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192-018
C :LORi'~'ILlvI*DOC PLUGGI_'~G &LOCATION CLA~_R~'NCE REPORT .%er±aw ~h~.e well file, an~' c~,~U =n pluq~inq, well hea~ s=a=us, az~ !oca=i:n clearance - 9r~i~e loc. clear. ._ , ~.. c.,,d-,.~-:~~~. ~ 7~~~- " ~ STATE OF ALASKA ' ALAS~-,,~ OIL AND GAS CONSERVATION CO,,,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 192-018 300-028 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21132-01 4. Location of well at surface 97' NSL, 846' NWL, SEC. 11, T10N, R15E, UM At top of productive interval 2724' SNL, 503' NWL, SEC. 14, T10N, R15E, UM At total depth 2858' SNL, 588' NWL, SEC. 14, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB = 62' I ADL 028332 12. Date Spudded 113. Date T.D. Reached 114. Date Comp.,.Susp., or Aband. 4~6~92 I 4~9~92 I 2/16~2000 17. Total9978 Depth (MD+TVD)J 18.9213 FT! Plug 9848 Back Depth9095(MD+TVD)119'FT Directional[] Yes []SurveyINo 22. Type Electric or Other Logs Run CHT / TEMP / GR / CN / AC / DIFL 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 03-34A 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 116. No. of Completions N/A MSLi Zero 20. Depth where SSSV setI 21. Thickness of Permafrost N/A MDI 1900' (Approx.) 23. CASING SIZE 20" 13-3/8" 9-5/8" . WT. PER FT. CASING, LINER AND CEMENTING RECORD SE'lq'lNG DEPTH Hc3LE I TOP BO'FrOM Ii IZE !'"] CEMENTING RECORD, Surface 110' ~0', !1865 # poleset Surface 2501' -1/2" 12.300 sx Coldset III Surface 8010' -1/4" 1500 sx Class 'G', 300 sx Coldset I 7742' 9978' 1/2"'"'~26 SX Class G' / 25. Conductor 72# 47# 26# GRADE H-40 L-80 L-80 L-80 / 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) None MD TVD MD TVD 26. AMOUNT PULLED TUBING RECORD SIZE ! DEPTH SET (MD) PACKER SET (MD) 3-1/2", 9.2#, 13CrI 8515' - 9255' 9187' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED 8899' i P&A with 38 Bbls of Class 'G' 7565' Set Whipstock 27. PRODUCTION TEST Date First Production Not on Production Date of Test Hours Tested Casing Pressure Flow Tubing Press. Method of Operation (Flowing, gas lift, etc.) N/A PRODUCTION FOR OIL-BBL IGAS-MCF TEST PERIOD CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE WATER-BBL WATER-BBL ICHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-APl (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 APR 20 2000 Alaska 0ii & Gas Co~s. C0r~}missi0n Anc. h0r~ge Submit In Duplicate 29. Geologic Markers 30. Formation Tests ................................... Measured True Vertical Include interval tested,' pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Base HRZ 9436' 8924' Shublik 9505' 8993' Top of Sadlerochit 9595' 9083' APR 2_0 2000 . , Alaska Oil & Gas Cor~s. 3J. List of A~achments: summary of Daily Drilling Repeals 32. I hereby cedify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~~ ~ Title TechnicalAssistantlll Date 03-34A 192-018 300-028 Prepared By Name/Number: Terr/e Hubb/e, 564-4628 Well Number Permit No. / Approval No. .................... INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 03-34 DESCRIPTION OF WORK COMPLETED PRE RIG WORKOVER / SIDETRACK CEMENT PLUG & ABANDONMENT Date Event Summary 2/12/2000: 2/14/2000: 2/16/2000: 2/20/2000: 2/21/2000: RIH & drifted to 9720' SLM. MIRU CTU & PT'd equip. RIH & killed well. FP'd well. A CTU Cement plug was pumped to Plug & Abandon the lower wellbore prior to Rig Sidetrack Operations as follows: CTU on location. RIH & tagged PBTD @ 9660' MD. Pumped 30 bbls of 15.8 ppg Class G Cement to plug & abandon the open perforations located @: 9482' - 9500' MD (Sag Zone) Reference Log: BHCS 4/11/92. 9611' - 9640' MD (Zone.4) 9753' - 9763' MD (Zone 4) 9777' - 9788' MD (Zone 4) 9796' - 9806' MD (Zone 4) Did not obtain returns during entire job. Contaminated Cement w/Biozan & cleaned out cement to 9320'. POOH. WOC. RIH & tagged TOC @ 9506'. Pumped an additional 7.5 bbls of 15.7 ppg Class G Cement to bring TOC to - 9320'. POOH. FP'd well. RD. WOC. RIH & tagged TOC @ 8899' MD. PT'd tubing to 2300 psi for 15 minutes - passed. RIH & cut tubing @ 8515' MD w/chemical cutter. Continued w/03-34A RWO / Sidetracking Operations. APR 20 2000 ~Jaska Oil & Gas Oo~'~,s, ()ommissio~ Anchorage Facility Date/Time 01 Mar00 02 Mar 00 03 Mar 00 PB DS 03 Progress Report Well 03-34B Page 1 Rig Nabors 9ES Date 27 March 00 21:00-06:00 21:00-06:00 06:00-06:00 06:00-09:30 09:30 09:30-19:30 19:30 19:30-23:00 23:00 23:00-06:00 06:00-08:30 06:00-08:30 08:30 08:30-14:00 08:30-11:00 11:00 11:00-13:30 13:30 13:30-14:00 14:00 14:00-17:00 14:00-14:30 14:30 14:30-17:00 17:00 17:00-23:30 17:00-20:00 20:00 20:00-23:30 23:30 Duration 9 hr 9 hr 24 hr 3-1/2 hr lOhr 3-1/2 hr 7 hr 2-1/2 hr 2-1/2 hr 5-1/2 hr 2-1/2 hr 2-1/2 hr 1/2 hr 3 hr 1/2 hr 2-1/2 hr 6-1/2 hr 3 hr 3-1/2 hr Activity Move rig Rig moved 80.00 % L/D Derrick, RDMO to well location 3-34B. Laying herculite and spotting substructure @ report time. Move rig (cont...) Rig moved 90.00 % At well location - Cellar Lay Herculite. Spot substructure, camp, pits and workshop. Hook up service lines. Serviced Top drive Work completed, Top drive changed out Continue installation of service loop for top drive. Rigged up Drillfloor / Derrick Equipment work completed Raise and Pin Derrick. Raise chute. Lower Blocks and bridle down. PFU blocks to top drive. Serviced Draw works Replace Brake bands on Drawworks. Currently putting drwaworks back together. Anticipate rig ready for acceptance 1000-1100 hrs. Move rig (cont...) Serviced Draw works Complete changing out brake bands on drawworks. Rig Accepted @ 0830 hrs. Equipment work completed Wellhead work Removed Hanger plug Equipment work completed R/U lines to x-tree and install secondary annulus valve. R/U DSM- no pressure. Pull BPV. Circulated at 7733.5 ft String displaced with Seawater - 100.00 % displaced Circulate out Freeze Protect- 220 bbls of Diesel. Installed Hanger plug Equipment work completed Install TWC and test from below to 1000 psi. Wellhead work Held safety meeting Completed operations Hold Pre-spud Meeting and discuss environmental issues and H2S concerns for DS3. Removed Xmas tree Equipment work completed Remove x-tree and adaptor. BOP/riser operations - BOP stack Rigged up BOP stack Equipment work completed APR 20 2000 Oi~ & G~s Cons. Commis~ Tested BOP stack A~l~01'0~e Pressure test completed successfu'lly - 3500.000 psi Install Test joint. PUU and test BOPE to 3500 psi. J~ AOGC-C waivcd-witncss.~C-onduct-t94 i Facility PB DS 03 Date/Time 23:30-00:30 23:30-00:30 04 Mar 00 00:30 00:30-02:00 00:30-02:00 02:00 Duration 1 hr 1 hr 1-1/2 hr 1-1/2 hr 02:00-06:00 4 hr 02:00-04:00 2 hr 04:00 04:00-06:00 2 hr 06:00-00:00 18 hr 06:00-09:30 3-1/2 hr 09:30 09:30-10:00 1/2 hr 10:00 10:00-22:00 12 hr 22:00 22:00-00:00 2 hr 05 Mar O0 00:00 00:00-06:00 6 hr 00:00-03:30 3-1/2 hr 03:30 03:30-04:00 1/2 hr 04:00 04:00-06:00 2 hr 06:00-16:00 10 hr 06:00-10:00 4 hr 10:00 10:00-11:30 1-1/2 hr Progress Report Well 03-34B Page 2 Rig Nabors 9ES Date 27 March 00 Activity accumulator function test. Wellhead work Retrieved Hanger plug Equipment work completed BHA run no. 1 Made up BHA no. 1 BHA no. 1 made up Make up 4.1/2" double spear assembly on 3.1/2" HWDP. Pull Single completion, 4-l/2in O.D. Retrieved Casing hanger Completed operations BOLDS. Spear tubing- could only engage first pup joint below hanger with one grapple. Pulled tubing free w/25K o/pull. Up weight 130 Mbs. Release spear and L/D fishing equipment and hanger. Rigged up Tubing handling equipment R/U Chrome handling equipment. Preparing to pull tubing @ report time. Pull Single completion, 4-1/2in O.D. (cont...) Laid down 2300.0 ft of Tubing Stopped: At sub-assembly POOH laying down 50joints 4.1/2" Chrome tubulars using Chrome handling equipment and thread protectors. 56 SS bands recovered. Retrieved SCSSSV nipple assembly Completed operations L/O SSSV valve and clear rigfloor of control line spooling equipment. Laid down 5200.0 ft of Tubing Completed operations Continue to L/O 4.1/2" Chrome Tubing. 179 joints in total. L/O 23 joints 3.1/2" Chrome plus 2 GLM and cut off @ 15.17 ft. Rigged down Tubing handling equipment Equipment work completed Clear rig floor. Load Pipe shed with HWDP and clean rig up prior to next operation. BHA run no. 2 Made up BHA no. 2 BHA no. 2 made up Install wear ring. M/U Whiptsock mill assembly, 9 x 6.1/2" DC's and 18 x HWDP. Serviced Block line Line slipped Slip 40' drilline Singled in drill pipe to 1533.5 ft RIH picking up 4" driilpipe. BHA run no. 2 (cont...) Singled in drill pipe to 7733.5 ft Single in 4" drillpipe to 7700'. 