K-anchor/PBR assembly retrieved. An 8-1/2" bit and scraper Fun will be made to the' packer. The 9-5/8" casing will be pressure tested and repaired as required. A casing inspection log will be run and a 7" - 5-1/2" tubing string with gas lift mandrels will be installed with a tubing crossover depth_of ±5075' TVD. The tubing tail above the cast iron bridge plug will be shot off. The PBTD will be confirmed with a GR/CCL and the rig released. A 13-5/8", 5000 psi, RSRRA BOP stack will be used on well work performed by the workover rig. The BOP equip- ment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. conclusion of the job. Estimated start: December 7, 1982 Subsequent Work Iteported The subsurface safety valve will be installed and tested upon . RECEIVED DEC 0 2 1982 Alaska Oil & Gas Cons, Ccmmission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ' neer Signed ~'~' ~~ ~ ~'~~Title Area Drilling Engi Date The space below for 69~mission u;e~ .... Conditions of Approval, if any:Please notify the ~ssi~n so 1; .hat a ~ep~esentive may be p~esent Approvea .opy to witness testing of the BOPE. Returned ORIG'J4AI. SIGNED., / ........ ~ COMMISSIONER the Commission Date / ..... ~Z. Approved by Form 10~03 Rev. 7-1-80 GRU1/SN8 Submit "Intentions" in Triplicate and "SubseqUent Reports" in Duplicate ,~RCO Alaska, Inc. ['~-'"'i Post Office B ;160 Anchorage, Alaska 99510 Telephone 907 277 5637 October 25, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Re: D.S. 13,9 - Permit No. 81-158 D.S. 13-24 - Permit No. 82-65 D.S. 13-25 - Permit No. 82-91 ~o~ D.S. 14-6 -Permit No. 78-65- w~ D.S. 14-11 - Permit No. 80-131 D.S. 14-17 - Permit No. 81-21 D.S. 14-21 - Permit No. 82-86 D.$. 13-21 - Permit No. 82-53 Attached are "Notice of Intention" Sundry Notices work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS · TKKW' 1 mi Attachments cc' Sohio Petroleum Co. ARCO Alaska, Inc. Is a subsidiary of AllanlicRichlieldCompany ~ STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION C~(VllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] ' 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, AK 99510 4. Location of Well Surface: 1731'S & 1129' W of NE Cr Sec. 9, TION, R14E, UN TD: 882'N & 9!2'E of SW cr Sec. 9, TION, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 73' RKB 6. Lease Designation and Serial No. ADL 28312 7. Permit No. 78-65 8. APl Number 50- 029-20328 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-6 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate X] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within .the Sadlerochit Sand below the oil/water.contact for use as a water supply well in the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator,. tested to working pressure.. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Intended Perforation Intervals 10310'-10420' MD'~ 10430'-10470" MD~ 10474 '-10492' MD 10512 ' - 10532 ~ 10542 ' - 10560~ 10570'-10580' MD-~ 10588'-10596' MD- 10600'-10620' 10630' -10646' 10652' - 10678' MD~ 10690'-10720' Ref' BHCS 3-15-79 RECEIVED Subsequent Work ~ ),._~_./?~ No l~-?:g-~-~3 Datea --- on Form · NOV 0 2 1982 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ...... Title Reaional The space below for Commission use Date /5/~/,~.~ Conditions of Approval, if any: OIlIGINAL SIGNED BY H~flRY W. KUGLER Approved by. COMMISSIONER Approved Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post.Office Bo...60 Anchorage, Alaska 99510 Telephone 907 277 5637 July 12, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 POrcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton. Enclosed are monthly reports for June on these drill sites- 2-24 14-22 2-25 15-6 6-17 18-1 13-22 18-2 13-25 1E-13 13-26 1H-8 14-15 Also enclosed is a well completion report for Kuparuk 1£-12, and subsequent sundry reports for- 3-14 14-6 4-9 15-3 4-15 Eileen No. 1-4 NGI-7 (Since the information on the Eileen well is of a Confidential nature, we would appreciate it if you could store it in a secure area. ) Surveys for 2-22 and 13-21 are being reran; completion reports for these wells will be submitted when approved surveys are received. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG: 1 lm Enclosures GRU1/L48 RE[EIVED J U L. I 2 I982 Alaska Oil & Gas Cons. Commissiort Ancl~ora,rle ARCO Alaska Inc is ,~ subsidiary of AllanhcRichfieldCompnny STATE OF ALASKA ALASKA't~)'IL~' ' AND GAS CONSERVATION C~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL FXIX OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 78-65 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20328 4. Location of Well Surface: 1731'5 & 1129'W of NE ct, Sec. 9, TION, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) 73 ' RKB 12. I 6. Lease Designation and Serial No. ADL 28312 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-6 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate} (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). The proposed work described in our Sundry Notice, dated 06/08/82, has not been performed. Also, the work is not scheduled to be done in the immediate future. I ECEIVE JUL £ 982 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~. ~. W/~:~,~'/~ Title Area Drilling Engineer The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 GRU1/S8 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office I~h~360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 10, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 14-6 Dear Mr. Chatterton: Enclosed is our sundry notice of intent which proposes repairing the production tubing in the subject well. Since the approximate starting date of this work is June 18, 1982, your prompt approval will be appreciated. Sincerely, -~' //~ ~ Area Drilling Engineer MAM/JG: 1 lm Enclosure DS 14-6 GRU1/L18 RECEIVEO JUN 1 0 1982 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, lnc, is a subsidiary of AtlanticRichfieldCompany i STATE OF ALASKA ALASKA".-d L AND GAS CONSERVATION C~-41MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL~I~3 OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, ]:nc. 78-65 3. Address 8. APl Number P.0. Box 360, Anchorage, AK 99510 s0-029-20328 4. Location of Well Surface: 1731'S & 1129'W of NE er See. 9, TION, R1/4E, UM TD: 882'N & 912'E of SW er Sec. 9, TION, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 7_~z' RKB I ADL 28312 12. 9. Unit or Lease Name Prudhoe Bay Unlt 10. Well Number DS 14-6 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORTOF: (Submit in Triplicate) ::" ~Submit in Duplicate) Perforate [] Alter Casing [] Perforations ' [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [~ Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes repairing the production tubing in this well. The 5-1/2" tubing wiii be puiied. The weIi wiii be checked for possibie ieaks in the 9-5/8" casing and repaired as necessary. The weiI wiII be recompleted with new 5-1/2" piastie-coated tubing with gas iift mandreIs and the necessary provisions for subsurface safety equipment. A 13-5/8", 5000 psi, RSRRA BOP stack wiiI be used on weIi work performed by the workover rig. The BOP equipment wiIi be pressure tested weekiy and operationaIIy tested each trip. A non-freezing fiuid wiiI be ieft in raIi uncemented annuii within the permafrost intervai. A 5000 psi WP wireIine iubrieator wiIi be used and tested on aiI wireiine work. The subsurface safety vaIve wiii be instaiied and tested upon eoneiusion of the job. Approximate Start Date is 06/18/82. RECEIVEO Work ~c2°r~ed Subsequent '~2J~~-~- JUN t 0 982 on ~o~ No. ~at~.~ Alasb Oil & Gas Cons. Commission Anchorage 14. I hereby cer_~.tify_that t_Lhe fore,~jing is true and correct to the best of my knowledge. Signed ~///¢~~~ ~J~ Title Area Drilling Eng'neer The space below for Commission use Conditions of Approval, if any: Approved Cop~. Date ORIGINAL SIGNED .BY LONNIE C. SMITH Approved by. COMMISSIONER Returned By Order of the Commission Date Form 10-403 GRU1/A9 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas Company ~,~urth Alas,~,~strict Y'ust Office L, ox 360 :~,~chot'ag,:, Alaska 99510 Telephone 907 277 5637 October 12, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 12-4, Permit No. 79-48 DS 3-11, Permit No 79-47 WGI #4, Permit No. 79-50 ermit No. 78-65 ermit No 78-67 Dear Sir' Enclosed please find a Monthly Report of Drilling Operations for the above-mentioned well. Very truly yours, P.A. VanDusen District Drilling Engineer PAV'ms Enclosured ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ~oYm ~'0. io-~ REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20328 6. LEASE DESIGNATION AND SERIAL NO. ADL 28312 1. 7. IF INDIAN°ALOTTEE OR TRIBE NAME WELL WELL OTItER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME ARCO Oil and Gas Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 360, Anchorage, AK 99510 DS 14-6 (14-9-10-14) 4.LOCATION OF WELL 1731'S & l129'W of NE cr Sec 9, TION, R14E, UM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec 9, T1ON, R14E, UM 12. PERMIT NO. 78-65 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for September, 1979 Finish RU Otis snubbing unit. Snubbed in 2-1/16" tbg to 1700' and circ out w/glycol' mixture. Snub in hole to ice bridge @ 1777' Circ and wash w/glycol mixture to 1820'. Snub out w/2-1/16" tbg. Pump 63 bbls diesei down tbg. RD snubbing unit. RU' and ran CBL from PBTD to tbg tail. Run spinner, fluid density & temp log w/well SI. Open well to flow and re-log production logs. Flowed total 770 bbls fluid w/60% water cut. POH w/production logging tools. PU & run noise log w/well flowing @ 4200 BPD rate. POH w/noise log. Pump 53 bbl diesel. Attempt to run SSSV, stopped @ 421' POH. Operations temporarily suspended. RU and flush 14-6 flowline w/flow from 14-7. W~ll SI, temporarily suspended on 9/30/79. 14. ! hereby certify., that the~~ect ?~.'~~ TITLEDistrict Drilling EngineeflrATE lfl/12/7q SIGNED NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Post Ol~ic~ Uox 380 Anc,hom".?, A!aska 9~5i0 Tel.~i--)h{,.. ~,5'( 2'77., ,~ ._,f: '" '" ~', October 8, 1979 Reference' Enclosed are Pressure Surveys for the following'/~RCO wells' D S -- 5/14-15/79 Camco ' 8/13/79 Dresser~Atlas · and return the attached cop7 as receipt c-' of data. ' K, J. Sahlstrom North Engineering T_.%~NSMITTAL # 395 I)ISTIIIBUTIOX Nort.lt Ceo:logy l)r'i 11 Jh]g. Manage r (;col ogy State of A]aska I) & M ]jXXOI1 i, ~ob i ]. (;e t't v Sohio Ha rat:l ~on Phi 11 (]hcvron North Alaska District Post OIiick A n c ho rag ~,-~'~. 'I a~s ~ a 99510 Telephone 907 2775~.37 Reference: Enclosed are Cased Hole Logs for the following ARCO wells' D.S. 14-6 9/4/79 Differential Temperature Log 5" " " Fluid Density 5" " " Acoustic CBL-VDL 5" " " Sonan Run 1,2 5" " " Flowmeter 5" '~tease sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering T~2qSMITTAL # 382 DISTRIB[~'ION North Geology Drilling Eng. Manager Geology State of Alaska DaM I~.XXOI1 ~Xbbil Getty Sohio Marathon Phi 11 ips Chevron ARCO Oil and Gas Company Alaska R e,~..,,~. ,~ Post Of.fic~ ,;,~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 4, t979 Mr. Hoyle H. Hami'lton State of Alaska Department of Natural Resources Division of Oil' and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: WGI #2, Permit No. DS 3-10, Permit No. DS 12-3, Pmrmit No. 79-43 79-21 79-41 Permit No. 78-65 Permit No 78-67 CPF-1-23, Permit No. 79-42 Dear Sir' Enclosed please find a Monthly Report of Drilling Operations for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'jh Enclosures ARCO Otl and Gas Company Is a Division of Atla. nticRichfieldCompany Form No. ~-4 SUBMIT IN DUPLICATE REV. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP1 NUMERICAL CODE 50-029-20328 6. LEASE DESIGNATION AND SERIAL NO. ADL 28312 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL ~--I GAS [-'l 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME ARCO Oil and Gas Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 360, Anchorage, AK 99510 )S 14-6 (14-9-10-14) 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT Prudhoe. Bay Field-Prudhoe Oil 1731'S & l129'W of NE cr Sec 9, TION, R14E, UM 11. SEC. T~ R. M. (BOTTOM HOLE OBJECTIVE) Sec 9, T1ON, R14E, UM 12. PERMIT NO. 78-65 13. REPORT TOTAL DEFFH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Pool Report of Operations for the Month of August, 1979 Began .perf operations 8/12/79. Tstd wireline BOP & LUB to 2500 psi. Perfd intervals 10,148'-~~', 10,136'-10,148', ~'~1/~0~136', 10 088'-10 107' w/4 shots per foot. Perfd depths referenced 'to BHCS/GR of 3/1~,,~. FloW~ press bomb from 10,115' w/gradient stops. Attempt to set SSSV but could not get deep enough. Attempt to pump diesel down tbg to clear same, could not. RU & chip ice plugs & dump Methanol attempting to clear tbg to SSSV nipple. Shut dwn wireline operations 8/25/79. As of 8/31/79 waiting on Snubbing Unit to thaw out ice plugs. 14. ! hereby cetti.~, th~~n i~t ~~ TITLE DJstr~ct Dr~l lJnq En~Jnee~ATE /$ Iq~q SIGNED r ' - ' t - NOTl:-Report on this form is required for each calendar month, regardless of the status Of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. DS 14-6 Drilling History API 50-029-02328, ADL 28312, Permit No. 78-65 Spudded well @ 0800 hrs 2/26/79. Drld 17-1/2" hole to 2735'. Ran 13-3/8" csg w/shoe @ 2717'. Cmtd w/5000 sx Permafrost II cmt. Did 30 sx top job. Installed & tstd pkoff. Drld shoe & 10' new hole. Tstd form to 12.5 ppg equiv. Drld 12-1/4" hole to 10,875. Ran DIL/BHCS/CAL/GR & FDC/CNL/CAL/GR logs. Shot side- wall cores. Drld to 10,895_'. Ran 9-5/8" csg w/shoe @ 10,881'. Cmtd w/lO00 sx Class G cmt. Tstd FO~T-. Dwnsqz w/300 sx Permafrost cmt thru lower FO. Did Arctic Pack job thru upper FO. Displ mud w/wtr & wtr w/CaCle. Ran gauge ring & junk bskt. Ran 5-1/2" compl assy w/shear sub @ 9931', pkr~@ 9801'. Set pkr. Displ tbg w/diesel. Set BPV. NU & tstd tree. Pulled BPV & dummy valve. Ran GR/CNL/CCL logs. Press up for long term tbg tst. Released rig @ 1500 hrs 3/26/79. Anchor laska q95i0 Taloph~,,~; 907 277 5537 July 13., 1979 'i f;":" l: ~.i O I,._ 1 EI',JG 3 ENO ...... 4 ENd-~ ........... tGEOL 2 GEOL ..... 3 GEOL STAT TEC'- STAT TEC Reference' CONFER: FII F: Enclosed' are the f~nal prints for the following ARCO wells: - . D.S,_.Z:~~-IC-/// Acoustilog " 2/25/79 21[ & 5" Run 1 C. ~-~IC~ ...................... -- .......... S/lS/.Ta.2," Run 1 D.S. 7.-9 ~"'.,~HC Ac'oustilog 1/31/7~ 2 D.S.. 7-9 ~/ Dual Induction Focused Log 1/31/'79 2" & 5" Run 1. Please sign and return the attached .copy as receipt of data. Vezy truly yours, R. A. Bellinger TPJ%NSMITTAL # 216 DISTRIBU?ION North Geology Drilling Eng. Manager R& D Geology State of Alaska EXXOtl ~ lob i 1 Getty Sohio blarathon Phill.i. ps Chevron ,i 1.9, ].979 ]'}c.,"I::ei'eflce ' tlnc]o.sed are 'the following cased hole logs' /.g 9--16 7I)T 1]_/22/78 , ~ 3-~ c/o ~/2o/7~ ~I)S 3-6 F]. Dens. 2/19/79 ~S 3-8 C/O 2/14/79 ~~ CNI, 3/25/79 ~S- 3 - 7 'I'DT l 0/19 / 78 ~)s s- 2 'mT 1~/~0/7S [~ 15-3 CNL 3/17/79 ~$ ~3~4 GR 3/30/79 ~$ ..-~ TDT 10/17/78 ~'/1)W 1-1 Temp. 1/13/79 ~ ])S 7-11 CNL 3/2.7/79 1.)lease sign and return the copy as receipt of data. Sincerely, V.G. P,e:inlers North ]]ngJ.neering TI~&NSMi'Iq.'AI, It 187 N.:.)I') :i. ] (;et-. t )- Sohio North Alaska District Post Office",'o::' 360 Anchorage%.~;~ska 99510 Telephone 907 277 5637 'May 18, 1979 ,r; 'CEIVFD Reference' Enclosed are the following open hole logs- 4-6 ~ BHCS 5" ~ i~ Y~-~ CNL/FDC S" DS 14-6 DIL 5" DS 14-6 CNL/FDC DS 14-6 DIL 2" DS 14-6 FDC 2" DS 14-6 FDC 5'~ DS 14-6 CNL/FDC 5" DS '13-2 BGL 5" DS 13-2 FDC S" DS 13- 2 BHCS 5" DS 13-2 DIL 5" DS 14-6 CSU 3/15/79 1/31/79 3/15/79 3/10/79 3/15/79 3/15/79 3/ZS/79 5/10/79 1/14/79 1/31/79 1/51/79 1/31/79 3/16/79 · - , . Please-Sign. and return the copy as receipt of data./~~- Sincerely, V.G. Reimers North Engineering ~RANSMITTAL #169 DISTRIBUTION North Geology 5~xon. Drilling Mobil Eng. Manager Getty R fi D Sohio - Geology Marathon. State of Alaska Phillips D ~ M Chevron · North Alaska DTstr~ct Post O~dce ~ 360 Anchorage, ~ska 99510 Telephone 907 277 5637 May 8, 1979 Reference' Enclosed is a Magnetic Tape, #14-6, Open Hole, by Dresser, dated 4-11-79. Please sign and return the.attached'~ansmittal · as receipt of data..~/ ~~ '~.~/?F.-' '" Very trUly yours, R.'A. Ha~lin' North Operations EngineeTing L- 2 ENC-' / 3 ~N':3' ' ..... 4 STAT TEC l~_. STAT TEC ~ CONFER= FILF~ Transmittal #161 DISTRIBUTION North Geology Drilling Eng. Manager R&D Geology State of Alaska D~M ~xxon Mobil Getty Sohio ~rathon Phillips Chevron n Form No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 5. APl NUMERICAL CODE 50-029-20328 6. LEASE DESIGNATION AND SERIAL NO. ADL 2831 2 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 9. WELL NO. DS 14-6 4. LOCATION OF WELL 1731'S & l129'W of NE cr Sec' 9, TION, R14E, UM 7. IF INDIAN'ALOTTEE OR TRIBE NAME 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 9, TION, R14E, UM 12. PERMIT NO. 78-65 Pool 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES 1N HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of operations for the Month of February, 1979. Spudded well @ 0800 hrs 2/26/79. Drld 17-1/2" hole to 2720'. As of February 28~preparing to run 13-3/8" csg. S,GNED. · T,TLE District r~rilling Eng, DATE l'.~or~,i~ ¢,morican Prod.::.c~r,,g L)ivisioi~ I',!or[h Alask:- ';strict Post Of/ice ~ 380 Anchorage, ^!as,',(~ 995'!0 Tc. lophori,3 907 277 5'637 April 12, 1979 Reference' Enclosed are.copies of the.following Directional Survey ~~Gyroscopic Survey 3-20-79 · · D.S. #7-11' Gyroscopic Survey 3-30279 I coMM~ ~ R~S ENO --'1" ~ (~ r,.~ J 3 C, EOL- ---J STAT CONFER: please sign and return the attached copy of the-transmittal as receipt of data~z/~4 Very truly yours, R. A. 'Hamlin North Operations Engineering Transmittal # 15~? Alaska DISTRIBUTION North Geology Drilling Eng. Manager R & D Geology State of Alaska D & M ~XXOI1 Mob i 1 Getty Sohio Marathon Phillips Chevron April 11, 1979 Reference' Enclosed are the following Magnetic tapes' ~s zs:.~ ~sszo~ s/s/7~ ~~ #sszos ~/zs/79 0~ -~S-~1-18 #53150 4/24/78 'Please sign and return the copy as receipt of data. Sincerely, .. V.G. Reimers North Engineering TRANSMI]TAL # 151 DISTRIBUTION North Geology tLxxon Dr i 11 ing blob i 1 ling. Manager Getty R & D Sohio Geolog), Marathon State of Alaska t~]~illips I) & M Chevron I~lgll, ll l'~llll~lll..CIII rlUMUt,.,iii~I~j i./IVIIIIUll Norlh. AI~~ Anchorage, ~laska 99510 Telephone 907 277 5637 April 5, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 I i CO ,A RES ENG 12 _ . I 3 ~ :f'~- 1 GEOL !--J 2GEOL ~ .L~I STAT TEr'i'~ '--~0 N FE R: Subject- DS 7-10, Permit No. 78-77 DS 7-11~ Permit No. 78-78 DS 13-3,:"Permit No. 78-62 DS 14-6;' Permit No. 78-65 Dear Sir' Enclosed please find a Completion Report along with the Drilling History and Gyroscopic Survey for the above-mentioned, wells. Very truly yours, P. A. VanDusen District Drilling.Engineer PAV'cs Attachments F(~r:u P--.7 ~-~'~' ~' ' ' ' '~SUBMIT IN ~ATE* ' :: ~See other In- STATE OF ALASKA ~ : st ructions on OIL AND GAS CONSERVATION COMMITTEE ~ reverse side, : WELL cOMPLETION OR RECOMpLETION REPORT AND LOG* i i ii W ELL W ELL DRY Other. b. TYPE OF COMPLETION: WELL OVER EN BACK I'.ESV R. Other' NAME OF OPERATOR Atlantic Richfield Company . ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 LOCATION OF WELL (Report location clearly and in accordance with any State require~onts)* 5. AP1 NU1VI.F_A{ICAL CODE 50-029-20328 s. LF_.~E DES~GNA~ON ~ND SERUm NO. ADL 28312 ~. I~ I1N-DI.A.N, ALJ_~)~'I'EE OR TRIBE NAM. E 8. UNIT,FA3~iVI OR LF-,ASE NAME Prudhoe Bay Unit .-DS 14-~6~(14-9-10-14) At surface 1731'S & l129'W of NE cr Sec 9, TION, R14E, OM At top prod. interval reported below 1089'N & 1323'E of SW cr Sec 9, TION, R14E, UM At total depth 882'N & 912'E of SW cr Sec 9, TION, R14E, OM 10. FIELD A~4D POOL, OR WILDCAT ~r~flhoe Ba Field- hn~ F)i~ Pool I . SEC., T., R.. M., (I~)TTOM HOLE OELIEc'rlVE) Sec 9, TION, R14E, H~ 2/26/79 3/17/79 I 3/26/79 ' I{OW 1VLA~Y* ROTARY S m CABLE TOOLS 10,8 5'MD 9620'TVD [10,836'MD 9571'TVD[ Single 22.PRODUCING IHTE~VAL(S), OF TItI~.' COMI:U_,E"TIO~I~[M:L BOSOM, N~E (~ AND ~)* ~.W~ DIRE~O,N~ ) SURVEY ~ADE Top Sadlerochit IO,071'MD 8937'TVD 'Base Sadlerochit 10,787'MD 9530'TVD ,~ Yes 24. ~E E~CTRIC ~D OT~ LOGS DIL/BHCS/CAL/GR, [DC/CNL/CAL/GR, GR/CNL/CCL i j m~. _ ,, m CAS~G RE~ (Re~rt all strings set in well) 20" 194~ Welded[ H'iO ] 115~ 30" 300 sx Arcticset cmt ' 13-3/8"' [72~ Butt :~] N-80 [ 27~7' 17'-1/2" 5000 sx Permafrost II cmt . 9-5/8" [47t Butt / N-80&J 10,8~1' 12-1/,4" .1000 s'x Class G cmt , [ °°:9s I , 26. LINER ~CO~ ' 27. TUB~G ~ - - " 9931 '"' 9801 ' 28. PERORATIONS OP~ TO PRODU~ON (In~NE, size and number) ~. - ACID, Si!OT, :F~CT'~. C~iENT SQU~ZE, ~C N/A ' N/ ,. m mill Ilmm I m I mil L r m ~. ~ODU~ON DATE FIRST P~ODUC~ON [ ~ODUCTION ME'IIIOD (Flowh~g, gas lif~, pumping--size and type of pump). . . . ]%VELL STATUS (~oduc~ or shut-in) N/A . DATE OF TruST. [HO~S TES~ ']~OXE SiZE [~OD'N FOR OI~BEL. G~CF. WA~B~. [ GAS-OIL ~ : ' ' W~~L. lOlL GRAVITY-~I (CO~.) FLOW, ~BING [CAS~G P~S~ CAL~~ OI~BBL. GA~I~ ~ 1 .' ~-HOUR ~ ; ~. ~ ~ .... : "- .~~ m m m mil ~ - ~ , Drill ing History, GYroscoPic Survey 33. I hereb~~~t t~re~o?:~ anda, taehed infor, atio: i, co,ple~--~o~ct-hl determi,ed from all;,,,il,ble ,eeord, SIGNED W, '7 .--~ ~'--~''''-~ TITLE District Drilling Engineer DATE 4/4/7'9 m mm :~ m m '- *(S,, Instructions and S~ces [or AdditiOnal Data on Reverse Side) INSTRUCTIONS General: This form is designed for su',:m~tting a complete and correct well completion repor'~ end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown for depth measure- ments given in cther spaces on this form and in any attachmer~ts. Items 20, and 22:: If this well is completed for separatc, prcduction from more than one interval zone (multiple completion), so state ~n item 20, and in item 22 show thc p~cJuci~,.'.;l interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the intervul reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produce.d, show- ing the ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show thedeta~ls of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). I . WATER AND MUD NAM~E None " , .... " "' ' ' ' ' ~'""'~"' Top SadlorochSt 10,071 ' 8937' Base Sadleroch~t 10,787' 9530' .,. . ...:~ ..... ..... r.i,~.,.~i,,i ..,.~, ..., .~. ._.:_ ~*.o.:~,.~, ...... f...~,~% . ''" ~';~-"'~t'~~-', None ~ -. .. , ............... ,~ .......... ~, .