220 joints picked up Circulated at 7773.5 ft Tag Top of 7" liner @ 7740'. Up/Down Wcight= 195/175 klbs, rotating 185 klbs. Torque 3,500 ftlbs. Sweep-holc clean-CUt/ 1250psi. APR 20 2000 Alaska Oii & Gas C',o~-~. Commis,, Ancho~'age 011 Facility · PB DS 03 Progress Report Well 03-34B Page 3 Rig Nabors 9ES Date 27 March 00 Date/Time 11:30 11:30-15:15 15:15 15:15-16:00 16:00 16:00-19:00 16:00-19:00 19:00 19:00-20:00 19:00-20:00 20:00 20:00-06:00 20:00-22:30 22:30 22:30-03:00 06 Mar O0 03:00 03:00~03:30 03:30 03:30-06:00 06:00-12:15 06:00-11:00 11:00 11:00-12:15 12:15 12:15-13:00 12:15-13:00 13:00 13:00-17:30 13:00-13:15 13:15 13:15-15:30 15:30 15:30-17:30 17:30 Duration 3-3/4 hr 3/4 hr 3 hr 3 hr 1 hr 1 hr lOhr 2-1/2 hr 4-1/2 hr 1/2 hr 2-1/2 hr 6-1/4 hr 5 hr 1-1/4 hr 3/4 hr 3/4 hr 4-1/2 hr 1/4 hr 2-1/4 hr 2 hr Activity Obtained bottoms up (100% annulus volume) Pulled out of hole to 133.5 ft At BHA Pulled BHA BHA Stood back Electric wireline work Installed Permanent packer Equipment work completed R/U Schlumberger and run 9.5/8" EZSV and correlate. Set Bridge plug at a siltstone interval @ 7,526 ft. Perform integrity test Tested Casing Pressure test completed successfully - 3000.000 psi R/U and test casing and bridge plug to 3000 psi/30 minutes pumping 7 bbls. BHA run no. 3 Made up BHA no. 3 BHA no. 3 made up M/U Whipstock BHA and surface test MWD. R.I.H. to 7564.5 ft At Top of packer: 7564.5 ft Functioned Tubing cutting tools Equipment work completed Orientate whipstock and set bottom anchor with 15 klbs shear, mills sheared @ 45 klbs. Whipstock set @ 85 degs R of highside. Circulated at 7534.5 ft Displace well to 10.2 ppg Milling Fluid. Preparing to mill window @ report time. BHA run no. 3 (cont...) Milled Casing at 7531.0 ft Completed operations Mill window f/7,501' to 7,517' and new hole to 7,531'. Circulated at 7531.0 ft Hole swept with slug - 100.00 % hole volume Sweep hole clean. Window clean but open hole taking some weight. Cleaned up with circulating. Perform integrity test Performed formation integrity test Obtained leak off 12.5 ppg EMW Conduct FIT with 10.1 ppg mudweight. Injection noted @ 880 psi. Shut down pump and monitor welibore pressures. 2.6 bbls pumped, 2 bbls returned. BHA run no. 3 Circulated at 7531.0 ft Check window- good, Pump dry job. Heavy slug spotted downhole Pulled out of hole to 1000.0 ft ~'PR ~ 0 2000 At BHA Pulled BHA BHA Laid out Alaska 0ii & Gas Cuds. Cmm~s: T_: ..... hipsmck ~,, ~-~ anchOr@neqrn~n,-'-" , ~.,~,~ ~,~, w ~,, IA. Milts-in~ood-~h ..... Facility PB DS 03 Date/Time 07 Mar 00 17:30-18:30 17:30-18:30 18:30 18:30-06:00 18:30-21:30 21:30 21:30-22:30 22:30 22:30-01:00 01:00 01:00-03:30 03:30 03:30-04:00 04:00 04:00-04:30 04:30 04:30-06:00 04:30-06:00 06:00-06:00 06:00-06:00 08 Mar 00 06:00-19:30 06:00-13:30 13:30 13:30-14:30 14:30 14:30-18:00 18:00 18:00-19:30 19:30 Progress Report Well 03-34B Page 4 Rig Nabors 9ES Date 27 March 00 Duration 1 hr 1 hr 11-1/2 hr 3 hr 1 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 24 hr 24 hr 13-1/2 hr 7-1/2 hr 1 hr 3-1/2 hr 1-1/2 hr Activity gauge. 4in. Drillpipe workstring run Circulated at 30.0 fi Began precautionary measures Flush BOP stack of any residual metal. BHA run no. 4 Made up BHA no. 3 BHA no. 3 made up P/U Drilling assembly and orientate same. Serviced Lines / Cables Line slipped and cut And service Top Drive Singled in drill pipe to 2590.0 ft 81 joints picked up R.I.H. to 7500.0 ft At Window: 7500.0 ft Circulated at 7500.0 ft Began precautionary measures APR 20 2000 0il & Gas Cons. C0mmis~ios An~0ra~e Attempt to obtain communication to Sperry Sun Rig Floor displays. Troubleshoot same. Reamed to 7531.0 ft On bottom Ream/wash to bottom. Drilled to 7540.0 ft Initiate kick off in 8.1/2" Hole. Drilled to 7540.0 ft Drill and survey from 7,540' to 8,130'. ART - 15-1/4; AST = 6-1/4; Pumped hi-vis sweep at 8,040' - no visible increase in cuttings; good hole conditions; BHA run no. 4 (cont...) Drilled to 8130.0 ft (cont...) Drill and survey from 7,540' to 8,130'. ART = 15-1/4; AST = 6-1/4; Pumped hi-vis sweep at 8,040' - no visible increase in cuttings; good hole conditions; BHA run no. 4 (cont...) Drilled to 8314.0 ft Reached planned end of run - Maximum hours on bit Directionally drill 8.1/2" Hole f/8,130' to 8,314'. Penetration performance averaging 20-25 fi/hr. Approaching high K-revs for bit, decision made to pull for PDC. Circulated at 8314.0 ft Obtained bottoms up (100% annulus volume) Sweep hole clean. Flowcheck. Pulled out of hole to 300.0 ft At BHA POOH- hole in good shape. Downloaded MWD tool Completed operations Download MWD and break out Motor and bit. Bearings still effective, one cone easy to move. Even wear. On Bottom Krevs @ 325,000, On/Off Bottom @ 350,000 ~..,, STATE OF ALASKA ALASKA .LAND GAS CONSERVATION CC_ ?IISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic F-lService 4. Location of well at surface ,{' ¢' ¢/' 97' NSL, 846' EWL, SEC. 11, T10N, R15E, UM At top of productive interval 2724' SNL, 503' EWL, SEC. 14, T10N, R15E, UM At effective depth 2812' SNL, 559' EWL, SEC. 14, T10N, R15E, UM At total depth 2858' SNL, 588' EWL, SEC. 14, T10N, R15E, UM 6. Datum Elevation (DF or KB) RKB = 62' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 03-34A 9. Permit Nu,~ber 192-018 10. APl Number ~ 50- 029-21132-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary ,,/ Total depth: measured 9978 feet true vertical 9213``/feet Effective depth: measured 9848 feet true vertical 9095 feet Casing Length Size Structural Conductor 110' Surface 2439' Intermediate Production 7948' Liner 2236' Perforation depth: measured true vertical Plugs (measured) junk (measured) Tagged PBTD at 9848' MD (04/21/99) Cemented MD TVD 20" 1865 # Poleset 110' 110' 13-3/8" 2300 sx Coldset II 2501' 2501' 9-5/8" 500 sx Class 'G', 300 sx Coldset I 8010' 7498' 7" 426 sx Class '(3' 7742' - 9978' 7257' - 9213' 9482'- 9806' (five intervals) 8762'- 9057' (five intervals) Tubing (size, grade, and measured depth) RECEIVED FEB 01 2.000 Alaska 0il & 6as Cons. Commission 4-1/2", 12.6#, 13Crto 7729'; 3-1/2", 9.2#, 13Crto 9255' Anchorage Packers and SSSV (type and measured depth) 7" TIW 'HBBP' permanent packer at 9187'; 4-1/2" AVA TRSV SSSV Nipple at 2208' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation February 8, 2000 16. If, proposal was verbally approved Name r Date approv.e .d.. Contact Engineer Name/Number: Lowell Crane, 564-4089 17. I hereby certify that,.the f.f.f~egoing is tru_.,e and correct to the best of my knowledge Signed Dan Stone,,/ ~.._~~ ..... ~' .~ Title Senior Drilling Engineer L'"'/ ~ ~- ~mmission Use Only 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of Approval: Notify Commission so representative may witness Plug integrity '~ BOP Test "~ Location clearance Mechanical Integrity Test__ Subsequent form re(~u~l 10- Approved by order of the Commission ORIGINAL SIGNED BY ..,,~.-~.~,~)(~~Commissioner Form 10-403 Rev. 06/15/88 RobertN. IApprova' No. Og2" Submit In Triplicate ,, _ hared ervices · rilling Alaska ~ BP Exploration / ARCO Alaska Inc. To: AOGCC Date: January 12, 2000 From: Jim Smith Subject: Reference: Prepare Well DS 3-34A for Sidetrack Operations Form 10-403 Attachment APl #50-029-211-320-1 RECEIVED FEB 0 1 2000 Alaska 0it & Gas Cons. Commission This memo is written as an attachment to form 10-403 to provide description of activit(~l~r~l~rra6~are well 3-34A for the sidetracking operations to follow, Nabors 9ES is expected to move on DS 3-34A in very early March, 2000 to sidetrack to a different bottom hole location, Planned Pre-Rio Operations No P&A operations may be conducted until an approved Sundry Permit is received from the AOGCC. 1. Drift existing 4-1/2" and 3-1/2" tubing through the tubing tail at 9255'. 2. RU coil and P&A existing perforations (9482'-9788') with Class G cement at 15.8 ppg. Planned cement coverage is from 9,935' (PBTD) to TOC at 9,350'MD. (Note: top perf at 9,482'). Calculated cement volume is 22.3 bbl to fill this amount of 7" 26# production liner. Pump 25 bbl (140 ft3) of 15.8 ppg Class G at 1.17 ft3/sx. Total sacks of cement is 120. Tag and test cement to meet AOGCC requirements. 3. Cut the 3-1/2" 9.3# 13CR tubing at 8,500'MD in the middle of a joint. Cut method to be either a jet cut or a chemical cut at field discretion. 4. Test the 9 5/8" mandrel packoff and tubing hanger (through test port) to 5000 psi. Completely back out and check each Lock Down Screw (LDS) for breakage or over-tightness (check one at a time). If overtight LDS are identified, bring additional crewmen and tools to function the LDS prior to rig arrival. 