- .. Eastman Wh ' stock A PETROLANE ~PANY REPORT of SUB-SURF,4CE DIRECTION.4L SURVEY ATLANTIC RICHFIELD COMPANY , COMPANY D.S., 14r6 , WELL NAME PRUI")FTC)R RAY LOCATION JOB NUMBER A379 G0199 TYPE OF SURVEY GYROSCOPIC 3-20-79 SURVEY BY Gene Rutland OFFICE A~S~ DATE COlqPLETION REPORT 29 MAR 79 EASTMAN WHIPSTOCK DS 14-6 GYROSCOPIC SURVEY K B ELEV 73 FT RADius OF CURVATURE METHOD OF COMPUTATIONS DECLINATION 31 DEG. EAST COMPUTED FOR EASTMAN BY F M LINDSEY AND ASSOCIATES RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY ! B M ELECTRONIC COMPUTER TRUE HEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M 0 0 0 0.00 SUB DR I F T SEA DIREC DE. Ge · --7:3.00 N O.OUE 2700 0 0 2700.00 2627.00 N O.OUE 2800 2 30 2799.96 2726.96 SIO.OOE 2900 5 0 2899.74 2826.74 S26.00W 3000 8 0 2999.09 2926e09 S30.OOW 3i00 i0 0 309748§ 3024.85 S36400W 3200 11 0 3196.18 3123.18 S43eOOW 3300 13 0 3293.98 3220e98 S49eOOW 3400 14 0 3391.22 3318.22 S47.00W 3500 16 0 3487.8i 3414e81 S49.00W 3600 i8 0 3583.43 3510.45 S48.00W 3700 20 0 3677.98 3604.98 S49.00W 3800 21 0 3771.65 3698.65 S47.00W 3900 24 0 3864.02 3791.02 548.00W 4000 26 0 3954.65 3881.65 S47.00W 100 28 30 4043.55 39?0.55 S44.00W 200 3i 0 &130.36 4057.36 S4?.OOW &300 33 45 4214.81 4141.81 S49.00W 4400 35 0 4297.3& 422&e34 S50.OOW 4500 35 30 43?9.00 4306.00 SSO.OOW 4600 35 0 4460.67 4387,67 $52.00W 4700 35 0 4542.58 4469.58 S46.00W 4800 3& 30 4624.75 4551.75 S48.00W 4900 3a 30 4707.16 4634e16 548eOOW AO00 34 0 4789.82 4716.82 S49.00W TOTAL COORDINATES 0.00 S 0.00 W 0.00 S 0.00 W 0.12 N 1.45 E 6.24 S 0.56 E 16.23 S 4e74 W 29.34 S i9.26 W 43.40 S 24.84 W 57.83 S ~9.79 W 73.45 S 57.14 W 90.77 S 76.37 W 110.14 S 98427 W i31.71S 122.65 W 155.14 S 148.67 w 180,99 $ 176.88 w 209.54 S 208,04 w 24i.63 S 240.69 w 276.40 S 276,08 w 3i2.23 S 315.86 w 348.89 S 358.80 W 385.99 S 403e0~ W 422.31 S 447.86 W 459e92 S 491.13 W 498.80 S 532.81 ~ 536.70 S 574.90 W 573.99 S 617.05 W CLOSURES D I STANCE ANGLE D Iq S 0,00 S 0 0 0 W 0.00 S 0 0 0 W 1.46 N 8,5 0 0 E 6.26 S 5 9 42 E 16.,91 S 16 18 19 W 32.20 S 24 19 20 W 50.01 S 29 47 35 N 70.20 S 34 31 55 N 93.06 S 37 52 5i W 118.62 S 40 4 39 W 147.61 S 41 44 23 W 179e98 S /+2 57 35 W 214.88 S 4~ 46 48 W 253,08 S 44 20 32 W 295.28 S 44 47:38 W 341.06 S 44 53 19 ~ :390.67 S 44 57 S8 N 444.14 S 45 19 54 W 500.46 S 45 48 6 W 5,58.04 S 46 14 7 W 615..57 S 46 40 ,5:3 W 672.86 S 46 *92 44 W 729.85 S 46 ,93 18 W 786.49 S 46 `58 7 H 842.7,9 S 47 4 i5 W SEVER t TY OEG/IOOFT 0.000 0.000 2.521 :3.o01 2,oO8 Z.023 i.oo? 2.006 2.002 2.003 1,032 3.005 2.009 2.592 2.62~ 2.818 1.293 0.500 0.826 3.440 0.81:3 0.000 0.590 bistAi 90. ii6; . 2i . ..... 293. 3:39. 442. 8~i. ARCO DS 14-6 GYROSCOP!C SURVEY 29 MAR 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEASe DRIFT VERTICAL DEPTH ANGLE DEPTH SUB DR I F T SEA DIREC DEG, TOTAL COORDINATES 5100 34 0 4872.72 4799e72 S49.00W 610.67 S 5200 34 0 4955,63 4882.63 S49.00W 647,36 S 5300 33 0 5039.01 4966e01 SSI,OOW 68~884 S 54'00 34 0 5122,40 5049,40 S50,OOW' 717,94 S 00 35 0 5204,81 5131,81 SSO,OOW 75~,35 S O0 35 30 5286,48 5213.48 SSO,OOW 791.45 S 5700 36 0 5367,63 5294,6~ S49.00~ 829,39 S 5800 36 45 5448,15 5375,15 S48.00W 868,69 S 659.26 701.'6 743.74 786.33 829.71 873.93 962,77 5900 37 0 5528,14 5455.14 S49,00W 908,45 S 1007,71 6000 37 45 5607,61 5534.61 S48'.00~ 948.67 $ 105'3.17 6100 37 &5 5686.68 5613.68 $48.00~ 989.64 S 1098.67 6200 37 15 5766.02 5693.02 S42.00N 1032.66 S 1141.70 6300 37 0 5845,75 5772.75 S46.00~ 1076e07 S 1183.62 6400 36 0 5926,13 5853,13 S36,00N 1i20,90 S 1222,59 6500 36 30 6006,78 5933,78 $47.00~ 1165,12 S 1261,71 6600 36 0 6087.42 6014.42 S46,00~ 1205083 S 1304,60 6700 35 30 6168,58 6095,58 S46,00~ 1246,41S 1346,63 6800 35 45 6249,86 6176.86 S47,00W 1286.51 S 1388,88 69~0 36 0 6330,89 6257,89 S46,00~ 1326,84 S 1431,39 7000 35 30 6412,05 6339,05 S46.00W 1367,43 S 1473,42 s ~200 35 30 6574.87 6501.87 S46.00~ 1448.11 S 1556,96 73p0 35 30 6656,28 6583,28 SkT'O0~ 1488,08 S 1599,08 7400 35 30 6737.70 6664,70 S46,00~ 1528.05 S 1641.20 7500 35 30 6819,11 6746,11 S46.00W 1568,39 S 1682.98 7600 35 0 6900.77 6827.77 S46,00W 1608,~8 S 1724,49 T~O0 35 0 6982,69 6909,69 Sk7.O0~ 1647.96 S 1766.10 7800 35 0 7064.60 6991,60 S47.00~ 1687.08 S 1808805 7900 35 0 7146.52 7073052 S46.00N 1726056 S 1849065 CLOSURES DISTANCE ANGLE D M S 898.64 S 47 il 27 w 954.53 S 47 17 48 ~ 1009.66 S 47 26 40 ~ 1064.78 S 47 36 10 W 1121.37 S 47 &3 26 ~ 1179.04 S 47 50 7 ~ 1237.44 S 47 54 49 W 1296.75 S 47 56 26 N 1356'75 S 47 57 55 N 1417.45 S 47 59 17 N 1478.67 S 47 59 19 W 1539.44 S 47 5~ 14 ~ 1599065 S 47 43 29 N 1658,66 S 47 E9 4 W 1717,39 S 47 16 44 ~ 1776,52 S 47 15 11 ~ 1834,93 S 47 1~ 47 ~ 1893,17 S 47 11 28 W 1951,77 S 47 10 14 W 2010.18 S 47 8 11W 2068,24 S 47 6 16 H 2126,30 S k7 4 28 g 2184,37 S 47 3 33 ~ 2242.43 S 47 2 41 ~ 2300,49 S 47 I 6 ~ 2358,20 S 46 59 36 w E415.55 S 46 58 54 ~ 2472.91S 46 58 55 W 2530.27 S 46 58 16 W DOG LEG SEVERITY DEG/IOOFT 0.000 0.000 1.163 1.048 1'000 0.500 0.608 0'831 0.440 0.838 0.000 2.254 1.470 3.597 3e924 0.608 0.500 0.423 0.4~6 0.500 0.000 OEO00 0,581 0.581 0.000 0,500 0.574 0.000 0.574 . . -- DISTAl 897.1 953. 1008,: 1.063,! 1120, 1177,' 1236,* _. 1295., 1355. _ .. 1416. 1477., .~ ~ 1537, 1597. 1656. 1~1~. 1773. . .. 1832. 1899. 19480 2007. 206 . 2122, 2180. 2296, 235~ 2~11, 2468, 2525. ARCO DS I GYROSCOPIC SURVEY 29 MAR 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COHPUTER TRUE MEASe DRIFT VERTICAL DEPTH ANGLE DEPTH 0 M SUB DR I F T SEA DIREC DEG, TOTAL COORDINATES 8000 35 0 7228,43 7155,43 $47,OOW 1766.O5 S [891,26 W 8100 35 0 7310',35 7237035 547,00W 1805,16 S 1933,21W 8200 34 30 7392,51 7319051 $47,00W 1844,04'S 1974.89 W 8300 34 45 ?4?.4,80 ?401080 S4?.OOW 1882e79 S 2016,45 W "~eO0 34 0 7557.34 7484034 S47,00W 1921e29 S 2057,74 W 00 34 0 7640.24 7567*24 S4?.OOW 1959.43 S 2098m64 W 8600 34 0 7723,14 7650o14 5qT*OOW 1997,~? S 2.139,53 W 8700 35 O 7805.55 7732055 S50,OOW 2035,09 S 2181,95 W 8800 34 O 7887,97 7814,97 SSO,OOW 2071,50 S 2225034 W 8900 34 0 7970,87 7897087 SSX.OOW 2107.07 S 2268049 W 9000 34 30 8053,53 ?.980.53 553.00W 2141.72 S 2312.83 W 9100 34 0 8136.19 8063*19 S56.00W 2174.40 S 2358.65 W 9200 35 0 8218,60 8145,60 S57.00W 2205.66 S 2405.88 W 9300 35 0 8300.51 8227*51 SS?,OOW 2236.90 S '2453098 W 9400 35 0 8382.43 8309043 SS?.OOW 2268014 S 2502009 W 9500 35 0 8464.34 8391034 S55,00W 2300,21S 2549.64 W 9600 34 30 8546,51 8473,51 ' 558,00W 2331.67 S .2597e16 W 9700 34 30 8628,92 8555092 S61.00W 2360041 S 2645.96 W 9800 34 0 8711,58 8638058 S61000W 2387,69 S 2695018 W 9900 34 0 8794048 8721.48 S61,00W 7414.80 S 2744.09 W '~000 33 30 8877.63 8804063 $62.00W 2441031S 2792,91W ~100 34 0 8960.78 8fl87,78 S63.00W 2466.97 S 2842.19 W 10200 33 30 9043.92 89?0092 S63.00W 2492.19 S 2891,?0 W 10300 34 0 9127.07 9054007 S63.00W 2517,41S 2941,20 W 10400 34 30 9209,73 9136,7] S63,00W 2542,96 S 2991~34 W 10500 34 0 9292.39 9219o~9 S63.00W 2568.51S 3041,49 W 10600 ]4 0 9375,29 9302~29 S6&,OOW 2593,46 S 3091053 W 10700 ~4 0 9458,20 9385*20 S63.00W 2618.41S 3141.58 W ~10800 34 0 9541.10 9468,10 S64.00W 2643*37 S 3191,62 W BOTTOM HOLE CLOSURE 4144013 FEET AT S 50 22 3 W CLOSURES DISTANCE ANGLE D H S 2587,62 S 46 57 38 W 2644.98 S 46 57 41W 2701,98 S 46 57 44 W 2758080 S 46 57 47 W 2815026 S 46 57 50 W 2871,18 S 46 57 52 W 2927010 S 46 57 55 W 2983,71S 46 59 40 W 3096.09 S 47 6 45 W 3208,00 S 4? 19 39 W 3263,92 S 47 29 9 ~ 3377,11S 47 48 27 W .3433089 S 47 ~6 38 W 3490,26 S 48 4 59 W 3545.79 S 48 15 52 W 3600,71S 48 27 42 W 3655032 S 48 39 7 ~ 3709,50 S 48 50 34 ~ 3763.51 S 49 Z 33 W 3817045 S 49 14 37 w 3871.44 S 49 26 21W 3926017 S 49 37 54 ~ 3980.95 S 49 49 9 w 4035.30 S 50 0 25 ~ 4089.70 S 50 11 23 W 4144.13 S 50 22 3 W DOG LEG SEVERITY DEG/IOOFT 00574 0.000 0.500 00250 0.750 0.000 00000 1.405 1.000 0.559 0.813 le063 1.053 0.000 0.000 1,147 1,085 1,699 0.500 0.000 0,585 0.590 O0500 0.500 0,500 0.500 0.559 0*559 0,559 SECTIC DISTAI~ 26~0,i 2697,; 27.5.3,!_ 2810,2 2866.1 29~.e~, 2978.,I 3035.e1 3091.1 3203,~ 3316.1 3430el 3708,; 37620~ 3816e' 3870,' ..... 39250 398P, 40350 ~0890 4144~ ARCO DS 14-6 GYROSCOPIC SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 29 MAR 79 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 173 173. 100 0 0 273 273. 200 0 0 373 373, 300 0 0 473 473. 400 0 0 573 573. 500 0 0 673 673. 600 0 0 773 773. 700 0 0 873 873. 800 0 0 97 3 973 · 900 0 0 1073 1073. 1000 0 0 1173 1173. 1100 O O 1273 1273. 1200 0 0 1373 1373, 1300 0 0 1/~73 1473. 14OO O 0 1573 1573. 1500 0 0 1673 1673. 1600 0 0 1773 1773. 1700 0 0 1873 1873. 1800 O. 0 1973 1973. 1900 0 0 2073 2073. 2000 0 0 2173 2173. 2100 0 0 2273 2273. 2200 0 0 2373 2373. 2300 0 0 2473 2673, 2400 0 0 2573 2573. 2500 0 0 2673 2673. 2600 0 0 2773 2773, 2700 0 0 2873 2873. ;]600 0 0 2974 2973. '2900 0 0 3075 3073, 3000 . 1 1 3176 3173. 31OO 3 2 3278 3273, 3200 5 2 3381 3373. 3300 8 3 3e85 3673. 3aO0 11 3 3589 3573. 3500 16 5 0.00 S 0.00 S 0.00 S 0,00 $ 0',00 S 0,00 S 0,00 S 0,00 S 0,00 S 0,00 S 0,00 S 0,00 S 0,00 S 0,00 S 0.00 S 0,00 S 0.00 S 0.OO S 0,00 S 0,00 $ 0,00 $ 0,00 $ 0.00 S 0,00 S 0.00 S O.OO S 0.44 N 4,17 S 13.19 S 25.85 S 40.03 S 54.59 $ 70.35 S 88.00 S 107,88 S 0.00 0.00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 OeO0 0.00 0.00 0.00 0.00 0.83 1.22 3.05 10.81 21.62 36.18 53.79 95.75 ARCO DS 14-6 GYROSCOPIC SURVEY MEASURED DEPTH AND OTHER DA'TA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 29 MAR 79 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION 3695 3673. 3600 21 3801 3773. 3700 28 T 39[0 3873. 3800 36 8 a020 3973e 3900 aT Il a13~ 4073. 4000 60 13 4250 4173. 4100 77 17 4370 ~273. 4200 97 20 4493 4373. 4300 119 22 46[5 4473'. 4400 142 23 4737 4573. 4500 164 ~858 4673. 4600 185 21 agBO 4773, 4700 207 22 5100 4873. 4800 227 20 5221 4973. 4900 248 53~1 5073, 5000 267 19 5461 5173, 5100 288 21 5583 5273. 5200 310 22 5707 5373. 5300 333 23 5831 5473, 5400 358 25 5956 5573. 5500 ~83 25 6083 5673. 5600 410 27 6209 5773. 5700 436 26 6334 5873, 5800 461 25 ~ 6458 5973, 5900 485 24 6582 6073. 6000 509 24 6705 6173. 6100 532 23 6828 6273. 6200 555 23 6952 6373, 6300 579 24 7075 6473, 6400 602 23 7198 6573, 6500 625 7320 6673. 6600 647 22 7443 6773, 6700 670 23 -. 7566 6873. 6800 693 7688 6973. 6900 715 22 7810 7073. 7000 737 22 TOTAL COORDINATES 130.52 S 155.39 $ 183.68 $ 215.61S 253.24 S 294.15 $ 337.85 S 3B3.24 S 427,66 S 474.53 S 520.78 S 566.51 S 610.67 S 654.98 $ 696.89 S 740.04 $ 785.11 S 831.95 S 881.07 S 930.79 S 982.55 $ 1036.59 $ 1090.67 S 1147.a0 S 1198.48 S 1248.43 S 1297.70 S 1347.99 S 1397,63 S 1447.18 S 1496.02 S 1545.40 S 1594.93 S 1643.26 S 1691.00 S 121.29 148.94 179.86 214.48 252.10 295.45 345.71 399.73 454.60 506.45 608.49 659.26 710,29 760.97 812,66 866.37 921.29 976.60 1033.16 1090.80 1145,26 1197.87 1244.20 1296.97 1348.72 1400.83 1504.69 1556.00 1607.56 1659.17 1710.46 1761.07 1812.24 ARCO DS 14-6 GYROSCOPIC SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 29 MAR 79 TRUE MEASURED VERTICAL SUB ND-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 7932 7173. 7100 759 22 8054 7273. 7200 781 22 8 176 7373. 7300 803 22 8298 7473. 7400 824 21 8419 7573, 7500 846 22 8539 7673, 7600 866 20 8660 7773, 7700 887 ... 21 8782 7873, 7800 909 22 8902 7973, 7900 929 20 9023 8073, 8000 950 21 9144 8173, 8100 971 21 9266 8273, 8200 993 22 9388 8373, 8300 1015 22 9510 84T~, 8400 1037 22 9632 8573, 8500 1059 22 9753 8673. 8600 1080 21 9874 8773, 8700 1101 21 9994 8873. 8800 1121 20 10115 8973, 8900 1142 21 10235 ':)073, 9000 1!61 19 10355 9173, 9100 1182 ;21 10476 9273, 9200 1;203 21 10597 9373, 9300 1224 21 10718 9473, 9400 1245 21 1739,28 S 1787-17 S 1834,75 S 1881.94 S 1928,50 S 1974,30 S 2020,23 S 2064,99 S 2107,77 S 21~9,48 S Z188,15 S 2226.28 S 2264,39 S 2303e48 S 2374,91 S 2407,76 S 2439.75 S 2470,70 S 2500.95 S 2531.42 S 2562,41S 2592,73 S 2622,93 S 1862,89 1913,91 1964,94 2015,53 2065,47 2114,59 2164.62 2217.56 2269,36 2323,27 2379,22 2437,63 2554.34 2612,61 2672,13 2731,38 2789,99 2849,53 2908e90 2968e70 3029,51 3150,48 ARCO DS 1~-6 GYROSCOPIC SURVEY 29 MAR 79 INTERPOLATED MEASURED DEPTH 1.000 2000 3000 4000 SO00 6000 7000 8000 9000 10000 VALUES FOR EVEN 1OOO FEET OF MEASURED DEPTH. TRUE VERT !CAL SUB DEPTH SEA TOTAL COORDINATES 1000. 927* 0.00 S OeO0 2000. 1927. 0*00 S 0.00 2.999. 2926. 16.23 S 4.74 3954. 3881. 209.54 S 208.0& 4789. 4716. 573.99 S 617,05 5607, 5534. 94B,67 S 1053e17 6412. 6339. 1.367.43 S 1473.42 7228. 7155. 1766.05 S 1891.26 8053. 7980. 2141e72 S 2312.83 8877. 8804. 2441,31S 2792.91 VERTICAL SECTION ATLANTIC RICHFIELD COMPANY DRILL SITE 14-6 RADIUS OF CURVATURE GYROSCOPIC SURVEY MARCH 29~ 1979 $200 ALL DEPTHS SHOWN ARE TVD 84O0 TVD = 9,541' TMD = 10,800' HORIZONTAL VIEW ATLANTIC RICHFIELD COMPANY DRILL SITE 14-6 RADIUS OF CURVATURE GYROSCOPIC SURVEY MARCH 29, 1979 I ALL DEPTHS SHOWN ARE TVD COMPLETION REPORT 26 MAR 79 ATLANTIC RICHFIELD COMPANY DS 14-6 .~MAGNET[C-' SINGLE 5-HOT SURVEY .................................. K'--B-EL'EV 73 FT ~[RA-D J US--OF'-CURVATORE NETHOD-OF--COMPUTATI-ON$ DECt:INAT l ON--31--DEGe .... EAST COMPUTED FOR A~DDCO BY FeN. LJNDSEy 'AND AS'$OC-IATES ........... ................................... RECORD OF SURVEY ALL' CALCULATIONS PERFORHED'BY [ B"H-"ELECTRO'N]C'COHPUTER $. DR 'T'-~/-ERT']CAL ...... SUB .......... DRIFT ........... ~'OT-AE.--C:OORD-I'NATES ................... -C--L'O"-'$'-U-'R-E DEPTH-A~GLE ........ DEPTH ........... SEA ....... DiREC ............................................................... D[~TANCE- -0' ...... -0- .... i5'4-0 .... 0"i5 ....... !5~9.99 2'~'77-=-2 ""~"5 ........ 2676~ 5i ....... 26'03,-'~ ....... $25~"00E ..... . :'-'~5 ........... 2923'97 i37"99 ........ 306~',99 8~0"'-~4'""'15 ...... 4~87.29 ~614~29 $49~00~ 3'3-30 ........ 6789 ~5 0 6252.07 6179.07 ........ 548,00~ ......... ~'300";5~ ..... S'-:-'~'35'4';4~'"'-~ ......... i877.77 i'9~'6-'-3'3-'45 ..... 8039. ,50'"'3~ 0 3322 .... ~2 15' 918~.25 91!2,25 $62.00~- ....... .................................................. MAGNETIC SINGLE SHOT SURVEY ........................ RECORD--OF~-SURVEY ALL-CALCULATIONS-'-PERFORMED-BY--I--B--M-'-EEECTRONIC"COMPUTER 26 MAR 79 TRUE .................... E 'HEA$*~DRI'FTVERTICAL ........ SUB ......... DRIFT DEPTH-'--ANGLE ..... DEPTH ........... SEA- "DIREC DISTANCE ANGE£ .............. D-'M ................................ ' .......... DEGe D DOG-IZEG SEVERTTY D-EGT~F '~' DiSTAl": '"]~0875' 33"-'45 ....... 9648,02 .... 9575,02 ...... S68,00~-'-Z&~'8~'4I-S- .... ~l'~,'83~77-~ ..... 41~l~*elg-""~-50-'-]'3-'li'¢--W -o,mooo. -BOTTOH'-'HOLE-'-CLOSURE '-- 4 I22 e'Ig'-'*FEET- AT ARCO DS X4-6 MAGNETIC SINGLE SHOT SURVEY 26 MAR 79 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, ............................ TRUE ......... MEASURED ..... VERTICAL-'SUB MD-TVD ................. VERTICAL- .................. ................ DEPTH '- DEPTH SEA DIFFERENCE -'CORRECTION ....... TOTAL COORDINATES .............. 1'73 ........................... 173' ........ 10'0 ................ 271 .......... 273, ..... 200 37-3 .......................... 373, ........ 300 ........... 0 ......................... 0 ......... O, ................ 473 ........................... 473e ......... 4-00 ......... 0 573 ....................... 573, ............. ~00 .......... 0 ......................... 0 ................................ O, .................. 673 ......... 673, .......... 600 ....... 0 .................................... 0 ....................................... 0e 773 ................ 773~ ......... 700 ............. 0 ....................... 873 ............. 873. .... 800 ..... 0 ....................................... 0 ......................................... O* .................. 973 ......................... 973; ........... 900 ............ 0- 0 '0 ...................... 1073 ............................. 1073e ............ I000 ................ 0 ............................ ............. 1173 ........................... 1173+' ......... I100 ............. 0 0 .......................... !273 1273. ............ I200 .......... 0 .................................... 0 .................................................. O. -I373 ...................... 1373 ~ ................ 1300 .................. 0 0' 0 ....................... 1473 ...................... 1473* ........ i400 ................ 0 ....................................... 0 .................................................... O, ............ 0 ........................ 0 ................................. 0', 04 N ............ 0-~ O0-'E-- ....... 0 ............................ 0 ................................... OelO N '- O"OR'-E 18 N ............ 0 ~'0-6--E 28"N ............... 39N ................ ~! N ............. 0e !t2--'E 62 N .............. 0-~-47'- E 72 N ................ 0,66-- E 81'N 0-~"87-- E 8 7"N ....................... I"~ I:I-"E 90" N ................. 89 N .................... ],-,6'5 ..... ~ B4'--'N .............. !573 ......................... 1573'; ...... 1500 ...................... 0 ............................. 0 O* 52-'N ............. ............................. 1673 ................................ 1673~ ........... I600 ................. 0 ................................. 0 ................................ 0e ~2'",~ ........................... I'77'3' .......................... 1773. ........... 1700 ..................... 0 ................... : ....... 0 ................ 1.i1' S ............. ............................. i873 ......................... 1873' ........... 1800 ......... 0 ............................................... 0 .................................................... Re/+3 $ ........................ 4 ~"I-9-'"[ ..... ............ l 97 ~ ............................. 197 ~ ~ ............ i9 00 ................. 0 ........................ 0' ................................... ~; 0 9-- S ..................... 5-~-I'3--E ............................. 2073 ............... 2073,, 2000 ..............0 ......................................... 0 ...................................................... 6.09 $ ...................... ...................... 2'i73 ................................ 2i 7'~, ............... 210o ............... 0 ............................ 0 .................................... tt;4~" 5 ..................... 7'~-~-i-'-E' ................... 2273 ....................................... 227:~ ;. ............. 2200 ................... 0 0 l!. ,;. i, 4' $ ........................... ................... ~73 ................................ 2373. ............... ~300 .............................................................................................. 0 0 14;18"S .................... 'i'0.~.6 E ............................... 2473 .................................. 2473. ........ 2400 ......... 0 ....... : 0 17'58 $ ........ ....................... ~S73 ......................... 2573* ............ 2~00 .............. b ..................................... 0 ............ 21,~3 ~$ ............... ........................... ~673 ............... 2673~ ........... 2600 ............ 0 .................................................... 0 ................................................... 25,43'$ ............... 16', 2S--E 2~7~' ................................. 2773* ............... 2700 .............. 0 .......................................... 0 ........................................ 30 ~'66-"-5 .................... I['7'~'82 .... E 2974 · 2900 I I 45,62 .5 ..................... 15-'~-07-E 307§ .............3073. ........ ~000 .............. 2 ........................... :t .................................................. §6,94 S ................... 3177 ........................... 3173~ ..... 310.0 ............ 3 ........................................ I ............................................ 70,78 ,5 ........................ 3279 :~7~,, 32oo '- ~ ............................................. 2 .................................................. 8~+,s9 $ ................... ARCO DS !4-6 MAGNETIC SINGLE SHOT SURVEY 26 MAR 79 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN IO0 FEET OF ,SUB SEA DEPTHe · ......................... TaU ......... MEASURED .......VER T ! CAL SUB .... ND-TVD ................... VERT ]: CAt: '_~i.--'-..'-_'i'L "_~ D?T_H _i..~..-_' .... '_ .... DE PTH_'~._ _~.EA"-~D ~?FERENC~'J~_~--~.~"._~9~.RE.~ T.~J.~. '2_"~ J_~ OT A.L' ................. COORD . , ...... 3695 ...................... 3673; ........ 3600 ........... 21 .... 5 ~65e05-S ............ 3802 ......... 3773, .... 3700 ........ 29 ............................ 8 ...................................... ~9~'Z2 ~9'10 ............. 3873, ....... 3800 ............ 37 8 220,69 'S ............... ............... '~02'1 ....................... ~973~ ........ 3900 ........... ~B ...................... 1I 25~'5 -&'367 'k27]* .... k200 ......9~ 1-9' ~7~'02'--S ....................... ~9 .................... ,~73. ....... ~00 .... 116 ...................................... 22 .......................................... ~20e35 ............... ~610 ................... ~7~ ~ ......... ~00 .......... 137 2'1~ k66'~ 17-"5 ........ '&8-5 3 4673 * ............ ~600 ......... 180 21' 556'* 50"-' S ......................... ~97~ ................ ~77~* ......... ~700 .... 200 ................................ 20 .............................. -5'09~- ................. ~'873~ .......... ~8-00 ......... 221' 21 6~5~'24'--'$-- ........................ ~55 ............................... ~17~' ............... 5'100 .......... 282 ........................... 2! ...................................... 776~9' ................... 5:5'76 .............................. 52~]. ........ 5200 ......... ~0~ .......................... 2 i-' ................ a22. .................................. 5699 ................... 5~7]. ......... ~300 ....... ~26 .......................................... 2] .................................................... 869.~ 6-072 ......................... ~67~'~ ........... 5600 .......... ~99 2'6 ................................... 1'0i~.2a- 6~22 ................................. 5'8~3. .......... 5800 ............ ~9 ............................ 2'5 ! ! i7. ~50-' S ................... -65-6 ~ ............................... 6073. ............. '6000 ........... ~96 ......................................................................... 2] 1215'29 ........................ 6692 ...................... ~17~, ....... 6100 ..... 5!9 ....................................... 2~ ................................... 12~'1~ 6'B1~ .......................... 62~' .......... 6200 .............. 5~1 ............................................. 22 .................................. .............................. 69]7 .............. 6~7]~ ............ 6]00 ......... ~6~ .............................................. 2~ ................................................ - ~059 ............................. 6~. ........6~00 586 ............................... : ............. 22 ................................ 1~05,00 ~"S .................................. ~18i ......... 65~ ....... 6500 ' 60B .............................................. 22 1~52,gl ......................... 7~0~ .......................... 66~ .......... 6600 ....... 63O ........................................ 22 ........................................... 1501.21 ........................ 7~25 ...... 67~. ' 6?00 ....... 652 ............................................ 22 ........................................ 1~9~5~ ARCO DS 14-6 HAGNETIC SINGLE SHOT SURVEY HEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTHe ..................... TRUE MEASURED VERTICAL-'SUB-' MD-TVD .............. DEPTH ........DEPTH -'SEA'DIFFERENCE 7'907 .................... 7173, ........ 7100 ....... 73-4 20 1731~03"-"$ ....... 1819~5'5-TtlI '8I¢7 ................ 7373*' -7300 .......... 774 ..... 20 I819'5!- ................. 826'6 ....................... 7473e ....... 7400 ......... 