5. Test the 9-5/8" casing and 7" production liner (down to the P&A cement) to 3000 psi. Ensure pressure is equal on both the annulus and tubing to prevent tubing collapse. 6. Set a BPV in preparation of the rig move. Assure annuli are freeze protected to near 2000'. 7. Clear and level pad in the area of rig placement. Planned Drilling Rig Operations 1. MIRU. ND tree, NU and test BOPE. Circulate out freeze protect fluid and circulate well to clean seawater. 2. Pull 4 Y2" and 3 ~" 13CR tubing down to the pre-rig tubing cut at 8,500'. Use care and thread protectors with all tubing since it is expected that there will be a high recovery rate with this pipe. Replace 9-5/8" packoff if necessary. Make GR/JB run to 8,000'MD. Set BP at 7,950'MD. Test 9-5/8" casing to 3000 psi for 30 minutes against the BP. PU BHA and RIH. Displace hole to milling fluid and cut a 45' section from 7700' to 7745' approx, in the 9- 5/8" casing. Spot a balanced plug of 17.0 ppg cement across the section and perform a light cement squeeze on it. Sidetrack at +/-7700'from the existing wellbore in 8-1/2" hole size in the Colville shales. Displace to LSND mud system. Drill 8-1/2" hole along the directional plan to land at high hole angle in the Sag River formation (approx. 9464'MD/8703'TVD). . 4. 5. 6. . . 9. Run and cement a 7" drilli ,iner at 9464'MD providing 150' of lap abc ihe KOP at 7700'. 10. Pressure test 9-5/8" and 7" casings to 3000 psi for 30 minutes prior to drilling 7" float equipment. Drill out 20', perform FIT to 9.2 ppg EMW, displace the hole to QuickdrilN and drill 6-1/8" horizontal hole from 9464' to 11,617'MD' in the Sag River formation. Run MWD/GR/Res+PWD and follow directional plan in the Sag River. No other logs are planned. 11. Run 4-1/2" 12.6# L80 IBT-Mod slotted Bonzai production liner and cement with 15.8 ppg cement above the ECP. (Note: If entire wellbore below the 7" drilling liner remains in the Sag River the well will be completed with slotted liner only---no Bonzai). 12. Pressure test casing strings to 3000 psi 13. Run 4-1/2" 12.6#, L80, IBT-Mod production tubing. Set packer near 9300' in the 7" drilling liner. Present plan calls for 6 GLMs. 14. Freeze protect permafrost zone through top GLM. 15. Set BPV, ND BOPE, NU and test tree. RDMO. Well Control Considerations Pore pressure is estimated at 3,100 psi (6.8 ppg EMW) in the Sag River. MW used for drilling this interval will be 8.3 ppg or slightly higher. Although not expected, lost circulation may be a problem due to a fault crossing in the 8-1/2" interval. Standard LCM pill formulation will be employed to combat any losses. H2S DS 3 is an H2S pad. The highest readings on the pad were 688 ppm in August, 1999. H2S contingency programs will be in effect. Mechanical Information No identified problems at this time RECEIVED :EB 0 l rO00 A~aska Oil & Gas Ct}ns. Commission Anchorage 03-34A Proposed P&A OrigRKB=62' 13-3/8", 72 #/ft, L80, BTC 4-1/2" TRSV SSSV Nipple I 2208' I 3 each 4-1/2"x1-1/2 GLMs 6 each 3-1/2 x 1-1/2 GLMs 4-1/2" 12.6# 13CR Tubing 3-1/2" 9.2# 13CR Tubing (XO at 7729) RECEIVED 0ii & 6as Cons. Commission ~chorags Top of 7" Liner at 9-5/8", 47 #/ft, L80, BTC 7742'1 o o'1 Cut 3-1/2" Tubing at 8500' approx. (above PKR) 3-1/2" 'X' Landing Nipple@ 9119 x 3-1/2" TIW HBBP Production Packer @9187MD 3-1/2" 'X' Landing Nipple@ 9224 3-1/2" 'XN' Landing Nipple@ 9242 3-1/2" tubing tail @ 9255 Coil to spot/squeeze 15.8 ppg cmt across perfs to place TOC at 9350' approx. 132' above top perf Peds 9482-9806 7", 26#/ft, L80 ~ 9978' ~ & 26#/ft 13CR n~t~, ~,. i~,~ P_nmm~nf~ - PRUDHOE BAY UNIT JES Proposed P&A of Oria. Well WELL: 03-34 2-1-00 LRC Corrected Perf Depths APl NO:50-029-211-320-01 Shared Services Drilling 03-34B Proposed Orig RKB = 62' WELLHEAD: 13-3/8", 72 #/ft, L80, BTC 4-1/2" X Nipple I 2200' 6-GLMs, 1-1/2 to top 7 inch, 1 inch below the liner top 4-1/2" 12.6# L-80, IBT--Mod Tubing surface to 9550 approx. 7 in., 26#, L-80 drilling liner from 7550 ft 9464 ft in the Sag river formation RECEIVED 0il & Gas Cons. Commission Anchorage Top of 7" Liner at I 7742' 9-5/8", 47 #/ft, L80, I 8010'1 BTC Coil to spot/squeeze 15.8 ppg cmt across perfs to place TOC at 9350' approx. TNT 7" x 4-1/2" production packer at 9300' single "XN" in the tailpipe. Stab WLEG into 4-1/2" liner top Either slotted liner or 4-1/2" Bonzai completion below 7 inch liner shoe, TeL has 100' of lap into the 7 inch liner. TD at 11617'MD/8743'TVD Peds 9482-9806 7", 26 #/ft, L80 & 26#/ft 13CR 9978'I - PRUDHOE BAY UNIT 1/12/2000 JES Proposed 3-34B Well WELL: 03-34B 2/1/2000 LRC Corrected Perf depths APl NO:50-029-211-320-xx Shared Services Drilling STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate _ Plugging _ Per/orate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 62 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 5179' FNL, 4434' FEL, Sec. 11, T10N, R15E, UM 03-34A At top of productive interval 9. Permit number / approval number 2516' FSL, 564' FWL, Sec. 14, T10N, R15E, UM 92-18 At effective depth 10. APl number 50-029-21132-01 At total depth 11. Field / Pool 2857' FNL, 4690' FEL, Sec. 14, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 9978 feet Plugs (measured) Tagged PBTD @ 9848' MD (4/21/1999) true vertical 9213 feet Effective depth: measured 9848 feet Junk (measured) true vertical 9095 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 1865# Poleset 11 0' 11 0' Surface 2439' 13-3/8" 2300 Sx CS m 2501' 2501' Production 7948' 9-5/8" 500 Sx Class G & 300 Sx CS I 8010' 7498' Liner 1410' 7" 426 sx C~ass G 9978' 9213' RECEIVED Perforation depth: measured 9482" - 9500'; 9611' - 9640'; 9753' - 9763'; 9777' - 9788'; 9796' - 9806'. C,£ 1999 true vertical 8761' - 8778'; 8879' - 8905'; 9008' - 9017'; 9030' - 9040'; 9048' - 9057'. Alaaka 0ii & (las Cons. C0mmissior Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR Tbg @ 7729' MD; 3-1/2", 9.2#, 13CR Tbg @ 9255' MD. Anch0ra§~ Packers & SSSV (type & measured depth) 7" TIW HBBP PERMANENT PACKER @ 9187'. 4-1/2" AVA TRSV SSSV @ 2209' MD. ~ j j~ J ~, J 13. Stimulation or cement squeeze summary ~,J ~ i b J J'~J ~% J~ Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (shut in) Subsequent to operation 234 875 7366 337 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICAT '~E~ 03-34A DESCRIPTION OF WORK COMPLETED PACKER LEAK SQUEEZE Date Event Summary 3/08/99: 3/13/99: 3/15/99: 3/17/99: 3/19~99: 4/18/99: 4/21/99: RIH & tagged PBTD @ 9286' MD. Performed a CT Packer Leak Squeeze with the purpose of regaining IA integrity as follows: MIRU CTU. PT'd equip to 4000 psi. Killed well w/Crude. RIH w/CT & tagged PBTD @ 9286' MD. The following perforation intervals are isolated by a sand plug: 9482' - 9500' MD (Sag Zone) Reference Log: BHCS 4/11/1992. 9611' - 9640' MD (Zone 4) 9753' - 9763' MD (Zone 4) 9777' - 9788' MD (Zone 4) 9796' - 9806' MD (Zone 4) Pumped 6 bbls of Neat Latex Acid Resistive Cement to repair the Packer leak. Placed 4 bbls of Cement into the IA through the Packer & 2 bbls of Cement into tubing. Left Cement / water interface @ 9145' MD. POOH w/CT. Left 250 psi on wellhead. RD. RIH & tagged TOC @ 8805' MD. Milled / FCO Cement to 9312' MD. PT'd IA. Found IA by tbg communication present (leaking gas lift valve). RIH & tagged TOC @ 9314' MD. RIH & UR'd sand to 9860' MD. RIH & tagged TOC @ 9848' MD. Returned well to production & obtained a valid well test. ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 May 25, 1999 ... - .... .;,~!7,.'