793 .................... : ..... ='19 ......................... 1863,~6 8386 ................. 7573;'-- 7500 .........8'13 ......................... 20' 1'907e'31" .................. 8506 ................... 7673, ..... 7600 ...... 832 ............................. 19 ................................ 1950,75 8626 .................. 7773'e .... 7700 ....... 852 20 -' 1993'64 .............. 8746 ..... 7873, *' 7800 872 ............................. 20 ............................. 2035.82 .............. 8866 ................... 7973. ........ 7900 .... 892 ................... 20 .................2077.60 ........................ 8986 .............. 8073e .... 8000 ...... 912 ........................................... 20 ................................... 2!18,75 ................... 9106 .......................... 8173' ........ 81'00 .......... 933 ............................. 2-1 ..................... 21~7'62 ............... 922'7 ................ 8273~ ....... 8200 954 ...................................... 21 ............................................ 219~,51 $ ...... 1917';-82--W $ ..... 1966~5~'-W 5 ........ $ ....2065'119--~' S ...... 21'15~5'5-~ $ 2166e'42-'~' $ ......... 2218~20--~ 9348 ................... 8373; ..... 8300 .............. 975 21 2230*40"$ 9468 ..... 8473, 84.00 995 ...................................... 20 .................. 958-9 ........................... 8573, .......... 8500 ..... 1016 2I 2299~91'$ ............................. 9'?09 ............................. 8673! .............. 86'00 ..... 1036 ...................................... 2'0 ............................ 233~37"$ .......... 261Ze9'1--~ ................ 9830 ........................ 8773e ......... 8700 1o57 21' 2366~6'$ .......... 2672~'0'~-'~ .............................. 9950 ........................ 8573~ .......... 8800 1077 .......................................... 20 '1007o ............ : .............. 8973, ........... 8900 ...... 1097 ........................... 20 2429*88 $ ........... 278~'~'02-~ 10~89 ...................... 907~ ..... 9000 '-~6 .................. 10307 .................... : ........... 9i73. ........... 9100 ....... 1134 ................................. 1'8 !0~26 .................. 927~. ......9200 1!52 ............................................. 18 1'05~5 ............................... 9373~ .......... 9300 ...... 1i7i ............................ l"~ i'0665 ...................... 9~73e ......9~00 ..... 1191 ........................ 10785 .......................... 9573, ....... 9500 1212 .......................................... 26 MAR 79 ARC:C) DS ! ~-6 HAGNETIC SINGLE SHOT SURVEY ~6 MAR 79 -iI~TERPOI~ATED VALUES FOR EVEN IOOO FEET OF MEASURED DEPTH, .............................. TRUE HEAsURED ..... VERTICAL ......... SUB DEPTH ...... DEPTH '- SEA TOTAL 1000 -'- 999e 926e 2000 ............ 1999' ........ 1926' ........... 3000 2998. --' 2925. 48e23 $ ............. 13,76-E 4000- ................... 3954; ......~881, 5000 ........... 4794, .......... 4721. .................... 6000 ...................... 561~; .......... 5542; .................. 958'3i ..... S-,~--I-~O?;?2-'W ~: ....................... .................. ?bOO .......... 6424. 6351, .... 1382.10 eooo .................... 72~0; ......7177; ............... .............................. 9000 ......... 8084* ......8011, ....... 212~,42-$72277;06'~'~~' .............. .............. 10000 ................. 89~I"; ........ 884i; ....................... 2~il;59'""$ ...... · · 648'-- ..... i.,, !. i. . Alaska Oil and Gas Conservation C~ission Hoyle H. Hamilton Chairman of the Comm~s~ign Lonnie C. Smith Commissioner Ben Le. Norman Petroleum Inspector t/arch 13, 1979 B,O.P.E. Test on A~co' s DS 14-6 Sec 9, ~, R14£, t~ ~onday, February .26 - I departed my home at 71OOAM for a ?:40 AH showup and 8:40 AH departure via Arco charter arriving at Prudhoe Bay at 10130 AH. I proceeded to West Sak #13 for an upcoming B.O.P.E. test, the subject of a separate report. Tuesday, Februaz-f_ 27 - Tests initiated on West Sak #13. Wednesday, Februa_ry 28 - Tests completed on ~est Sak t13 and SSV and SSSV tested' on~ell t7-6, the subject of a separate report. Thursday, Narch ! - Drilling Foreman for Arco on veil tl4-6vas Jack Hurray and 'Parker-Rig #176 Toolpusher ~as Dean Trout. Tests began at 9:30 PH with the shoe.on the 13 3/8" at 2717'. On the initial pressuring of the annular preventer someone clos. ed the valve on the 13 3/8~ casing head and, with the test plug not .seated, bleu the test joint and Kelly system out of the-hole at approximately 2500 PSIG and draped it over the ~rlnd wall. The test Joint, Kelly, and rotary hose v~re damaged and tests were suspended pending repairs. .~iday,_Na~h 2 - Tests resmu~d at 6110 Pm ~rlth the anuula~ p~eventer testing to 3000 PSIg. In tryin~ to test the pipe. rams it,s i~ t~ 5 I./2a pi~ r~ had not been chang~ after ~nin~ tub~ on the previous hole and tests ~ere again suspended at 6~30 PM to cha~e to 5~ r~s ~ ~ pipe r~ type preventers. Tests resumed at 7:30 PM with upper pipe rams, lover Kelly valve, o~tside valve on the kill line, and HCR valve in the choke line tested to 5000 We then performed the accumulator test with acctmmlator pressure at 3100 PSIG. With the pumps off the HCR valve was opened and annular and both pipe ram preventers.~cl~sed simultaneously. Pressure dropped to 1550 PSI¢ and remained steady. The pumps ~ere then turned on and pressure built 250 tSI.h twenty seconds and back to 3100 PSIG in three minutes. N~ backup bottles tested 2100, 2200, 2000, and 27~0 PSIG. Lover pipe rams then ~ested to 5000 PSIS. : The Kelly cock would not test as it was frozen and could not be ciosed~ due to ambient temperatures of -38'F. Check valve and hside valve in the kill line and inside valve in the choke line then tested to 5000 PSIS, B.O.P.E. test on 2 Arco' s DS 14-6 ~rch 13, 1979 While removing the test j oimt to test the blind r~ I checked tM locatiom which was well organized, reserve pit mil built, rig in good repair, but the well sign was not in place. Blind rams and ten valves and twenty-two flanges in the chok~ manifold tested to 5000 P$IG. However, one valve in the choke maaifold ~Duld not t~t. The mmual adjustable choke was free moving and the cameron aut~tic choke actuated. Both dart and ball type floor valves were in place. S._aturday. ~,r. Cb~ 3 - Tests were concluded at 12:20 ~ and a field inspection report prepared with a copy §ivea to Jack Hurray, a copy ~ailed to lob Hines, and the original attached to this report. I departed Deadhorse via Wien Fit #2 at 11500 AI~' and arrived in Anchorage via Barrow and Fairbanks at 3:00 PH and at my ho~e at 3:30 ~°nd. ay--._~.~ r:ch _5 - Jack Hurray called to advise the Kelly cock had been successfully tested to 5000 PSIG. ~er, parts to repair tP~ O-C-T valve in the choke manifold had not yet been received. A1 a Oil and Gas Conservation Commi ~e Field Inspect.ion Report Drlg. Permit No.~_~" ~,~o~, Well/~m Sec_~T/O/~/R/~E, UM Opera tor~~.~_ ...... Represented by/')~U~~ Name & Number _~r~ Satisfactory Type Inspection Satisfactory Type Inspection Yes No Item (~-)"Location,General Yes No Item (~-)"BOPE Tests ( ) (~ I. Well Sign (~'~ ( ) 15./~Casin.q set (~)~ ( ) 2. General Housekeeping (~wt" ( ) 16 TesL fluid-( )wtr.----~-~ )mud (~)~oil (~)~ ( ) ~. Reserve Pit-( )open( )filled (~F' ( ) 17 Master Hyd. Control Sys.-.~o~psiQ (~' ( ) 4. Rig (~ ( ) 18 N2 btls.~z~o~,~Z~.~,~,~-z~/p~' -. .~ ~ s ( ).Safety Valve Tests (~bT ( ) 19 Remote Controls ( ) ( ) 5. Surface-No. Welis~ (~-)~ ( ) 20 Drilling spool- ~ "outlets ( ) ( ) 6. Subsurface-No. Wells (~ ( ) 21 Kill Line-(~-~'Check valve ( ) Well Test Data (~/" ( ) 22 Choke Flowline (~'~HCR valve ( ) ( ) 7. Well Nos. , , , (~-~ ( ) 23 Choke Manifold No. valvs/~flgs~_ ( ) ( ) 8. Hrs. obser , , , (~)" ( ) 24 Chokes-(~emote( )Pos.(~dj. ( ) ( ) 9. BS&W _,--,--,-- (.~-' ( ) 25 Test Pluo-(~ellhd( )csg( )none ( ) ( ) 10. Gr. Bbls. , , , (,¢/~ ( ) 26. Annular Preventer~sie ( ) Final A~andonment -- (~-)~ ( ) 27. Blind Rams~-~.~._ ~psie ( ) ( ) 11. P&A Marker ( ~ ( ) 28. Pipe Rams~-~, psiq < ~) ( ) ( ) 12. Water well-( )capped( )plugged ( ) (~w~- 29. Kelly & Kelly-cock ~_psig ( ) ( ) 13. Clean-up (~/~ ( ) 30. Lower Kelly valve ~.~_~_p~sie ( ) ( ) 14. Pad leveled (~,~' ( ) 31 Safety Floor valves-/~-tBV (b~i~art Total insPection observation time~-~x.~.hrs/c+~ry~ Total number leaks and/or equip, failures Remarks/-~-"~~ c?~-/~ ~~ d'~ --c~ .-~.-~- ~,.-~_~c.~ c-- ,.~_~.~- ....,_~ · ~-~- · -~--< ~,~-~ ~'/~. ~:.z~ cc'~'~ //~/,v~- Notify in days or when ready Inspected by ~'~~ate~-~--~ ~{ichfieldCompany North Ame~ ican Producing Division North Ala~' District Post Offic"~.~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 28, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 7-10, Permit No. 78-77 DS 13-3, Permit No. 78-62 ~DS 14-6.,'~ermit No. 78-65 Dear Sir- .Enclosed please find a Monthly Report of Drilling Operations for the above-mentioned wells. VerY truly yours, P. A. VanDusen District Drilling En. gineer PAV' cs Enclosures STATE OF ALASKA JAY S. HAMMOND, C. OVERNOR ¢ ALASKA OIL & GAS CONSERVATION CO~MISSION 3001 Porcupine Drive Anchorage, Alaska 99501 February 5, 1979 Re: Prudhoe Bay Unit DS 14-6 Atlantic Richfield Company Permit No. 78-65 Mr. P. A. VanDusen District Drilling Engineer Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approved revised application for permit to drill the above referenced well at a location in Section 9, Township 10N, Range 14E, UPr4. Well samples, core chips and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log info~ation on all logs shall be submitted for copying except experimental l~s, veloc- ity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the reg'ulatations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commenc- ing operations you may be contacted by the ~abitat Coor- dinator's office Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3., Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Cod. e, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be con- tacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issu- ance of this permit to drill. ~. P. A. VanDusen Prudhoe Bay Unit DS 14-6 February ~, i~!~ To aid us in scheduling field work, we ~uld appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representative of the commission may be present to witness testing of blowout preventer equipment ~fore surface casing shoe is drilled. In the event of suspension or abandonment, please i gve ' ti this office adequate advance nottflca on so that we may have a witness present. Very truly yours, Hoyle ~. ~amilton Chairman ~7- ©~:~D~'~ ~ ~ ~©~]_~$S~0N , . Alaska Oil-'6"'-~as--~Conservatlon Commission Enclosure cc: Department of Fish and Game, Habitat Section w/o enclo. Department of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Labor Law Compl iance Division w/o encl. AtlanticRiC'hfieldCompany North Ameri~'-'~ Producing Division North Alask~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 25, 1979 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 14-6, DS 7-11, DS 7-12, and DS 7-14 Dear Mr. Hamilton: Enclosed find our revised Permit to Drill for the above mentioned wells. These permits replace those previously submitted. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:cs Enclosure Form 10-401 ' REV. 1-1-71 STATE OF ALASKA OIL AND (SAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK SUBMIT IN TR~'~ATE (Other instructions on reverse side) P ECEIVEL . DRILL I'~ DEEPEIq r--] b. TYPE OF WELL OIL GAS WELL [~] WELL ~ OTHER 2. NAME OF OPERATOR Atlantic Richfield Company P.O. Box 360 Anchora§e, Alaska 99510 4. LOCATION OF WELL Atsurface 1731 'S & 1129'W of NE cr Sec 9, TION, R14E, UM Alaska S'NGLE APz 5o-oe9-2o~0 6. LEASE DESIGNATION AND SERIAL NO. ADL 2831 2 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 14-6 10. FIELD AND POOL, OR WILDCAT ~ P r ud hoe Bay Field/Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Atpr°P°~dpr°d'z°ne1320'N & 1320'E of SW cr Sec 9, TION, R14E, UM Sec 9, TION, R14E 13.' DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. 3 miles NW of Deadhorse, Alaska · Federal Insurance Co. #8011,38-40 Amount $100,000 17. NO.ACRES ASSIGNED TO THiS WELL 14. BOND INFORMATION: T~E Statewi de Surety and/or No. 16. No. OF ACRES IN LEASE 1 320' I 2560 18. DISTANCE FROM PROPOSED LOCATION 119. PROPOSED DEPTH TO NEAREST WELL DRILLING, COMPLETED, I OR APPLIED FOR, FT. 2640' I 9618'TVD (10824'MD) 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, ff any) 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 73' RKB 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START Feb. 25, 1979 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 32" 20" 94# H-40 ll2 250 sx PF II to surface 17-1/2" 13-3/8" 72# MN-80 270,0 Circ. to surface-approx. 4500 sx 12-1/4" 9-5/8" 47# 80-95 10824 1 500+ cmt. column on 1st staae (approx lO00sx) plus 300 sx 6n 2nd stage Atlantic Richfield Company pro the Sadlerochit zone. Logs wi RSRRA BOP stack will be used. operationally tested each trip provisions for subsurface safe in all uncemented annuli withi poses to drill this well to 10824'MD (9618'TVD)'to produce 11 be run across selected intervals. A 13-5/8" 5000 psi The BOP equipment will be pressure tested each week & · A string of 5-1/2" 17# L-80 tubing, packer and necessary ty equipment will be run. A non-freezing fluid will be left n the permafrost interval. Selected intervals within the Sadlerochit will be perforated and reported on a subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work· Well will be flowed to production facilities during perforating and testing. The downhole safety valve wi 11 be i n- IN ABOVE SPACE DESCPdBE PROPOSED PROGRAM:If proposal is to deepen give data on present productive zone and proposedstal I ed and tested new productive zone. If proposal is to da-ill or deepen di~ectionally, give pertinent data on subdurface locations and measured and true Si o n o f t he j o b u po n conc l u- ,em~ depths. Give blowout preventer program. · 24. I hereby~~he _ _ SIGNED. ~. lC. F~~ (This space for State office us~) CO NDITI~NS OF A~PROV AZ, IF AN Y: ~ ~TLEDistrict Drilling Eng. SAMPLES AND CORE CHIPS REQUIRED n~s ~CNO DIRECTIONAL SURVEY REQUIRED J~YES [] NO MUD LOG [] YES ~NO OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE PERMIT NO.. q g"/.0._~"" APPROVAL DATE. APPOVED BY TITLE *See Instruction On Reverse Side Conservation August 23, 1978 Re: Prudhoe Bay Unit, DS 14-6 Atlantic Richfield Company 78-65 Mr. ~rank Brown District Drilling Engineer Atlantic Richfield Company P. O. Box 360 Anchorage, Ilaska Dear Sir: ~ :~v~ ~J Enclosed is the- approved*~ap~ltcatfon for permit to drill ~e a~ve ~ferenced ~11 at a l~a~ ~ ~~o~ 4, ~h~p 10N, ~nge 14E, ~. Well samples, core chips an~ a mud log .are no,: required. A ~~- tional survey is required. Many rivers in Alaska an4 their d-~a~-aqe systems_ have been classified as important for the s~tng oF m~- ~ation of ~- mous fish. Operations in .~m~ areas are. sub~t to ~ 16.50.870 and the r~ulations p~lag~ ~reu~r (Tttte 5, A~ka A~inistration C~). P-rtor ~- c~nc~ ~~io~$ you ~y ~ contend by ~e H~~t C~rdina~r's Off~, ~r~t of Pollution of any waters of the State is~t~by ~ 46, Chapter 03, Article 7 and the reguXati~p~lqa~ed (Title 18, Alaska Administra%lve Code, ~~ 70) and Pederal Water Pollution Control ~, as-.mme~.~'. meno~ng operations you ma~ be ~.~.~e~.~a the Department of Environmental Conserv&~lo~.. Pursuant to AS 38.40, Loc~l Hire under ~a~e. Le&~s, ~ &Xaska Department of Labor is being permit to drill. Mr. Frank Brown Prudhoe Bay Unit, DS !4-6 -2- August 23, 1978 To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representatt~ of the Division may be present to witness testing of blowout preven- ter equipment before ~urfa~e =asing shoe is drilled. In the event of suspension or aba~~nt please gt~ ~his of.fi~ adequate advance notification so ~at we m~y have a witness present. Very truly yours, Hoyl~H/.~~ami lton Chai~n Alaska Oil and Gas Conservation c~tt~ H~H:be Enclosure cc: Department of Fish and ~, Habitat Section w/o e~l. Department of Envirom~ental C~nse~tion w/o e~cl. Department of Labor, S~pe~isor, Labor ~ Compline Division w/o encl. Form 10-401" REV. 1-1-7! SUBMIT IN TRIPLICATE (Other instructions on reverse side) RECEIVED OIL AND GAS CONSERVATION GOMMITTEE Al 1~ t% .. 1 i978 PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL b. TYPE OF WELL OIL GAS WELL [] WELL 2. NAME OF OPERATOR OTHER DEEPEN [-'] Division of 0ti ann G~s b~.s~;,'vr~ti Anchorag~ SINGLE MULTIPLE ~ ZONE O ZONE L-] ATLANTIC RICHFIELD COMPANY 3. ~DRESSOFOPERATOR P.O. BOX 360 ANCHORAGE, ALASKA 4. LOCATION OF WELL At surface At proposed prod. zone 99510 1731'S & 1129'W of NE cr Sec .9, TiON, R14E, UM 1320"N & 1320'W of SE cr Sec. 4~ TiON, R14E~ UM 13. DISTANCEINmLESANDDIRECTIONFROMNEARESTTOWNORmST OFFICE* 4 Miles NW of Deadhorse, Alaska ' 14. BOND INFORMATION: r~EStatewide Surety and/or No. Federal. Insurance Co. #8011-38-40 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 3960' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2640' 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 73 RKB 23. 16. No. OF. ACRES IN LEASE 19. PROPOSED DEPTH 9393' TVD (10239'MD) · PROPOSED CASING AND CEMENTING PROGRAM 50-029-20328 $. 6. LEASE DESIGNATION AND SERIAL NO. ADL 28312 ~h IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 14-6 10. FIELD AND POOL, OR WILDCAT Prudhoe ~B~y F. ield/Prudhoe ~Oil 11. SEC., T., R., M., (BOTTOM Pool HOLE OBJECTIVE) Sec. 4, T10N, R14E 12. Amount $100,000 17. NO.ACRES ASSIGNED TO THIS WELL . 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATEWORKWILLSTART .Tan. 7: 1979 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SE~ING DEPTH Quantity of cement 32" 20" 94# H-40 112 250 SX P~ TT ~n ~,,r~noo ~7%" 15--$/8" 72# MN-80 2700 cJrc ~nn o~ 12~" q-5/8" 47# 80-95 9380 1500+ mint colnmn on 1st stag~ (Approx lO.OO ~w). pl,,~ qOO~.-on- 2nd R~" 7" 29# N-80 10239 250s× stage Atlantic Richfield Company propo ~es to directionally drill this well to +__10239'MD(+_9393'TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-3/8" 5000 psi RSRRA BOP stack will be used. The BOP equipment will be pressure tested each week & operationally tested each trip. A string of 5½' 17# L-80 tubing, packer & necessary prov- isions for subsurface safety equipment will be run. A non-freezing fluid Will be left in all uncemented alluli within the permafrost interVal. Selected intervals within the Sadlerochit will be perforated and reported on a subsequent report. A 5000 psi WP wireline lubricator tested to working pressure, will be used on all wireline work. Well will be flowed to production facilities during perforating & testing. The downhole safety v~lve will be stalled and tested upon conclusion of the job. The Sadlerochit zone will be cored. IN ~O~ SPACE D~CRIBE PROPOSED PROGRAM: If propo~l is to deepen ~e ~ta on present produc~e zone and proposed new produc~ve zone. If prO~ ~ to drill or d~pen ~ec~on~y, ~ve pe~ent dam on sub~ce locations ~d measured ~d ~ue ver~ depths. Give blowout pr~enter pro~. 24. I hereby ceLtify that the Foregoing,~ True and Correct DA~ 7-31-78 nTL~iSt Drilling Engineer (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED ~ NO DIRECTIONAL SURVEY REQUIRED ~YES [] NO MUD LOG [] YES CONDITIONS OF APPROVAL, IF ANY: [ OTHER REQUIREMENTS: F~ ~.NO [ A.P.I. NUMERICAL CODE ~ ~ ~ '? //~/'~ Auqus~ 23e Z978 PERMIT NO. APPOVED BY q ~" ~ ~" APPROVAL DATE ~-.~ ~ TITLE Chairm~n - - *See Instruction On Reverse Side DATE. 8/23/78 protracted sec!i6n line well~= I well weli~' 3 weil~4 well~5 SECTION 9 1252' r 1228' 1203' 179' f 1154' r weli~8 C~ IO8O' CERTIFICATE OF i HEREBY CERTIFY THAT I AM PROPERL~-~~~ ' AND LICENSED TO PRACTICE LAND SURFEYING ~,, .~ STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERV]SION, AND ALL DIMENSIONS AND .OTHER CETAILS ARE CORRECT. · A~UILT WELL NO. I LAT. 70°14' 2Z.346" LONG. 148~55' 05.97~ WELL NO.~ LAT. 70°14' Z:I. 189" LONG. i A. 8c~5' WELL NO. :5 LAT. 70° IA.' 20.035" LONG. 148° 14' 04.535" WELL NO. 4 LAT. 70° 14~ ! 8.$78" LONG. 145° 3.5' 03.81 WELL NO. 5 LAT. 70° 14' LONG. 14 8°35' 03.08~° WELL NO. 6 LAT. 70° 14' 17.7Z9" LONG. 145°35'03.084" WELL NO. 7 LAT. 70° IG' 15.416" LONG. IG~55' O! .639" WELL NO. 8 EAT. 70° 14' i 5 LONG. 148° 35' 00.917 Y 5 939 I95.35 X 675Z!7.39 Y 5 ~9 078 X 675 Z44.90 Y 5 938 961.67 X 675 Z7~.49 Y 5 938844.62 X 675 300.OZ Y 5 938728.35 X 675 527.78 Y 5 938 61 I X 675 355.4Z Y 5 938494.45 X. 675 382.95 Y 5 938 577.79 X 675410 13019'!6 EXISTING WELL OR CO N DU CTOR . ARCO No. HVL No. ATLANTIC RICHFIELD CO. AS-BUILT DRILL SITE No. IG WELLS I THRU 8 LOCATED IN PROTRACTED SECTION 9~TION~RI4E~U.M. PREPARED BY HEWITT V. LOUNSBURY ~ ASSOC. 723W. 6th. AVE., ANCHORAGE~ ALASKA DATE MAY 1978 SCALE I CHKD. BY G.D_ FIELD BK. CHECK LIST ~IDR NE~9 WET,T, PEP~IITS Cc~npsny :/~ d O 1. Is the permit fee attached ..................... Yes No Remarks 2. Is well to be located in a defined pool .............. r 3. Is a register~t survey plat attached ................ 4. Is well located proper distance, from property line ......... ~/~ 5. Is well located proper distance from. other wells . 6. Is sufficiont undedicated acreage available in this pool ...... ~ __ .7 ~Is ~ ' well to be devzated ....................... ) operator the only affected party ..... , ..... ..... Is 9. Can permit be approved before ten-day wait ............. /--- 10. Doe. s operator have a bond in force ................. 1.1.' Is a conservation order needed ................... Lease & W'ell No. Item. -(1) Fee 12. Is administrative approval needed ' -- 13. Is conductor string provided .................... ~/~ 14. Is enough cement used to circulate on conductor and surface .... ~ . 15. Will cement tie in surface and intermediate or production strings 16 ~qill cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones ........... ~ 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating - Test to ~ psig Approve Date (2) Loc. 3) Ad. min. -(5) BOPE ~p 20. ~--~q-s--~,~_>] ~qs'proved i,i~~--~raf~an ~ -(6) Plan Approval Recc~mended: Geology: Engine~e~in~g_: HWK ~ JAL ~ LCS ~~Bml / ' ' - RAD--- Revised 4/14/78 CHECK LIST !~IDR ~ ~T,T, P'EtI~ITS Cc~npany Y~2s.. ~ ' No Remarks [. Is the permit fee attached ..................... ~ 2. Is well to be located in a defined pool .... ' .......... Is a registered survey plat attached ................ Is well lOcated proper distance from property line ......... Is well located proi~r distance from. other wells .......... 6. Is sufficieqt undedicated acreage available in tJ~is pool 7. '~s well to '~a deviated ...... .'. ............... 8. Is operator the only affected ~party ................. 9. Can _permit be approved before ten-day ~eit ............. 0. Does operator have a bond in. force .... 1. Is a conservation order needed ................... 2. Is administrative approval needed ................. Item. Approve Date -(].) Fee i~----- ~' L~'7 3. Is conducLor string provided .................... 4. Is enough cement used to circulate on conductor and surface .... .5. Will cement tie in surface and h~termediate or production strings .6. "~gill c~nen{-, cover all known productive horizons ....... .... .7. Will surface casing protect fresh water zones ........... ~__~ .... .8. Will all casing give adequate safety in collapse, tension & burst ~ . ..~_~ (2) loc. __(3) Admin. /~ .~ (4) casg. .9. Does BOPE have sufficient~ pressure rating - Test to ~ psig. . ~ !0. Has D~,~Mapproved Plan of Operation ................ ~ ~dditional Requirements: -(5) PX)PE -(6) Plan Approval Recommended ~o!~: ~Jmeering Revised 4/14/78 .Well Histo.ry File APPENDIX Informati°n 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. .o DRESSER ATLAS 71G TAPE FORMAT ~(~.~t~ THE LAT~G TAPE FORMAT CONSISTS OF A HEADER RECORD CONTAINING PERTINENT INFORMATION CONCERNING THE WELL (SEE BELOW) FOLLOWED BY THE DATA RECORDS, THE HEADER RECORD) OF EACH CURVE, THE DATA FOR CURVE ! IS FOLLOWED BY THE DATA WHERE FEET : NUMBER OF SAMPLES OF EACH CURVE PER RECORD(I.E, 125) ********************************************************************************* ........................................................................................................................................................................... . :"-"7~ ........ .H~ ':'~',::?' ~F" ~ 'c'}~ ;"~:~ S ~,.,: :~,,~:.~;:~,:...:~::..::::~;. F=; ?~? = T':~?D~L :~2 ;2~<g-~'~ ::~ ~::~<: ::::~:~::~:-~L:.~:~- ;~;2~F~' ~":~'"~'? ~:'~C}~: · FIELD FIELD DESCRiPTiON POS%T~ON CHAR, : OF BYTES* · ~ EPILOG COmPUTATiON NUMBER ~ · 3 WELL NAME 85 · 5 FILLER 167 · 7 TAPE STARTING DEPTH 2~9 · 9 DATA LEVEL SPACING 257 2~0 FP · 11 FILLER 263 THE LAST RECORD 0 ATLANTIC RICHFIELD COMPANY .... DoSo l~ CIG .... LIBRARY DCC ltl~c~ 3 CURVES : ~f.,. ~ .. -~ ~.~ ~ .: ~ ~ .. ~ · LEVEL SPACING 0.5000 PAGE ATLANTIC RICHFIELD COMPANY .... D.S. 1~+ #6 .... LIBRARY DCC PRUDHOE BAY .... SEC 9-10N-lt~E .... NORTH SLOPE, ALASKA GR CCL CNL 780Q.50 50.82 O.qO $8.00 7802,50 55,~ 0,~7 ~9,~. 780~, 50 52,55 0,~7 ~1,1~ 7805,50 5~,95 0,$7 ~9,70 7~o7.5o ~.~z o.~7 7808,50 ~7,06 0,57 . _~..~..~.~.~.~ 7809,50 5~,29 0,50 7810,50 55,70 0,37 39,62 ,00 781 ~8 7B12.50 51. 781.-5.50 51 78t~,00 781q..50 56. ...................... 78..%5._,:..0.0 ..................... ~._.~ 7815.50 53. 7816.50 52.79 O. 57 ~.~_~.'i.'.~;7~i.,.9o ...................... 5..~,_,?~ ..................... i.i~, i!i~.~:!il 781_7,50 52,57 0,57 q.O,O0 7818.50 ~8.16 0.~7 37.12 ~'~'_~ ~,...o...~ ................. 5a,..~.!...._...~.~'~'.~.~Oj ~.~ 7819.50 52.22 0.37 36.~2 7820.50 ~8.82 0.~7 39.~2 7821.50 53.35 0.~7 ~7.58 7822.50 52.~8 0.~7 ~7.89 782~.50 51.86 0.57 ~9.~0 782~.50 53.82 0.37 ~7.25 PAGE 2 ATLANTIC RICHFIELD COMPANY .... D.S. 1N NG .... LIBRARY DCC PRUDHOE BAY .... SEC 9-10N-14E .... NORTH SLOPE, ALASKA GR CCL CNL 7827,00 5~,08 0,37 35.50 7828,00 53,53 0,37 37,6~ 7829,00 50,93 0.37 ~5.72 78~0,00 50,8~ 0,37 35,25 7852.00 50.8~ 0.$7 $~.50 7833,00 ~8,57 0,37 7834,00 49,95 0.57 7836.00 52,~q 0,~7 ~8,96 78B7.00 52, 7857°50 52,~ 7838,00 52, 7859.00 50, 78~0.00 qB. 78~1.00 ~7 78~2,00 q. 9,20 0.37 39.g3 78~3.00 ~9,58 0..57 57,50 78~,00 ~&.52 0.37 39,~2 ...... ~~. 5 o ~ ~. 6 e ........ 78~5.00 ~5.,6 O.S7 ~0,22 ~-':V~-~-;-~d- ............... '~";~'6 .................... 78~6.00 ~5,53 0,37 39,85 ......................................................................................................................................................... ;,.: ................................ :.._.. ,:: .,u..:: ,:..:: .;;&:,:L 78~7.00 ~1.87 0.~7 - .............................................................................................................................................................................................. :~: .-;~...:_..: ::: L.._, .i;:~:.:: ~ ............ ~ ......................................................................................................................................................... '...~_..< ....................... :...,....:,..;,,,..~.,.;,.._.,<:.:.., 78~9.00 ~7.69 O. B7 37.08 ................... 'l .............. ::::::::::::::::::::::::::::::::::::::::::::::: PAGE ATLANTIC RICHFIELD CO,~qRANY .... D.S, l~ #6 .... LIBRARY DCC ............... ~_R.U_DH...O_E _B.A.¥~.,~/~SEC...9,~...;~...O...N..., I~.E .... NORTH SLOPE, ALASKA GR CCL CNL 7851.50 ~9.11 0.~7 ~7.58 7852,50 ~5,~q 0,55 7S53.50 ~.05 0.37 37.26 7854.50 50.58 O. ~7 34.58 7855,50 ~7,15 0.37 ~7,09 785Z.50 ~5,63 0,37 38,20 7858.50 45,q2 0,37 5q.66 7859.50 qq,08 0,57 55,01 7860,50 q2,95 O. ~7 ~, 15 7861.50 qq.57 0,57 ~q,15 78~.5o 786~,50 ~2, 7865,50 786 7867.50 ~2. ~2 O. ~7 ~.~5 786~. 50 ~0.79 O. ~7 ~, 5& 7869.50 ~0.76 0.57 ~q.62 7870.50 37.~6 0.57 787Z , 50 ~5,75 O, ~7 ~, 5~ 7872.50 31.95 O. 57 ~. 59 787~.50 28,92 0.~7 787~,50 2~,68 0,~7 29,77 7875.50 2~.50 ~_~7 28.9~ . PA. GE ATLANTIC RICHFIELD COMPANY .... D,S, lq ~6 .... LIBRARY DCC ~q94 PRUDHO[ BAY .... SEC 9-10N-lqE .... NORTH SLOPE, ALASKA GR CCL CNL 876 · ~ 0 32 · 28 0 · 37 ~.q,~ ~:. ~':- :S:~~ :~-'i~/;.i ~i ~..i ....... -~. ~ ....... - - 787_'f~ ~_ 00 55,71 0,57 .~6,60 7878.00 q0,65 0.57 37.22 7879,00 q..y.,. 5q 0,57 3q,O~ 7880,00 51,99 0.57 ~5,10 7881,00 51,5~ 0.;57 788_2._..,...._00 q7,1G 0,57 788.3.00 ~9,50 0.;57 788~,.00 51o5~ 0.$7 41,17 7885.00 51,89 0.57 788G.00 50.71 0.;57 59.77 7887. O0 qB. 57 O. ;57 57,72 7887.50 51.97 7888.00 53. 0 3 ....... 7888.50 51.' 7889.00 50 q8. 7890.00 7890.50 q6.4 7891.00 ~5, 7892,00 52,q5 7893.00 qg.4G O,q5 qO,Gq 78~q,00 ~G,82 0,5~ 37,11 7895.00 51.38 1.16 789G.00 55.50 0.;57 7897.00 55,77 0,;57 7898.00 52.81 0.;57 ~9.99 7899.00 5l~, 5q 0.;57 ~8,07 ......... ......... ........... :::::::::::::::::::::::::::::: VV VV VV VV vv ~,E VV kE VV EE VV EE VV ~E~££EE VV kE VV EE VV EE EEE~EEEEEE RRRF. RRRR iiilli HRRRRRRR IIIIII RB RR ii HR RB 1I RR RR 1.1 RRRRRRRR ii ~2 RR ii RR RR II kR RR ii RR RR Ii RR R~ iiilli RP ~R 11iiii ¥¥ YY YY ~Y 000000 000000 5555555555 000000 OOO000 5555555555 O0 O0 O0 55 O0 00 O0 55 0000 O0 0000 555555 0000 O0 0000 555555 O0 O0 O0 O0 O0 55 O0 O0 O0 O0 O0 55 00 00 000o 00 55 00 00 0000 00 55 0O O0 00 55 55 O0 O0 O0 55 55 000000 000000 555555 000000 000000 555555 START* USER PCCC L107 ,55105] dOB SHiP SEQ. N .1 TOR R T* hE: DSKHIVERIF'~[,. 06,5~51051 CREAfE[): ,co ' s,1 5801 DATE 24-NAR-79 24-MAR-79 01129:23 01:42:50 __J PfiCI~IC COAST COMPUTING C~NTE~ i 0706,55105 REEL HEADER LENGTH: 132 6YTES REEL NA~IE: P.C.D.C. SERV 1CE - NA~15: ED1T REEL CONI'INUAIiUN NU£~I~ER: 0! PREVIOUS REEL i~AME: ~ COMMENTS: bis FOR~'~AT CUSTOMER TAPE DATE: 79/ 13/24 TAPE HEADER LENGTH: 132 BYTf. S TAPE NA~E: 55105 SERVICE NAME: EDiT TAPE CON'IINUATIUN NURSER: PREVIOUS fAP~ NA~E: COMMENTS: Ol DATE: 79/ 3124 EOF F~ILE HEADE~ LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECO~D LENGTH: PREVIOUS FtLE.,~NAM.k: 1024 BYTES WELL SiTE iNfORMATION RECORD .LENGTH: 189 BYTES COMPANY: WELL: FIELD: RANGE: TOWN: ECTION: OUNTY: STATE: ATLANTIC RICitFI~LD CO DRILL SiTE 14-6 1 4E lob 9 NORTH SLOPE ALASKA LENGTH: 610 ENTRY ~LUC~,S: 0 1 o6 o "DSTUMJSPkCI~'lCAT10N BLOCKS: 4TRY lC T(JOb SVURD~ UNI'IS APl AP1 AP1 APt FILk~ ~IZ~ EXP PROC SAM REP DEPT SHIFT Fl' 0 0 0 0 0 4 0 0 I 88 0 0 t~V 7 1 0 0 0 4 0 0 1 68 0 0 M M H(] 7 I 1 46 0 0 4 0 0 1 ~ 8 0 0 MMHO ? 11 44 0 0 4 0 0 1 68 0 0 MMH.O 7 21 8 0 0 4 0 0 1 68 0 0 GAPI. '7 31 32 0 0 4 0 0 1 68 0 0 US/I~- 7 52 32 0 0 4 0 0 1 68 0 0 GAPI q2 -%1 32 0 0 4 0 0 1 68 0 0 i N q 2 28 1 0 0 4 0 0 ,~1 68 0 0 G/C.% 42 44 0 0 0 4 O 0 1 68 0 0 P U 42 68 3 O 0 4 0 0 1 68 0 0 G/C3 42 ~5 1 0 0 4 0 0 1 ~8 0 0 C/C 42 42 1 0 0 4 0 0 1 68 0 0 CPS 42 ~4 92 0 0 4 0 0 1 68 0 0 CPS q2 34 93 0 0 4 O 0 1 08 0 0 10890.000 SP NCNL VALUE MN E.I'4tJN i C VAL 10800.000 SP NCNB -999.250 DT -999 0.079 NPHI 28 2984.000 PCNL 9~5 10700.000 GR NCNL -21.953 CILD 97.025 DT 0.082 NP~I 2552.000 ~CNb 10600.000 SP D~HO NCNb -59.313 CILD 40.531 DT -0.002 NPHi 3334.000 fCNL 10500.000 SP GR DRHO NCNL -]0.219 ClI.,D 65.06.3 DT 0.091 NPiii 3382.000 PCNb 10400.000 SP GR DRHO NCNL -17.]25 CibO 87.750 DT 0.062 NPHI 2518.000 FCNh 10300.000 SP GR DRhu NCNL -56.063 C1LD 36.438 DT -0.006 NPHI 3404.000 kCab i96 80 28 792 346 87 22 1172 186 76 21 1087 137. 69. 29. 826. 311. 84. 21. 129q. UE .250 .320 .000 ·621 .188 .809 .000 .883 .563 .754 .000 .453 .188 .973 · 00o 41.3 375 102 000 815 188 484 000 -59.250 CiLD 281.628 40.875 DT 83.750 -0.001 NPHi 24.512 3134.000 ~:'CNL 1042.000 10200-000 ~ SP -54.219: : CILD GR 37.781 DT DRHO 0.021 NPHI NCNb 2836.000 ~'CNL SP -62. 375 CiLO GR 3 6. 625 DT DRHO -0.010 NPHI NCNb 328 8 .O O 0 ~'C N L 10100.000 10000.000 SP GR N C N L 9900.000 1.17-216 100.188 29,248 895:ooo SP GR DRHO NCNL 37.669 76.563 0.020 13 3'000 -13.250 ClhO 511.488 97.875 Df 103.750 0.062 NPHI 39-30'7 1926.000 FCNL 491.500 -14.000 CILD 512.256 D1 101.750 NPHi 40.723 1881.O00 FCNL 458.250 ~NLMONiC V~bUE C iI.,M GR 138.625 ~HLJB 2. 592 MNEMUNiC VALUE, Chh8 ********** CALl 12.250 NRAT 2.852 CILa 218.244 CLL8 190.902 G? 104.875 CALl 13.094 RHOB 2.729 NRAT 2.902 CILM 326.531 CLL8 190.760 GR 35.063 CALl 12.336 RHO~ 2.418 NRA1 2.482 ClLM 187.959 CLL8 79.950 GR 61.000 CALl 12.500 RHOB 2.590 NRAT 2.434 Cih~ 132.163 CLL8 105.960 GR 87.688 CALl 13.695 RHtJB 2.607 NRAT 2.939 CILM 313.533 CLD8 212.978 GR 30.828 CALl 12.125 RHOB 2.303 NRAT 2.389 CiL~ 265.698 CLL8 176.796 GR 49.063 CALl 12.180 ~HO~ 2.404 NRAT 2·594 ClLM I41.O47 CLL8 112.676 GR 32.781 CALl 12.523 RHOB 2.395 NRAT 2.918 C,ILM 44.912 GR 35.469 RHLJB 2. 426 CLL8 39.409 CAL~, 12'242 NRA 2.295 CILM 559.563 CLL8 427.3'79 GR 104. 563 CALl 13. 742 ~}t[}~ 2..377 r~RAT 3.605 ClLM 539·231 CLL8 380.386 GR 1,06.500 CALl 14.406 RHtJ~ 2.404 ~RA'I 3.545 9800.000 9700.000 9600.000 9500.000 9400.000 9300.000 9200.0OO 9100.000 9000.000 8900.000 8800,000 MNkM(}bilC VAL, UI~ bP -~.500 GR 90,188 DRHO 0.01O tqCNL 1941.00o CiLO 547.594 DT 104.563 NPHI. 40,576 FCNb 465,250 MNEMONIC VALUi;. 5P -14.609 G~ 102.938 DRHO 0.013 NCNb 1873.00o CILD 703.297 UT i11.563 NPHI 47.119 ~CNL 424,250 CIbM 59~.279 CbL$ 413.510 GR 102.025 CAhI 16.313 HHOB 2.q71 t~HA'I! 3.606 SP -13.375 GR 106.31 ] DRHO 0.030 NCNb 1767.000 CIbD 685.408 OT 110,750 NPH1 43 701 PCNL 488[750 Clb~ 747.445 C~L8 528,380 GR 11J.000 CALl 13.758 RHOB 2.383 N~A'I' 3.963 aP -9.641 G~ 80.875 ORHU 0.044 NCNb 1765.000 ClbD 6t2.099 UT 109.750 NPt~I 41.~06 FCNL 415.000 C Ibt,~ 729.865 Cbbi~ 517.695 GR 109,000 CALl 13.688 RrtOS 2.361 NRA'I: 3.771 SF -14,041 C1LD 731,951 GR 97,375 DT 116,375 DAdO 0,013 NPHi 4~.777 NCNb 1786.000 ~CNL 4]4,250 CILM ~8,844 CUb8 410.915 GR 105.938 CALl 13.836 HH[]~ 2.420 NRAT 3.648 SP -14.109 GR 105.188 OReO -0.003 NCNb 1840,000 CiLD 6'17,597 DT I 15,750 NP}~I 47. 949 FCNL 41 1,500 CIbM 773,998 CUb8 606.035 GR 102,938 CALl 13.898 RHOB 2. ]73 NRAT 3.947 5P -14.359 GR 101.250 DRHU 0.055 NC:Nb 1780.000 CILD ~48.923 DT 111,.750 NPHi 39,502 [CNL 426.750 CIbM 727.273 GR 108.813 RHOB 2.320 GR 130 DRHO -O NCNb 1~73 ,828 ClhO 463 .875 DT 116 ,O05 NPHI 41 .000 f-CNL 454 CILM 680,399 GM 96.688 HHOB 2.381 SP -24.547 GR 140,000 DhH[J 0,011 NCNb 2110,000 CILD 349 DT 105 NP~I, 38 ~CNL 527 CUb8 521.916 CALl 13,477 NRAT 4.000 SP -23. 859 CiLD GR 152.750 DT DRtiU O, 029 N C I',t L ,1805.000 I:C ~ b CLL8 532,224 CALl 19,750 NRA 3.695 8P -1 1.859 CILD G,R 8 . 250 I D R H 0 .0 0 7 .N P }~i 1 l~CaL 2500-000 I~CNL .768 CILM 499,512 Cbh8 331 82I .188 GR 139,375 CALl 17:344 .357 RHOB 2,371 NRA~ 3.736 .750 .012 CI, LM 34'7,354 .188 G~ 170,750 .379 ~OB 2.438 .500 373,450 CiLM 389.947 1.16.563 GR 167,375 ~4 043 ~HOS 2,383 417~750 679.947 CILM 601.6t5 98,000 GR 114,438 37,012 ~HOb 2,451 670.500 CLLS 258.195 CALl 11 NRAT .. 7 11 502 CUb8 2~8,544 CALl 15,016 NRA'£ 3,824 ILL8 286.353 ALi 13,398 NRA 3.391 M NLMi)r,~ lC v ALU~ MN E;~qOf,~ lC VALUE, 8700.000 SP -:!,3.609 Cited 504.031 GR 150.250 DT 105.188 DgBO -0 . O03 hpliI .