~'' - . Mr. Blair Wondzell Alaska Oil & Gas Conse~ation Commission 3001 Porcupine Dhve ~chorage, Alaska 99501-3192 Re: Flow testing of xvells capable of unassisted flow to the surface. Dear Mr. Wondzell: This letter is in response to your emails on May 25 regarding justification for flow testing of ~vells capable of unassisted flow to the surface. The folloxving text provides a brief reason for the flow test, as well as arguments why casing damage should be minimal. In all cases, the wells will be tested for a limited duration and then shut-in and secured until approved by your office for some action (via 10-403) or the well is repaired. Tracking of the flow testing duration will be done from the Problem Wells Specialist office. DS 3-~:~Had a failed packer, which has recently been cement squeezed to regain pressure integrity to the tubing string. It has subsequently been tested to not be capable of unassisted flow to the surface, so an exemption for flowing is not requested. DS 11-25: Has a documented hole below the 5 1/2" x 3 1/2" crossover as per LDL 5/4/98. This single hole needs patching, since the well is capable of unassisted flow to the surface. Casing damage is not expected to be a concern, since the well will require gaslift and the annulus will be gas filled. Flow testing is requested prior to patching since perforations were added and need to be evaluated before a patch is set. Additional perforations or a squeeze may result post flow-test. A patch in the 3 1/2" tubing will not allow further downhole work without the patch being pulled, and subsequently reset before sustained production. The flow period request is for 2-4 weeks. DS 13-33: Has a documented hole in the tubing at a failed non-retrievable patch set over GLM #10 in 1990. The well has been shut-in since 1995, and does not have the reserves to justify a RWO to replace the tubing. The xvell passed a CMIT T x IA to 3000 psi in 1995. This is a candidate well for a Sundry 10-403 application to continue to flow with a known T x IA communication problem. The request is to flow test for 2-3 weeks to determine if production rates are sufficient to apply for Sundry Notice and/or determine if the well is capable of unassisted flow. The well will require gaslift from a deep valve, so the casing will be protected from production flow by the gas-filled annulus. DS 16-31' SI since 1994 with leaking patch over GLM #10. This is a candidate well for a Sundry 10-403 application to continue to flow with a known T x IA communication problem. The request is to flow test for 2-3 weeks to determine if production rates are sufficient to apply for a Sundry Notice and/or determine if the well is capable of unassisted flow. The well will require gaslift from a deep valve, so the casing will be protected from production flow by the gas-filled annulus. A CMIT T x IA passed to 3000 psi in 1994. DS 18-17: Has documented T x IA communication through a corrosion hole at 4546'. The request is to flow the well after a corrosion probe installation for 4-6 weeks to determine the corrosion rate for an engineenng study of the corrosion mechanism in the gravity drainage portion of the field. This well is capable of unassisted flow to thc surface. Due to the GOR of the ~vell and the single leak point, the annulus is expected to be gas-filled dunng the study period, which should minimize casing exposure to production fluids. The well will be SI and secured after the study is completed. DS ~-'2~.' Has documented T x IA communication through a corrosion hole at 7244'. The request is to flow the well after a corrosion probe installation for 4-6 weeks for the corrosion mechanism study in the gravity drainage portion of the field. This well is capable of unassisted flow to the surface. Due to the GOR of the well and the single leak point, the annulus is expected to be gas-filled during the study period, which should minimize casing exposure to production fluids. The well will be SI and secured after the study is completed. I hope this letter provides enough explanation for approving a flow-test of these wells for a limited period of time. Please call or email if you need additional information. ethlefs ' Problem Well Specialist Re: Wells capable of unassisted flow. Subject: Re: Wells capable of unassisted flow. Date: Fri, 04 Jun 1999 11:19:12 -0800 From: Blair Wondzell <Blair_Wondzell~admin.state.ak.us> Organization: SOA-AOGCC To: PRB Problem Wells <P 1041 ~mail.aai.arco.¢om> Jerry, I just finished reading your comments on these wells. Your proposal sounds fine to me. I agree you should proceed as you've proposed. Blair 6/4/99 PRB Problem Wells wrote: Blair: This is a summary of the requests I have from Engineering to temporarily flow wells that are capable of unassisted flow: DS 3-34: Post packer cement squeeze; determine if capable of unassisted flow to surface. Has broken gaslift valve in station 4. Flow period approximately 1 - week. DS 11-25: Documented hole below 5 1/2" x 3 1/2" crossover, needs patching. Needs flow testing after add perforations to determine if additional wellwork is needed prior to patching. Wireline tools will not be able to get below patch once installed. Flow period request for 2-4 weeks. DS 13-33: Documented hole in tubing, not economic to repair. Passed CMIT T x IA. Need flow test to determine if worthy to apply for Sundry Notice to continue flowing with known communication (capable of unassited flow). Flow period for 2-3 weeks. DS 16-31: SI since 1994 with leaking patch over GLM #10. Need flow test to determine if worthy to apply for Sundry Notice to continue flowing with known communication (capable of unassited flow). Flow period for 2-3 weeks. DS 18-17: Documented T x IA communication through corrosion holes. Request to flow well with corrosion probe installation for 4-6 weeks to determine corrosion. rate for engineering study. This well is capable of unassisted flow. DS 18-25: Documented T x IA communication through corrosion holes. Request to flow well with corrosion probe installation for 4-6 weeks to determine corrosion rate for engineering study. This well is capable of unassisted flow. I can provide more detail, but the main concern is that these wells are, or may be, capable of unassisted flow and have known communication. At the termination of these flow tests the wells will be SI and secured. Let me know if you need additional information, and whether these short-term flow tests are worth bothering you with. Thanks ! Jerry De thl els Blair Wondzell <Blair Wondzell@admin.state.ak.us> on 05/24/99 10:34:46 AM -- To: PRB Problem Wells/AAI/ARCO CC: Subject: Re: Wells capable of unassisted flow. Jerry, These types of problems are in a poorly defined area of our regulation, therefore my practice has been to check on the regulation goals of protection of casing. If the casing appears to be protected, then agree that the request is appropriate. For example if you have a "minor" tubing leak in a gas lift well, this is not much different than having a choke in a gas lift mandrel - so no problem. My suggestion is that by E-mail you provide data on the the specific wells such as depth of leak, severity, type of lift, why annulus will not be subjected to well bore fluids and similar thoughts that come to mind. We can evaluate and advise (on most I'm sure) that there is no problem with continued production. Lets give this a try. Thanks. Blair. PRB Problem Wells wrote: Re: Wells capable of unassisted flow. > > Blair: As a production well develops T x IA communication it has always been our > practice to SI the well except for very short periods of time we may need to do > diagnostics. The wells have been repaired and tested prior to resuming routine > production. As you have noticed, recently we have been evaluating several wells > with iow future potential, especially due to the cost of RWO's. It has been > great to get approval for some of these wells (14-40, 14-06) to continue to flow > with known communication problems. I expect more of these requests to come your > way. > As part of the process to develop a Sundry we have found it necessary to flow > these wells for a limited period of time prior to submission of the 10-403 to > figure out if they are even worth producing on a routine basis. In addition, I > receive requests periodically from the Engineering staff to flow other wells > capable of unassisted flow that have not yet been repaired, or have some other > diagnostic or evaluation requirement needed. Since the frequency of these > requests have increased, I feel some guidance from you is in order so we don' t > risk operating wells out of compliance. > I currently maintain a list with my alternate of wells that have been reques ged > for flow by Engineering. This list now has 7 wells capable of unassisted flow, > of which 2 wells are currently on line. The list includes the well name, purpose > of flowing the well, approximate duration (1-6 weeks), the date brought on line, > and the mechanical condition or problem with the well. Our criteria is based on > flowing the well no longer than is needed to obtain the requested data; in other > words, flowing for production of oil is not a legitimate request. At the > germination of the flow period the well is SI, secured, and removed from the > list. > Do you want to be informed of the wells on this list, given the short duration > of these tests? This is a fairly new procedure for us to use, but has be very > useful for tracking' these situations. Should you want to be kept informed at > this level of detail, I could periodically forward the list to you. Let me know > what you prefer. Thanks! > Jerry De thl els > ARCO Problem Wells Specialist STATE OF ALASKA ALASKA (?