~ 4.766 NCNb 2076,000 t~CNL 5'7~.000 8600.000 SP -12.328 CILD 579.185 GR 151.000 OT 103.O00 DRHO 0.020 NPH1 30.914 NCmb 2052.000 ~C~L 548.500 8500.OOO SP -11,109 CILD 444.059 GR 151.250 DT 104.750 DRBO 0.029 NPHi 38.037 NCNb 2164,000 FCNL 578.000 8400.000 SP -8.359 ClbO 338.848 GR 148.000 DT 87.000 DBHO 0.013 NPHi 28.955 NCNL 2116,000 fCNL 700.000 8300.000 SP -1U.609 CILD 501.715 GR 164.500 DT 102.188 DRHO -0.001 NPHI 38.916 NCNL 2052.000 fCNL 551.500 8200.000 SP -12.125 CILD 447.552 GR 89.938 DT 92.000 DRHO 0,013 NPH1 29.102 NCNL 2424.000 FCNL 834.500 8100.000 SP -I2,859 CILD 433.898 GR 91,375 DT 94.!88 DRBO 0.017 NPHI 29.8 34 NCNL 2400-000 f'CNL '704,500 80:O0.O00:SP,:: '12,609 CiLD 386'124 GE 80.625 DT 91.750 DRHO 0,017 NPMI 30 225 NCNb 2576.000 ~'CNL 75b:000 7900.000 SP -13.859 CILD 4~2.094 GR 91,563 DT 95.000 DRHO 0'001 NPhl .33,203 NCNL 2446,000 ~CNL 710,000 7800, 000 g P -12.609 CIhD 492.308 R 87.688 DT 96.000 DRHO NPHI 42~871 NCNB ~'CNb 688 500 7700.000 SP -I4.O78 CILD 483.475 GR 92,500 OT 94 188 DRHO 0.062 NPHI 44~580 NCNb 2654,000 ~CNL 7]0.000 iqNLMONiC VALUE Clh~ 49'7.570 GR 156.625 RHOB 2.441 CILM 583.143 G¢ 179.000 RHOB 2.443 Cib~ 554.'713 ~R 179.875 BHOB 2.393 ClbM 344.086 GR 154.125 sMOg 2.416 C1LN 537.251 375 RH(3B 02 CILM 457.961 GR 100.188 RHOB 2.401 CIL~ 442.524 GR 98,875 BHOB 2.418 CiLM 399.055 GR 92.500 RHOB 2.414 ClLi~ 474.074 GR 95.000 RHOB 2. :i96 CILM 510.723 GR 91.375 SMOb 2.420 CLL8 CALl NRA~ Chh8 CALl NRAT CLL8 CALl NRA'I Chh8 CALl mRAT CbL8 CALl NRAf Chh8 CALl NRAT CLL8 CALl ~ RA'I Chh8 CAbi NRAT Cbb8 CALl NRAT Chh8 CALl NRAT VALUE 275.71~ 13.953 3.281 246.866 13.625 3.393 389.650 13.953 3.463 130,280 13.188 2.914 371.014 14.844 3.535 39'7.824 15.328 2.982 378.418 15,469 3.033 3.055 415.584 15.344 3.256 451.898 2,635 3,098 C Iht~t 502.207 CbL8 419.672 GR 2.250 CALk 2.641 }{HOB 2 . 434 NRAT 3 . 195 DEPTH 7600.000 7500,000 7400.000 7300.000 7200.00o 7100.000 7000,000 6900 .OOO 6800.00o 6600.000 vALUE SP -1'i.009 CibO GE 97.563 DT NCNL 2552.000 FCnL SP -lb.125 CILD G~ 112.063 DT DRHO 0.032 NPHi NCNb 23i2.000 fCNL 6P -19.078 C1LD GR 93.313 DT DRHO 0.004 NPhI NCNb 2418.000 }CNL SP -17.078 CILD GH 102.625 DT L)RhO 0.061 NPtiI NCNL 2158.000 bCNL SP -18.609 CILD GR 81.938 DT DRHO 0.206 NPH1 NCNL 2314.000 ~'CNb SP -17.578 CiLD GH 83.375 DT DRHO 0.090 NPHI NCNL 2530.000 ~CNL 5P =14.797 CILD GR 84.125 OT DRfiO 0.035 NPHI NCNL 2565.O00 FCNL SP -20,359- CiLD GR 70.813 bT DRHO -O.00b NPB1 NCNL 27.34.000 FCNL SP -20.359 CILD GR 74.750 DT DRHO 0.006 ~PHI NCNL 2564.000 ~'CNL -39,750 CILD 52.5~3 DT DRHO · O.0q3 NPH1 NCNL' 3974.000 FCNL SP -57.625 CILD G,R D T DRHO NPH I NCNL 2306.000 V A 1~ 0 E ~84.384 92.188 42.2~5 7~5.500 532.778 104.750 53.564 481.750 ]10.471 96.375 i1.113 541.500 452.297 100.750 52.002 588.500 369.408 97.1.88 46.973 70~. 000 296.984 95.375 O0 369.142 92.375 43.848 8'71.500 280.088 9O.750 36.523 91,1.000 350.445 95.3'75 ~2.529 754.500 239.925 59.188 18.994 2048.000 340.425 93.000 39.355 ~66.500 M N k, ivl~jN lC VALUE M,~EiqOmlC VALUE Clb~vi 400.940 Cbb8 322.621 GR 87.125 CALl 2.631 MHOD 2.518 NRA'~ 3.066 C 1 L t~ RHI]~ C C GR SHOB 558.038 Cbb8 414.239 139.125 CALl 2.713 2.357 NRAT 3.597 393.5q3 CLL, 8 34~.~33 102.813 CAhI . 05 2.49~ NRAT 3.004 495.644 CuL8 357.792 107.438 CALl 2.689 2.414 NRA1 3.~09 372.906 Chh8 333.550 81.750 CALl 2.68~ 2.590 NRAT 3.32t CiLS GR ClLM 302.422 CLL8 25(~. 1'12 GR 87.i25 CALl 2. %64 RH[]B 2.410 NRAT 3.~18 CILM 378.139 Cbb8 38~.521 GR 88.250 CALl ].676 RHO~ 2.424 NRAT ~.154 ClLM 273-067 CLL8 GR 90.438 CALl RHOB 2.334 NRAT 8 -978 2.652 2.748 CILM 355.970 CLL8 332.036 GR 74 . ~i 38 CALl 2 . 654 RHOi5 2.389 NRAT 3.080 175.58.3 CLL8 48. 157 48.8zi4 CAL~ 2.631 2,678 NR%% 1.638 298.368 ,'tLS 70.~25 l~Abl 2.389 'RAT CiLM GR CIL~] 199.688 2.693 2 6500.000 6400.000 6300,000 6200.000 6100.000 6000.000 5900.000 5800. OOO 5700.000 5600-000 5500.000 Ni,~EH[]N iC VAL{JE PiNIi, MON iC VAI,tJE 8P -33.500 CILD 211 GR 88.438 UT 99 DP, HU 0. O19 NPHI 46 NCNb 2 i142. 000 i,'CNL 713 .330 CILM .563 GA .533 RHOB .000 SP -q5.250 CiLD 390 GR 69.063 DT 90 DRHO -0.013 NPHi 44 NCNL 2012.000 ~C~L 070 .542 CILM .750 GR .043 RHOD .500 5P -39.09~ CiLD 273 GR 75.750 DT 98 DRH(J 0.001 NPHi 50 NCNb 22J8.000 FCNb 547 VALUE NNEMONIC VA~UE 8P -72.563 CIbD 692 GR 64.250 OT 96 DRHO 0.063 NPHI 41 NCN~ 2428.000 ~CNb 952 28'7.640 CLL8 276.1~0 107.813 CALl 2.658 2.436 NRA'I 3.303 8P -84.500 CILD 1013 GR 38.063 DT 104 DRHU 0.055 NPHi 43 NCNb 2456.000 ~CNL 722 376.7 %{~ CLL8 283.656 7 4.1%0 CAI, I 2.660 2. ~32 N~AT 3.164 SP -65.438 CILD 469 GR 57.875 DT 99 DRHO 0.019 NPHi 56 NCNb 2420.000 FCNL ~31 .067 ClL~ 2a8.776 CLL8 267.923 .375 GR 89,188 CAUl 2.648 .000 RHLJD 2,389 NRAI' 3.494 .500 SP -71.438 CILD 584 GR 48.781 DT 87 DRHO 0.003 NPHi 23 NCNL 2838.000 ~'CNL 1238 .3~0 CiLM 544.681 CUb8 220.120 .375 GR 71.500 CAbi 2.~48 .406 RH[)~ 2.210 NRAT 3.018 .000 &P --61.750 CIhO : ~83 GR 48.375 DT 94 D~HU -O.01~ NPMI ~2 NCNb 2476.000 ?CNL 7'74 .375 C ILP} .0U0 GR .799 ,RHUD .500 SP -39. 000 CILD R 53-531 D~ R,HO 0.013 NPt~I NCNb 256 2,000 ["CNL 869.270 CLL8 310.86~ 25.906 CALl 2.65~ 2.230 NRAI 3.130 8P -72.875 ClbO GR 35.938 DT DRHO NP:M I N C N L ~ C N L, .725 CILM 418.301 CLL8 216. '65 .375 GR 49.719 CALl 2.~ 84 .934 tiH[JB 2.281 NRAT 3,~81 .500 SP -33.21,9 ClLD GR 6~.219 DT DRHO . 052 NPH i NC~IL 1830.000 FCNb .475 C iL~vi .375 GR .O00 .4-75 CiLN .188 GR .627 .000 474.513 CUb8 10%.'728 34.875 CALl 2.652 2.547 NRAT 1.962 415:.599 CLL8 242.884 51.094 CALl 2.684 2.303 NRA~ 3.088 435.374 CIbM 411.907 CLL8 280.394 10.3.750 GR 65.688 CALl 2.654 44..~36 RHOB 2.307 NRA~' 3.182 679.500 ~1.2.807 CIbN 510.409 CLL8 232-305 104.000 GR 43.844 CAbI 2.637 36.426 RH[JD 2.285 NRAT 2.742 941.000 384.384 CILM 357.542 CUb8 27~.110 111.~75 Ga 59.875 CALl 2.660 ~0.254 RHUB 2.291 NRAT 4.003 522.500 DE~TH 5400.000 5300.000 5200.000 5100.000 5000.000 4900.000 4800.000 4700. O00 4600.000 4500,000 4400.000 M i,;E ~o b,i JLC V/qLUE 8P -32.03~ CILb GR 59.90 DT DRt~O -0.002 NPHi NCNb 2404.000 ~CNL · VAbUE 30O. 117 114.750 54.346 5?5.000 SP -22.031 CILD .306.771 GR 75. 000 D'i 105. 000 OReO 0. 021 NPHI 4~9. 658 NCNb 2000.000 ~CNL 578.500 SP -57.500 CILD 5~8.664 GR 50.063 DT 112. {75 DigHt 0. 004 NPM1 5zi. 004 NCNB 2594.000 [~CNL 688.500 SP -29.609 CILb 248.062 GE 63.21.9 DT 99.188 DR~O 0.024 NPHi 55.908 NCNb 2118.000 FCNL 476.750 8P -3~.813 CII, D 210.526 GR 73.938 DT 103.563 DRHO 0.095 NPHI 49.41~ NCNB ~919.000 f~CNL g79.750 SP -36.531. CILD GR 45.688 DT .DRHD 0.030 NPhI NCNb 1377.000 FCNL SP -65.313 CiLD GR 47.156 DT DRHO 0.020 NPHi NCNb 2368.000 f'CNL 8P - 32.250 CtLU GR 23.938 DT DlqMO -0.033 NPHI NCNB 2026.000 FCNb SP -51.875 CIhD GR 59.219 DT DRMO -0.001 NCNB 2506.000 ~'CNL $? -32.438 CILD G~{ 73.375 DT DR~O 0.027 NPM~ NCNL 2254.00{) [~ Ci~'~ SP -~7.063 CILD R 84.625 DT RH(3 0'061 NPHI NCNB 1748'000 f'CNL 134.454 135.125 47.461 423.750 510.214 122.375 46.14.3 736.500 MNL!q(]N iC VALUE MN~JMONIC CILM 292.906 CLb8 GIq 64.31 3 CALl b~i[3b 2. 158 NRAT VALUE 25~.340 2.652 3.738 CiLM 32~.531 ~bb8 313.150 hR 6 .063 AL1 2. 660 RIiOD 2.328 NRAT 3.47~ C1LM 479.~01 CLL8 287 t~R 5 3. 531 CALl 2.67.6 RI-iUD 2.1 99 NRA'I' 3. Chh8 CALl N RAT CiLM 234.432 b~ 85.188 1~ HOtJ 2. 363 278.1 I0 2 3,822 CiLM 196.319 CLLB 21i.625 GR 82.188 CALX 2.646 RHOB 2.322 NRAT ~.463 CILM 130.746 Chh8 165.803 GR 37.g06 CALl 2.641 MHOB 2.061 NRAT 3.354 CILM 445.993 CLL8 278.71 GR 55.188 CALl 2.~48 MHtJB 2. 129 NRAT 3,~28 266.528 CILS 247'582 119.000 GR 72.750 46.973 ~hOB 2.295 533.000 CiLN 290.085 GR 56.719 RHGB 2.225 CiLM 232.516 UR 76.313 ~HOb 2.369 CIbM 273.9'~3 Ga 83.81 3 RHOB 2.204 32b.739 109.375 48.340 586.500 CALl. NRAT CLL8 CALl CLL8 CALl NIdAT CLL8 CALl NRAT 217.31,7 1,26.750 50 586 ~83:000 239.~25 I25.750 63.867 476.750 ~.328 .792 2.684 .404 218.244 2.66b 3.529 261.893 2.643 4.262 V AL tie t4t~Et4~Jl~ .lC VALUE 4300.000 $? -37.750 CIbD 200 GR 71.O88 OT 122 DRht~ -0.003 mP~ii 58 NCNb 1972.000 ~CNL 49] .785 .000 .740 .000 4200.000 Sp -40.625 C1LD 182 G~ b6.750 bT 111 DRHO 0.021 NpHI 40 NCNE 2230.000 ~'CNL 653 .727 .75O .576 .000 4100.000 5P -38.344 CiLO 184 GR 71.188 OT 120 O~.liO 0.079 NPHI 59 NCNb 1879.000 FCNL 375 .57! .375 .912 .750 4000.000 8P -39.90~ CILD 146 GR 70.000 DT 121 DEHO 0.018 NPMI 58 NCNb 2027.000 bCNb 438 .280 .375 .301 .250 ]900.000 St~LMON lC 3800.000 CIL~q 3700.000 VAbUk MNEMONIC 3600.000 VALU~ 200.313 Cbb% 210.873 82. 438 :,t~LI 2.643 2.273 ~RAT 3. 980 3500.000 180.536 Chh8 154.031 61.000 CALl 2.660 2.338 NRA~ 2.971 CILM 194.825 CLL8 177.654 GR f16.gJ8 CALl 2.646 RHO5 2. ~16 NF~AI 4.047 ClEM 1.56.671 CLL8 1~7.381 GR 9~.125 CALl 2.052 RHOB 2.316 NRAT 3.957 SP -59.219 CibO 205.788 ClEM GR 53.844 DT 11'7.750 G~ OReO 0.O17 NPH1 53.602 ~HijB NCNb 2052.000 ~C~L 486.250 141.986 124.000 -99925.000 -999.250 SP -40.000 CiLD Gk 78.438 DT DRHQ -999.250 NPH1 NCNb -999.250 ~'CNU SP -44.625 CILO GR 67.875 DT DRHO -999.250 ~Ptti NCNb -999.250 FCNL 1~4.172 118.563 -99925.000 -999.250 SP -52.O94 CIbD GR 63.56~ DT DRHO -999.250 NPHi NCNb -999.250 FCNL 13'9.055 112.188 -99925.0OO -999.250 SP DRHU NCNb -48.906 CIE[) 67.563 DT -999.250 NPH1 -999.250 fCNh 127.554 -99925.0,0 -999.250 CiL~ GR HHOS C I i.,M GR 1~ ~ U B 201.258 CLb8 177.040 4.1.344 CALl 2.670 2.123 NRA1~ 3.699 149.971 CEE8 -999.250 CAbi -999.250 NRAB 139.891 CLL8 -999.250 CALl -999.250 N~AT %ibm 140.120 CBL8 GR -999.250 CALl MHO~ -999.250 NRAT CILO 160.401 DT 126.000 t~CNL -99 250 3400.000 SP -43.531 (;}~ 73.500 :RHU -999.250 CNL '999'250 3300.000 C ILM i~HOB CiLM GR CIbM RHOt~ 128.450 CLL8 -999.250 CALl -999.250 NRAT 105.482 CEE8 99 50 NRAT 185.239 Cb1,8 -.999.~50 CAbI 999,250 NRAT CibO 187,821 DT 117,750 NPHI -99925.000 FCNb '999,250 SP -56.281 G~ . 53.313 DRHO 999.250 NCNb -999.250 146.873 -999.250 -999.250 150.612 -999.250 -999.250 1 26.92 l 2999.250 ,999,250 121.557 152.019 -999.250 -999.;50 -999' 3200,000 3100,000 3000.000 2900.000 2500.000 2700.000 2600,000 2590-000 SP GR NCNL SP D l~ H (.J NCNb DRHO SP DRHO SP GR NCNL SP GR NCNL SP GR DRHO NCNL SP DRHU NCNL VALUE ivlN ElqU[~ iC VALUE -35.281 CILD 193.500 CILN '77.438 OT 132.500 GR -999.250 ~PHI -99925.000 R~O~ -999.250 ~C~L -999.250 -36.750 CILO 285.237 7q.438 DJ' 141.750 -999.250 NPH1 -99925.000 -999.250 ~'CNL -999.250 -36.250 CiLD 335.958 65.188 DT 140.125 -999.250 NPHi -99925.000 -999.250 ~CNL -999.250 CILM CILM GR -b4.188 CILD ~59.]b9 CILM 37.375 DT 1~2.000 GR -999.250 NPHI -99925.000 HBUB -999.250 FC~L -999.250 -60.313 CiLD 650.410 CILM 44.088 DT 151.000 GR -999.250 NPHI -99925.000 RHOB -999.250 P'CNL -999.250 54.594 CILD 0.500 35.188 DT ~4.750 -999.250 NPMI -99925.000 -999.250 F'CNL -999.250 62.094 CILO 0.500 37.906 DT 57.~75 -999.250 NP~I -99925.000 -999,250 b'CNL -999.250 61-875 CILD 0.500 41.594 DT 5~.781 -999.250 NPflI -99925.000 -999.250 FCaL -999.250 C1LN GR CIL~ GR CILM VALUE 206.452 -999.250 -999.250 288.288 -999.250 -999.250 335.768 -999.250 -999.250 594.312 -999.250 -999.250 584.475 -999.250 -999.250 45.682 -999.250 -999.250 37.603 -999.25~ -999.250 -999,. ~,~0 MNESONIC Cbb8 CALl NRAT CLL8 CALi NHAT CLDB CA',~ CLL 8 C~;I NPAT Chh8 CALl NRAT CLL8 CALl NRAT NRAT ;7t.009 -~9 ). 250 -999.250 2~4. 736 - %~..9. 250 -5.99. 250 264.736 -999.250 -999.250 360.310 -999.250 -999.250 407.643 -999.250 -999.250 1052.956 -999.250 -999.250 1058.945 -999.250 -999.250 -999.250 (. ( SUMMARY O~ DAIA FIECUSD6 NUMBER OF RECURDS: 1038 BENGTH Dr RECORDS: 966 ~T£8 LENGTH O~ LAS'i ~ECO~O: 546 B¥'IES FILE TRAILER 1024 LENGTH: t2 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORO LENGTH: NEXT F1LE NAMEi: EOF TAPE TRAILER LENGTH: 132 BYTES TAPE.NAME: 5105 SERVICE NAME~ ' El)iT TAPE CONTINUATION NUMBER: O1 NEXT TAPE NAME: COMMENTS: DATE: 79/ 3/24