%AND GAS CONSERVATION CO, ISSION REPORT-( SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown --.- Stimulate X~ Plugging ~-. Perforate Pull tubing Alter casing Repair well 2. Name of Operator ~ 5. Type of Well Development X ARCO Alaska, Inc. ExCora~ory '~ 3. Address Stratigraphic . P.O. Box 100360, Anchorage, AK 99510-0360 service .. 4. Location of well at surface 97' NSL, 846' EWL, Sec. 11, T10N, R15E, UM. At top of productive interval At effective depth At total depth 2424' NSL, 592' EWL, Sec. 14, T10N, R15E, UM. 12. Present well condition summary Total depth: O~her 6. Datum of elevation(DF or KB) 62' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-34A 9. Permit number/approval number 92-18 10. APl number 50 - 029-21132-01 11. Field/Pool Prudhoe Bay Oil Pool measured 9978 feet true vertical 9213 feet Plugs(measured) Sand Plug top @ 9339' MD (9/19/95) feet Effective depth: measured 9339 feet true vertical 8634 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 1865# Poleset 110' 110' Sudace 2439' 13-3/8" 2300 Sx CS III 2501' 2501' Production 7948' 9-5/8" 500 Sx G & 300 Sx CS I 8010' 7498' Liner 2236' 7" 426 Sx G 9978' 9213' Perforation depth: measured [Isolated by Sand Plug: 9482 - 9500'; 9611 - 9640'; 9753 - 9763'; 9777 - 9788'; 9796 - 9806'] true vertical [Isolated by Sand Plug: 8761 - 8778'; 8879 - 8905'; 9008 - 9017'; 9030 - 9040'; 9048 - 9057'J Tubing (size, grade, and measured depth) 4-1/2", 12.6~, 13 Cr, 4-1/2 x 3-1/2" x-over @ 7729' MD;'3-1/2", 9.2#, 13 Cr @ 9255' MD. Packers and SSSV (type and measured depth) 4-1/2" AVA SSSV @ 2208' MD; 7" TIW HBBP Packer @ 9187' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached 14, Treatment description including volumes used and final pressure Representative Daily Averaee Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 387 451 1630 -- 252 Subsequent to operation Shu In 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ...X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404 Rev 06/15/88 Title Engineering Supervisor , Date SUBMIT IN DUPLICATE__ !.,"7 RAID 3-34A DESCRIPTION OF WORK COMPLETED HYDRAULIC REFRACTURE TREATMENT OF ZONE 4 & SAG RIVER 7/1/95: RIH & tagged PBTD at 9868' MD. 7/4/95: MIRU CTU & PT equipment to 4000 psi. RIH w/CT & loaded wellbore w/Seawater, then pumped gelled sand slurry containing 8500 lbs of 20/40 mesh sand, to place a pre-frac sand plug across the perforations at: 9753 - 9763' MD (Z4) 9777 - 9788' MD (Z4) 9796 - 9806' MD (Z4) Ref. Log: BHCS 4/11/92. Made final tag on top of sand plug at 9683' MD. POOH w/CT. Rigged down. 8/26/95: RIH & tagged bottom fill at 9645' MD. 8/27/95: MIRU & PT equipment to 8400 psi. Pumped a Hydraulic Fracture Treatment using 16/20 mesh proppant, through the open perforation intervals located above the sand plug at: 9482 - 9500' MD (Sag) 9611 - 9640' MD (Z4) Ref. Log: BHCS 4/11/92. Pumped: a) 650 bbls Pre Pad @ 35 bpm, followed by b) Shutdown. Resumed pumping: c) 840 bbls 40# Crosslinked Pad @ 36 bpm, followed by d) 717 bbls Cross Linked Slurry in 1 - 10 ppg proppant stages, followed by e) 134 bbls Flush, followed by f) Shutdown. Placed a total of 138,731 lbs of proppant into the formation. Rigged down. 8128195: RIH w/CT & jetted a proppant/sand plug fill cleanout w/biozan to 9810' MD. 915195: RIH w/CT & jetted a proppant/sand plug fill cleanout w/biozan to 9928' MD. Placed the well on production and obtained a valid welltest. 9/1 9/95: MIRU CTU & PT equipment. RIH w/CT & loaded the wellbore w/Seawater, then pumped gelled sand slurry w/5000 lbs of 20/40 mesh sand, to place an isolation sand plug over the perforation intervals (listed above). Made final top of sand plug tag at 9350' MD. POOH w/CT. Rigged down. 9/23/95: RIH & tagged sand plug top at 9339' MD. The well is currently shut-in due to annular communication. Future wellwork options to repair the leaky packer are being evaluated. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9602 CompanY: 7/31/95 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. 1-3 "~/~) t~ ~ LEAK DETECTION 9 5 0 71 2 I 1 D.S. 1-33,~_.~..~(~ ! ~-~Z~- PROD LOG 95071 0 I ' 1 D.S. 3-34A~/'~__. (~ ! ~/~ INJECPROFILE 950711 I 1 D.S. 4-01 '~ ~ h~_~ PRODLOG 950710 1' . 1 D.S. 16-21 ~' ~'- ~1 'Z_._ BAKER INFLATABLE 950712 I ' 1 D.S. 16-29A ~.~ t~)~/o (~ PERFRECORD 950712 I 1 D.S. 18-3A ~'/~/ / t, DUAL BURST TDT-P 950710 1 1 D.S. 18-3A / -/ / U ~ PROD PROFILE 950708 1 1 D,S. 18-18A ~;-' O ! ~-/ DUAL BURST TDT-P 950707 I 1 / ~ SIGNED: ~ ........ Pleas gn and return one copy of this transmittal to Sherrie at the above address. Thank you. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: David Johnsto~p< DATE: Chair~~:;~ ~ Blair Wondzell,~ ~, .J,¥ FILE NO: P. I. Supervisor .t~/(ole~ ~, Bobby Foster,~-~,-~ SUBJECT: Petroleum Inspector' July 18, 1995 1F91GQCD:doc No Flow Test ARCO - PBU - DS3-34 Prudhoe Bay Field Tuesday, July 18, 1995: I traveled this 'date'to ARCO's PBU DS 3-34 well and witnessed a No Flow test after being contacted by Rowland Burno, ARCO PE. The test began at 12:15 PM and was concluded at 3:15 PM. The casing had been bled down to 0 PSlG before I arrived on the location. The tubing had been bled down the flowline to Iow pressue seperator pressure - approximately 150+- PSlG - and then flowed to a 300 bbl. inclosed tank until I reached the location. The tubing was then switched from the 300 bbl. tank to a small open top tank. After 3 hours the well had produced no fluid. The results of the gas production test are as follows: Test # 1 30 Minute Test 450 Cu/Ft/Hr. Test # 2 30 Minute Test 330 Cu/Ft/Hr. Test # 3 30 Minute Test 255 Cu/Ft/Hr. Test # 4 30 Minute Test 195 Cu/Ft/Hr. Test # 5 30 Minute Test 157 Cu/Ft/Hr. Test # 6 30 Minute Test 15 Cu/Ft/Hr. The tubing pressure at the start of the test was 6 PSIG and gradually fell to 1 PSIG at the end of the test. I recommend to the Commission that this well be accepted as No Flow status. Summary: I witnessed the satisfactory "No Flow" test on ARCO's PBU DS 3-34. Attachment:: NONE.XLS cc. Dave Smith/Richard Ortiz - ARCO North Slope - PE Office PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS 92-018 92-018 92-018 92-018 92-018 92-018 92-018 92-018 92-018 92-018 B2-018 BHCA/GR CNL/GR DIFL/GR GR PERF PERF PFC/GR (PERF) PROD PROD/PRES/TEMP SSTVD L 9250-9964 L 9250-9943 L 9250-9990 L 8000-9250 L 9600-9880 L 9600-9888 L 9050-9929 L 9350-9775 L 50-9858 L 9250-9990 STAT (BLUELINE) L 9100-9877 92-018 TEMP 92-018 407 92-018 B2-018 DAILY WELL OP SURVEY 92-018 SURVEY B2-018 SURVEY 92-018 5247 L 2134-9793 R COMP DATE: 04/23/92 R 04/02/92-04/15/92 R 0-10017, MWD R 8010-8781, MWD R 8010-9926, ESS CORE T 8000-9990, O~F~ ~re dry ditch samples required? yes__And received? Page: 1 Date: 03/31/94 RUN DATE_RECVD 1 04/30/92 1 04/30/92 1 04/30/92 1 04/30/92 1 02/01/93 1 04/19/93 1 04/30/92 1 04/27/93 1 03/18/94 1 04/30/92 1 03/18/94 1 04/19/93 07/09/92 07/09/92 07/09/92 06/23/92 06/23/92 05/11/92 Was the well cored? ye~Analysis. & description received? ~re well tests required?~. Received? ¥~ ~ell is in compliance i~i~.a1 3omments ARCO Alaska, Inc. Date: Subject- From/Location: Telephone: To/Location: P.O. Box 100360, A' 0rage, AK Mar 15, 1994 Transmittal #: 94029 John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 99510~ ~, INumberWell I LOg(M.D.y)Datei Tool Type RUn,scale Cone'actor 101-02 ! 2-26-94 I Prod/Spin/Tempt~.,, 1,5" Schlumber l 01-03 2-19-94I ~'~Prod~BS/Temp ~( 1, 5" Schlumber I 01-09 3-01-94 Tubing Cutter ~ 1, 5" Schlumber 01-11 2-27-94 Prod Prof/Spin~ 1, 5" Schlumber 01-18 2-23-94 Leak Detection I 1, l"& 5" Schlumber 01-25 I 3-06-94 CNL i 1, 5" Schlumber .~3-20A i 2-17-94 Perf I 1, 5" Schlumber ~03-20A I 3-03-94 Dual Burst '~'-~' .1, 5" Schlumber 03-32 ! 2-26-94 Leak/Press/Temp 1, 2" Schlumber 03-34A i 2-24-94 Prod/Press/Temp 1, 2"&5" Schlumber 04-01 I 2-19-94 Prod 1, 5" Schlumber 04-24 2-22-94 Prod ! 1, 5" Schlumber 04-40 ! 2-22-94 Perf i 1, 5" Schlumber 04-46 . 2-16-94 Rope Perf 1, 5" Schlumber /04-47 2-18-94 v Perf 1, 5" Schlumber ~, 04-47 '2-15-94 ,," CBT-GR 1, 5" Schlumber ~04-47 2-15-94 v CET-GR 1, 5" Schlumber 05-06 2-11-94 Perf 1, 5" Schlumber 05-14A 7-11-93 USIT/Cem&Corr (.~%1, 5" Schlumber 05-15A 05-15A cC~ GND/GR-t.v,~ ~ 1, 5" Schlumber 05-26 3-02-94 Dual Burst '['c~ (~ 1, 5" Schlumber /'06-15 2-21-94 Prod 1, 5" Schlumber \ 06-!5 2-22-94 Comp Neutron 1, 5" Schlumber 06-22A 3-01-94 Perf 1, 5" Schlumber 07-08 3-02-94 Prod~,~ 1, 5" Schlumber 07-23 3-07-94 Leak/Spin/Tem~,~ 1, 5" Schlumber 09-34 2-21-94 Tubing Cutter i~c,, 1, 5" Schlumber ,11-02 2-10-94 Inj Pmf/SI~,~~, 5" Schlumber / 11-04 2-20-94 Tubing Cutter ~' 1, 5" Schlumber r,~l 1-04 2-17-94 Tubing ~,~ ~ ~1, 5" Schlumber 11-7ST 3-06-94 Inj Prof/Spin II~__~/'~._ 1, 5" Schlumber 11- 2-25-94 Leak/Press/Temp 1, 1"&5" Schlumber 16ST /Spin/~,~-b ~--l~ lot4 X~111- 3-08-94 Comp/l~l~table 1,5" Schlumber 6ST I Z~Co-- K~.~.(~ 0 ..~11-17 .2-20-94 Leak 1, 5" Schlumber ..~',,,11-17 3-08-94 Prod 1, 5" Schlumber 11-23 8-09-91 TMD 1, 5" Halliburton /11-24A 3-05-94 Perf/GR/CCL 1, 5" Schlumber \! 1-24A 2-22-94 Comp/Perf j 1, 5" Schlumber ARCO Alaska, Inc. I~a SubMJ~ry of AllanllgRlchllMdComl~/ [ 12-01 i 13-10 14-2B 14-2B 14-2B 14-2B 14-2B 14-2B .14-2B 14-24 14-28 14-34 16-08 17-21 i PWDW 02-01 3-06-94 2-24-94 1-16-94 Prod Perf CNL/GR 1-16-94 Sub-Sea 1 - 16-94 1-16-94 1-19-94 1-23-94 1-23-94 2-19-94 Acoustilo( Dual ! Se9 Bond/GR(cC{L,, PFC/GR/CCL PFC/Collar Lea~ 3-05-94 Leak 2-15-94 Prod/Press/Tom 3-07-94 2-24-94 2-09 -94 1, 2"&5" Prod Prof/Spin l 1, 2"&5" Perf Water Inj/FBS/Temple¢{ Schlumber Schlumber 1, 2"&5" I Schlumber 1, 5" I Schlumber Well 4-24 the correct APl # is 50-029-21508-00 Number of Records: Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon "State0f Alaska' Mobil Please acknowledge receipt by signing and returning a copy of transmittal. By: .,~/,~c~2 ~¢'.~ Date: RECEIVED ARCO Date: Alaska, Inc. ~ P.O. Box 100360, ,,,.,¢norage, AK 99510,~~, Feb25, 1994 Transmittal #: 94024 Subject: ARCO Static Pressure Surveys From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Well i Log Date Tool Type Run, Contractor NumberI (M-D-Y) Scale 2-3 i 6-5-93 Static Press Surv. 1, 5" Sch 2-5 I 7-21-93 Static PressSurv. I " Sch 3-8 i 11-22-93 Static Press Surv. " Sch 3-19 f 1-3-94 Static Press Sun/. I " Sch 3-34A i 11-22-93 Static Press Sun/. { " 3-35 i 12-7-93 Static Press Sun/. I " 3-36 i 7-24-93 Static Press Sun/. i " Sch 4-12 i 1.1-17-93 Static Press Sun/. t " Sch ' 4-31 ! 1-3-94 Static Press Sun/.. " Sch q 4-32 I 9-8-93 Static Press Sun/. " Sch q~OO -q~ 4-41 i 11-21-93 Static Press Sun/. ~ " Sch '~.'2r-.iLt* ~ 5-12 f 7-21-93 I Static Press Sun/. ! " Sch ~:~4.o-qT..-z-o 6-19 i111'28'93 Static Press Surv. i .. " Sch 7-7A I 7-2'~-93 Static Press Surv.I " Sch . 7-8 I 9-2-93 Static Press Sun/., " Sch 9-49 ~ 9-14-93 Static Press Sun/. f " Sch ~tt~---tEOq,-4' 11- f 9-5-93 Static Press Sun/. " Sch 11-17 ! 11-26-93 Static Press Sun/. " Sch 12-16At 11-8-93 Static Press Sun/.I " Sch 13-14 ! 7-2-93 Static Press Surv.i " Sch 13-14 i 7-2-93 Static PressSun/. " Sch 14-01 i 11-25-93 Static Press Surv. " Sch 14-6i 11-25-93 Static Press Sun/. " Sch 14-18 11-26-93 Static Press Surv. " Sch 14-38 12-4-93 Static Press Sun/. " Sch i /4~'O- [6"~"~0 14-39 12-4-93 Static Press Sun/. " Sch cti'~cc(3--q~c[et 15-6 5-28-92 Static Press Sun/. " Sch 15-15 7-5-93 Static Press Sun/. " Sch t, 10~-L(O -[OcU, O 15-16 8-26-93 Static Press Sun/. " Sch 15-18 i 10-26-93 Static Press Sun/. " Sch 15-23 i 9-23-93 Static Press Sun/. " Sch 16-12 ! 7-21-93 Static Press Surv. " Sch 16-17 ! 12-29-93 Static Press Sun/. " Sch 5000 16-18 ! 7-18-93 Static Press Sun/. " Sch 16-22 I 7-18-93 Static PressSun/. " Sch 17-1 ! 11-23-93 Static Press Sun/. " Sch 17-13 I 8-27-93 Static Press SurV.I " Sch 18-29A I 5-19-93 Static Press Sun/.I ARCO Al~sl(a, Inc. Is a 8ubMdlm'y of Atlantlc~chfleldCompsny ARCO Alask~ Inc. P.O.Box 100360 Anchorage, ~laSk~ 99510 DATE: 7-7-93 REFERENCE: ARCO CASED HOLE FINALS ~~ 10-12-92 Perf Record ir ~.'~J3-25 8-15-92 Perf Record 8-15-92 Perf Record 9-19-92 Perf Record 5-2-92 GR/Temp Log 10-17-92 Perf Record 8-21-92 Perf Record 8-22-92 Perf Record 6-23-92 GR/Perf Record 10-19-92 Perf Record 8-11-92 Perf Record 10-16-92 Perf Record Run 1, 5" HLS Run 1, 5" HLS Run 1, 5" HL8 Run 1, 5" HI~ Run 1, 5" HLS Run 1, 5" HLS Run 1, 5" HLS Run 1, 5" HLS Run 1, 5' HLS Run 1, 5" HLS Run 1, 5" HLS Run 1, 5" HLS Please sign and return th attache~l Fopy as receipt of data. RECEIVED , Have A Nice Sonya Wallace ~~ ~ ~'~ APPROVED ATO-1529 ~ 0 '1 ~'~ # CHEVRON D &M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL Trans# 93005 # PHILLIPS PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO * The correct API# for 3-34A is 50-029-21132-01. ** The correct API# for 7-4A is 50-029-20292-01. ARCO Aluka, Inc. P.O.Box 100360 Anchorage, ~ukl 99510 REFERENCE: ARCO CA~ED HOLE FINAL8 1-7--7~-1'7 2-20-93 Leak Detect Run 1, 5" -/~-.~.~1-9 12-22-92 Perf Record Run 1, ~,.1-9 3-18-93 Prod Profile Run 1, 5" 1-10--'7~'L~ 3-5-93 Prod Profile Run 1, 5" ~_~ l~c~ ~1-24A 2-8-93 PITS Run 1, 5" 2-11--'~-~2-23-93 Prod P~oflle Run 1, ~)-(~ -'2-13 2-13-93 Perf Record Run 1, 3-1---1~-'7~ 1-8-93 Prod Profile Run 1, -~C~_ ES -'3-9 11-12-92 Perf Record Run 1, 3-34A ~'~ 1-28-93 Prod Profile Run 1, ~--~ ~ -.-4-12 __ _ 9-19-92 Collar Log Run 1, ' 4-24--~-~)~ 3-6-93 Leak Detection Run 1, 2"&~' -7~ ~ ~5-6 2-13-93 Prod Profile Run 1, 5-11-'~'~O 8-13-92 TMD Run 1, ~c~ ~) { .. 5-22 2-9-93 Perf Record Run 1, 5" 6-3- ~- '~ 1-22-93 Perf .Record Run 1, "~-~ ~ ~6-10 2-16-93 Prod Profile Run 1, 1-22-93 Pert Record aun 1, 6-18~ 2-22-93 Prod Profile Run 1, ~\~ -6-19 2-16-93 Prod Profile Run 1, 730/~ ''- 2-15-93 Prod Profile Run 1, "~(d' ~(~ ~-9-2 . 2-8-93 Prod Profile Run 1, 9-7-'7(~'-~ 3-9-93 Prod Profile Run 1, ~"~ ~-7 --9-16 3-9-93 [nj Profile Run 1, 5" 9-42-~0'-~ 2-20-93 Temperature Log Run 1, c~ ~ ~ }~ -9-49 2-6-93 Prod Profile Run 1, 11-1A~ c~-) ~7_2-14-93 GR/Collar Run 1, 11-1A~ 3-19-93 GR/Collar Run 1, ~c~-- ~C) { --13-30 2-19-93 Prod Profile Run 1, 13-33~;~_ ~ [~12-14-92 Tracerscan Run 1, 13-33! ..... 12-14-92 Tracerscan LOg Run 1, c~°~-Ot --14-5A 3-19-93 PITS Run 1, /14-28 3-2-93 Baker IBP/Collar Run 1, ~"- ~- '-~14-28 3-8-92 Baker IBP/Collar Run 1, * 14-34-~-~12-10-91 TMD Run 1, ~- ~ ~ --16-25 2-26-93 Prod Profile Run 1, 16-26-c~--~2-28-93 Prod Profile Run 1, C~_(~. --16-28 2-28-93 Prod Profile Run 1, ** 16-29A-C~.-(v~3-1-93 Prod Profile Run 1, 5" ~-~ ~C~' --17-15 11-16-92 Perf Record Run 1, 5" ~17-16 1-12-93 Perf Record Run 1, 5" Please sign and return t~e attached c~opy u~recet~t of data. Have A Nice Day! ~ Sonya Wallace ATO-1529 Trans# 93049 Cmco HIS Camco Camco Camco Camco HIS Camco HIS Camco HIS Camco Camco HL8 HIS HIS Camco HIS Camco Camco HIS Camco Camco Camco Camco Camco Camco Camco Camco Camco HIS HIS Camco Camco Camco HIS Camco Camco Camco Camco HL8 HIS CENTRAL FILES CHEVRON # LUCILLE JOHNSTON EXXON MOBIL # PHILI, IP8 #11PX # STATE OF ALASKA The correct APl# for 14-34 is 50-029-21010-00. The coorect well name for this log is 16-29A. ARCO Alaska~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOLE FINALS 1-17 12-1-92 Prod Profile Run 1, 5" 3-9 12-4-92 Prod Profile Run 1, 2"&5" -~q~1o~-3-18 12-5-92 InJ Profile Run 1, 5" -*--3-34A 11-12-92 Temperature Run 1, 5" ~%--4-5 11-23-92 Jewelry Run 1, 5" ~4-23 12-7-92 Leak Detect Run 1, 5" ~6-12A 12-4-92 GR/Collar Run 1, 5" ~9-19 11-21-92 InJ Profile Run 1, 5" ~9-26 11-27-92 Prod Profile R~m 1, 2"&5" 9-28 12-7-92 Prod Profile Run 1, 5" ~9-33 11-29-92 Prod Profile Run 1, 5" ~12-29 11-20-92 Prod Profile R~m 1, 5" ~-~13-32 12-11-92 InJ Profile Run 1, 5" ~~%/14-33 12-1-92 Prod Profile Run 1, 5" Cll/nco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Pleue sign and return the attached copy as receipt of data. RECEIVED BY___~_~j~.~ Have A Nice Day! Sonya Wallace ATO-1529 APPR OVED___~~~ Trans# 93039 # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON M&RATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO '" * The correct well name for this log is 3-34A. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: REFERENCE: ARCO CASED HOLE FINALS -11 1-24-93 -11 2-7-93 1-13 2-7-93 ~1-24A 2-20-93 ~-L'~~1-30 1-24-93 2-14 7-27-91 ~ ~.~~3-24 1-25-93 ~~3-32 4-25-92 3-32 4-25-92 · ~'32 2-19-93 ~3-34A 2-19-93 ,4-35 8-16-92 ~01~-4A 3-2-93 1-13A 3-8-93 1-18 ~-1~-0~ ~12-4A 2-11-93 ~12-29 12-22-92 ~12-32 12-26-92 ~14-5A 2-20-93 ~14-12 4-24-92 4- 4- 2 4-37 4- 3- 2 4-37 4-13-92 RECEIVED 6-21 7-23-92 PSGT Computed Results 6-21 7-23-92 PSGT ~.-~-~-'-~ 16-27 8-23-92 Perf Record 1~ 7~ 16-30 2-12-93 Perf Record ~ ]~~17-21 12-20-92 Perf Record Please sign and return t~e attached copy as receipt of data. 8onya Wallace ATO- 1529 '.Alaska Oil &^.,,~..~_6as Cons. Commies/on Peff Record R~ 1, ~' H~ Pe~ Record Pe~ Record R~ 1, ~' H~ Pe~ Record T~ R~ 1, ~* H~ Pe~ Reco~ Pe~ Record R~ 1, ~' H~ PGST Computed Resets PSGT Pe~ Record Pe~ Record R~ 1. ~' H~ T~ R~ 1, 5' H~ DSN .TMD Boron ~Jection R~ 1, Pe~ Record Pc~ Record PSGT Computed Resets ~GT 5 ~/Mh R~ 1, ~' H~ ~GT 10 ~/~ Pe~ Record Pe~ Record R~ 1, ~* H~ PSGT Computed Resets PSGT R~ 1, ~' H~ Pe~ Record PSGT Computed Re~s PSGT R~ 1, ~' H~ Pe~ Record R~ 1, Pe~ Reco~ Pe~ Record Pe~ Record R~ 1. Perf Record R~ 1, PSOT Computed Resets PSGT PSGT Computed Resets PSGT R~ 1, ~' H~ R~ 1, ~' H~ R~ 1, ~' H~ R~ 1, ~' H~ R~ 1, ~' H~ APPROVED Trans# 930 # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # PHILLIPS # MOBIL # BPX # STATE OF ALASKA * The correct apl# for 3-32 is 50-O29-21141-00. STATE OF ALASKA ALASKA , AND GAS CONSERVATION REPORT SUNDRY WELL OP ATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 97' NSL, 846' EWL, Sec. 11, T10N, R15E, UM At top of productive interval 2516' NSL, 564' EWL, Sec. 14, T10N, R15E, UM At effective depth At total depth 2424' NSL, 592' EWL, Sec. 14, T10N, R15E, UM 12. Present well condition summary Total depth: Perforate 5. Type of Well Development Exploratory Stratigraphic Service J EEEIVED 0 CT 2 6 1992 Alaska 0il & Gas Cons. Commission An~horaga Other 6. Datum of elevation(DF or KB) 62' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-34A 9. Permit number/approval number 92-18 10. APl number 50 - 029-21132-01 11. Field/Pool Prudhoe Bay Oil Pool measured 9978' feet true vertical 9213' feet Plugs(measured) Fill @ 9914' MD (9/15/92) Effective depth: measured 9914' feet true vertical 9155' feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 1865# Poleset 110' 110' Surface 2439' 13-3/8" 2300 sx CS III 2501' 2501' Production 7948' 9-5/8" 500 sx CIG & 300 sx CS I 8010' 7498' Liner 2236' 7" 426 sx CIG 7742-9978' 7258-9213' Perforation depth: measured 9482-9500'; 9611-9640'; 9753-9763'; 9777-9788' true vertical 8761-8778'; 8879-8905'; 9008-9017'; 9030-9040' Tubing (size, grade, and measured depth) 4-1/2", 12.6g, 13-Cr, 4-1/2"x3-1/2" x-over @ 7729' MD; 3-1/2", 9.2#, 13-Cr w/tail @ 9255' U D Packers and SSSV (type and measured depth) 4-1/2", AVA SSSV @ 2208' MD; 7" TIW HBBP packer @ 9187' 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 Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 76O 778 1267 1082 --- 1568 1019 Tubing Pressure 329 314 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 06/15/88 910/12 JCA cc: SW, JWP Date SUBMIT IN DUPLICATE 3.34A DESCRiPTiON OF wORK cOMPLETED HYDRAULIC FRACTURE TREATMENT OF SAG RIVER 919192' dVVoatr a~ nt hse~t :pum Peal RIH & tagged bottom at 9929' MD. 9 / 1 0 / 9 2: eouipment to 4000 psi. RIH w/CT & toaded the wellbore ?/,1 MIRU & PT slurry containing 20/40 mesh sand, to plaCe a prefrac sand p~ug ~-, ........ e gelled sand Ref. Log: BHCS 4/11/92. 9611 - 9640' MD 9753 ' 9763' MD 9777 - 9788' MD Made final tag on top of sand plug at 9531' MD. pOOH w/CT. Rigged down. 9/12/92: RIH & retagged top of sand plug at 9528' MD. 9 / 1 3 / 9 2 ' Pumped a Hydraulic Fracture Treatment, using 16t20 mesh proppant, through the MIRU & PT equipment. open pedorations above the sand plug at: Ref. Log: BHOS 4/11/92. 9482 - 9500' MD (Sag) pumped: a) 211 bbls Pre pad @ 30 bpm, followed by b/Shutdown. ISIP @ 1750. Resumed pumping: c) 303 bb~s 40# Crosslinked Pad v~/5% Diesel @ 30 bpm, followed by d) 549 bbls Cross Linked Slurry @ I - 10 PPg, followed by e) 135 bbts Flush, followed by f/ Shutdown- Rigged down. placed a total of 109,920 tbs of proppant into the formation. MD. g/14192: performed a proppant/sand plug flit c[eanout to 9904' 9/15/92: RtH & tagged bottom at 9914' MD. Returned welt to production w/gasiitt & obtained a vatid welltest. R[EEIVED OCT ? 6 1992 Alaska Oil & Gas Cons. Commission ~,n.chorage STATE OF ALASKA ALASKA AND GAS CONSERVATION CE .41SSION 8 ~ 16 l REPORT OF SUNDRY WELL OPE'RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 4. Location of well at surface 97' NSL, 846' EWL, Sec. 11, T10N, R15E, UM At top of productive interval 2516' NSL, 564' EWL, Sec. 14, T10N, R15E, UM At effective depth At total depth 2424' NSL, 592' EWL, Sec. 14, T10N, R15E, UM Repair well Other ,, 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 62' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-34A 9. Permit number/approval number 92-18 10. APl number 50 - 029-21132-01 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9978' feet Plugs(measured) 9213' feet Effective depth: measured 9935' feet true vertical 9173' feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 1865# Poleset 1 10' 110' Sudace 2501' 13-3/8" 2300 sx CS III 2501' 2501' Production 8010' 9-5/8" 500 sx CI 'G' & 300 sx CS I 8010' 7498' Liner 2236' 7" 426 sx CI 'G' 7742'-9978' 7258'-9213' Perforation depth: measured 9482-9500';9611-9640';9753-9763';9777-9788' true vertical 8761-8778';8879-8905';9008-9017';9030-9040' 4-1/2,12.6#,13CR,4-1/2"x3-1/2 "x-over @ 7729' MD;3-1/2",9.2#,13CR w/tail @ Tubing (size, grade, and measured depth) ' " 9255' MD Packers and SSSV (type and measured depth) 4-1/2", AVA SSSV @ 2208' MD; 7" TIW 'HBBP' pkr @ 9187' MD 13. Stimulation or cement squeeze summary ~ [ E b i V ~ U 14. Intervals treated(measured) S E P 1 ? ltlg Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. C0m~'tss't¢ Representative Daily Average Production or Injection Data AnChorage Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl 545 371 1932 1000 817 1326 Casing Pressure Tubing Pressure 376 317 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 r rS--2 Regional Operations Engineer Form 10-404 Rev 06/15/88 y SUBMI-I/IN Di~PLIcATE ~ ~.~.rLY REPORT OF WELL OPEIL.~ONS DS 3-34A Perforating Operations: ARCO Alaska, Inc. perforated DS 3-34A at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 8/15/92. The intervals perforated were the following: 9482'-9500', 9753'-9763' and 9777'-9788' MD (Reference Log: AWS-BHCS dated 4/11/92). Production fluid 'was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 8/15/92. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. SI well, RIH and perforated 9482'-9500' MD at 4 SPF, POOH and confirmed all shots fired. RIH and perforated 9777'-9788' MD at 4 SPF, logged up and perforated 9753'-9763' MD at 4 SPF, POOH and confirmed all shots fired. (ref: AWS-BHCS of 4/ll/92).Rigged down and secured well. RDC: 9/3/92 RECEIVED SEP 1 7 1992 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA AND GAS CONSERVATION CC /llSSION O i /4z L REPORT iurF. 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 97' NSL, 846' EWL, Sec. 11, T10N, R15E, UM At top of productive interval 2516' NSL, 564' EWL, Sec. 14, T10N, R15E, UM At effective depth At total depth 2424' NSL, 592' EWL, Sec. 14, T10N, R15E, UM 5. Type of Well Development X Exploratory ~ Stratigraphic Service 6. Datum of elevation(DF or KB) 62' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-34A 9. Permit number/approval number 92-18 10. APl number ,.,;,,,,, 50 - 029-21132-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9978 feet Plugs(measured) 9213 feet Effective depth: measured 9687 feet true vertical 8949 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 1865 # Poleset 110' 110' Surface 2439' 13-3/8" 2300 sx CI III 2501' 2501' Production 7948' 9-5/8" 500 sx CIG & 300 sx CS I 8010' 7498' Liner 1410' 7" 300 sx CIG 9152' 8469' Liner 826' 7" 426 ssx CIG 9978' 9213' Perforation depth: measured 9611-9640' true vertical 8879-8906' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 CR, Tbg @ 7729' MD; 3-1/2", 9.2#, 13 CR, Tbg @ 9255' MD Packers and SSSV (type and measured depth) 7" TIW "HBBP" Packer @ 9187' MD; 4-1/2", AVA SSSV @ 2208' 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 Representative Daily Average Production or Iniection Data, OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 101 292 274 645 537 2062 Tubing Pressure 251 399 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 ~..~"Z... ~ Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 862/10 DTK cc: SW, JWP 3-34A DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF ZONE 4 6/20/92: MIRU & PT wireline equipment to 3000 psi. RIH & set a 6500 psi differential Shear Disk in the 3-1/2" XN Nipple at 9242' MD, to prepare for a ROPE Treatment (Really Overpressured Perforation Extension), on the perforations located at: 9611 9640' MD (Z4) Ref. Log: BHCS 4/11/92. POOH w/wireline, then pressured up on Shear Disk pumping 50 bbls Seawater, and ruptured the Shear Disk. RIH & retrieved the ruptured shear disk from tubing tail. Rigged down. 6/21/92: MIRU & PT to 9300 psi. Pumped a Hydraulic Fracture Treatment, using 16/20 mesh Carbolite proppant, through the perforations (listed above). Pumped: a) 301 bbls Pre Pad, @ 30 bpm, followed by b) Shutdown. ISIP @ 1945. Resumed pumping: c) 303 bbls 40# Crosslinked Pad w/ESL, @ 30 bpm, followed by d) 353 bbls Slurry w/proppant stages @ I - 10 ppg, followed by e) Shutdown. Placed a total of 23,587 lbs of proppant into the formation. Rigged down. 6/22/92: Performed a proppant fill cleanout to 9850' MD. 6/23/92: Tagged bottom at 9687' MD. Returned well to production with gaslift and obtained a valid welltest. STATE OF ALASKA v., , ~. ALASKA 'AND GAS CONSERVATION C( /IISSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed' Opera[ion shutdown Stimulate Plu99m9 Perforate X ...... Pull tubing Alier casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 97' NSL, 846' EWL, Sec. 11, T10N, R15E, UM At top of productive interval 2516' NSL, 564' EWL, Sec. 14, T10N, R15E, UM At effective depth At total depth 2424' NSL, 592' EWL, Sec. 14, T10N, R15E, UM 5. Type of Well Develop merit bxploratory Stradgraphic Service X 6. Datum of elevation(DF or KB) 62' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-34A 9. Permit number/approval number 92-18 10. APl number 50 - 029-21132-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9978' feet 9213' feet Plugs(measured) Effective depth: measured 9935' feet true vertical 9173' feet Junk(measured) Casing Length Size Conductor 1 '~ 0' 20" Su dace 2501' 13-3/8" Production 8010' 9-5/8" Liner 2236' 7" Cemented Measured depth 1865# Poleset 110' 2300 sx CS III 2501' 500 sx CI °G'& 300 sx CS I 8010' 426 sx CI 'O' R E C F ~ V ~ ~742'-9978' True vertical depth 110' 2501' 7498' 7258'-9213' Pedoration depth: measured 9611-9640' true vertical 8879-8905' Alaska 0ii & Gas Cons. Anchora~le Tubing (size, grade, and measured depth) 4-1/2",12.6#,13CR,4-1/2"x3-1/2 X over @ 7729' MD;3-1/2",9.2#,13CR w/tail 9255' M D Packers and SSSV (type and measured depth) 4-1/2", AVA SSSV @ 2208' MD' 7" TIW 'HBBP' pkr @ 9187' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Mbt Casing Pressure Prior to well operation 0 0 0 Tubing Pressure Subsequent to operation 300 1530 250 330 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil X__ Gas ~ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~.~¢~/¢,,¢¢',~',4¢'P~.,?' Title Form 10-404 Rev 06/15/88 FS-2 Regional Operations Engineer Date SUBMIT IN-iCuPLICATE .~JLY REPORT OF '~,~ELL OPER~.,.~-/ONS DS 3-34A Perforating Operations: ARCO Alaska, linc. perforated DS 3-34A at a selected interval in the Sadlerochit Sand of the Prudhoe Bay Unit on 4/23/92. The interval perforated was the following: 9611'-9640' MD (Reference Log: AWS-BHCS dated 4/11/92). Production fluid was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 4/23/92. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. RIH and perforated 9631'-9640' MD at 4 SPF, S.I well, POOH, 33 of 36 shots fired. RIH and perforated 9611'-9631' MD at 4 SPF, S.I well, POOH, and confirmed all shots fired. (ref: AWS-BHCS of 4/ll/92).Rigged down and secured well. RDC: 7/29/92 ARCO Alaska, Inc. Post Office Box Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 13, 1992 Ms. Joan Miller Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Ms. Miller: RECEIVED AU G 1 i' Alaska 0ii & Gas Cons. (;0m~tssL~n ~chorage Per our phone conversation of 8/12/92: (1) Please find attached copies of the Application and the Report Sundry pertaining to Approval # 90-519. Verbal approval was granted 6/5/90 to perforate Well 1-30, and the work was reported on a 10- 404 on 6/29/90. The Application was sent 7/2/90. Both reference the same approval number. (2) Regarding Approval # 9-692 on Well 16-20, please find enclosed a 10-404 Report Sundry for Bridge Plug Installation and Removal. In this case, the approved Application of 8/14/89 was for a Choke Packer Installation that was never performed. Per your request, the Bridge Plug Installation (11/90) and its removal (3/92) is reported referring to the 9-692 Approval #. (3) Regarding Approval # 91-090 on-Well 3-11i, of approval date 3/15/91, requesting approval for an Annular Communication Evaluation, I have directed your request for a 10-404 Report submittal to Julie Heusser / James Styler (at 659-5102), who are the Annular Communications Engineers responsible for filing this Report. (4) Regarding recent sidetrack work completed on Well 3-34A, the 10- 407 Completion Report is enclosed for the P&A of the old wellbore (--(3-34). Per conversation on 8/12/92, with Marion Sloan (564-5127) at BPX, the Completion Report for the new Well 3-34A, was sent 7/6/92. If missing from your files, she will supply another copy. ARCO Alaska, Inc. is a Subsidiary of Allanllc Richfield Company AR3B-6003-C Ms. Joan Miller August 13, 1992 Page 2 Regarding the 16-9A Rig Workover for Packer Failure, Marion will work on compleang the outstanding 10-407 Recompletion Report. Sincerely, . /' ........ L.;~ ;;~~ L ', John W. Peirce Engineering ~de JWP/002 Attachment cc: ~/~,on. Cawvey _ (ARCO) _ ATO- 1520 Juhe Heusser / James Styler- (ARCO) - PRB-24 Marion Sloan - (BPX) - Drilling Dept. RECEIVED AU G 1 ? 1992 Alaska Oil & Gas Cons. Commission ;Anchorage STATE OF ALASKA, 0 ~ i ~ I ~ ~ ~' ALASKA'"OlL AND GAS CONSERVATION C~'MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG , , 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2'. Name of Operator 7. Permit Number ARCO Alaska, Inc. 92-18 ,, 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-21132-01 4. Location of well at surface 9. Unit or Lease Name 97' NSL, 846' EWL, SEC. 11, T10N, R15E, UM !i ~'F~,..'I?L.'E'~;~ !¢~~I' ' '" --""'"""~'~1 ' 10.Prudh°ewell NumberBay Unit At Top Producing Interval ¢ "~'~"~'~:'! · VEL'IReD I DS 3-34A 2516'NSL, 564'EWL, SEC. 14, TION, R15E, UM ~' ~'~,,81..RE0 j .~,.~t~_.' 11. Field and Pool At Total Depth~~ '--'~~'~¥'/~'"" i~; Prudhoe Bay Field/Prudhoe Bay Pool 2424' NSL, 592' EWL, SEC. 14, T10N, R15E, UM .... 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 62' ADL 28332 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions I 4/6/92 4/9/92 4/23/92 N/A feet MSL I ONE 1~'. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost I 9978'MD/9213' TVD 9935'MD/9173' TVD YES [] NO [] 2208'feet MD I 1900' 22. Type Eleclric or Other Logs Run CH T/TEMP/GR/C N/A C/D IFL 23. CASING, LINER AND CEMENTING RECORD SE-I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED .... 20" cond H-40 Surface 11 O' 30" 1865 # Poleset 13-3/8" 72# L-80 Surface 2501' 17-1/2" 2300 sx CS III 9-5/8" 47# L-80 Surface 8010' 12-1/4" 500 sx CI ass "G"/300 sx CS 7" 26" L- 80 7742' 9152' 8-1/2" 7" 26# 13CR80 9152' 9978' 8-1/2" 426 sx Class "G" 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4spf 4-1/2"X 3-1/2" 9255' 9187' MD TVD 9611 '-9640' 8879'-8905' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Melhod of Operation (Flowing, gas lift, etc.) 4/24/92 Gas Lift D'~.te of Test Hours Tested PRODUCTION FOR OIL-BBL GAS~MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,,Ir 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. R' CEI'VED d UL -- 9 t99~ Alaska Oil & 6as Ooas. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS """--~ "~"F'~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Bas HRZ 9436' 8924' Shublik 9505' 8993' Top Sadlerochit 9595' 9083' JUL - 9 I 92 laska 0Jj & 6as Cons, 31. LIST OF ATTACHMENTS 32. I hereby cedify that the foregoing is true and correct to the best of my knowledge Signed ~/I '~.~_,~ Title Drilling EngineerSuoervisor 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". Form 10-407 ACTIVITY SUMMARY for WELh~-3ROJECT 4J0148 %-~ Page: 1 FIELD : PRUDHOE BAY WELL : DS 3-34A COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK RECEIVED : WO/COMP RIG: NABORS 2ES d u L - 9 Alaska Oil & Gas CoI~s..Com~ss[oB.. -- (COMP) KILL: 5.5 NU ND: 8-.5 PL~ ~1~~ 0 ~ ' -- ~ 5-z-i'/~'CMP MW: 9.8 04/02/92 ( 1) PULLING EXISTI~ LTN TD:10022 ACCEPT RIG AT 1400 HRS. 4/2/92. ATTEMPT TO PULL BPV. PB: 9823 CIRC. NU BOPS & TEST. SUPV:LAP (4J0148) DAILY: $ WBM 26,064 CUM: $ 26,064 EFC: $ 1,717,000 (COMP) OTHER: 1.5 PL TBG: 7.0 ST SEC: 15.5 04/03/92 ( 2) RUN--NING VERTILOG--CASING INSPEG MW: 0.0 WBM TD: 8290 FINISHED PULLING 5-1/2 COMPLETION. SET BRIDGE PLUG AT PB: 8290 8290' POH. PREPARED TO RIH & LOG. SUPV:LAP (4J0148) DAILY: $ 35,194 CUM: $ 61,258 EFC: $ 1,717,000 (COMP) LOG PERF: 3.5 OLD PROB: 1.0 ST SEC: 19.5 04/04/92 (-- 3) MILLIN~ SECTION IN 8-~/8 SECTN MW: 9.8 WBM TD: 8290 INSPECTED 9-5/8 CASING FROM 8285 TO SURFACE. GOOD PB: 8290 CONDITION OVERALL. RIH W/BHA %1. CUT FROM 8010 TO 8060'. SUPV:LAP (4J0148) DAILY: $ 52,480 CUM: $ 113,738 EFC: $ 1,717,000 (COMP) OTHER: 1.0 ST SEC: 23.0 04/05/92 ( 4) POW W/SECTION MILL MW: 9.8 WBM TD: 8290 CONTINUED MILLING FROM 8060 TO 8075'. POOH. RIH MILL %2. PB: 8290 MILLED TO 8064'. POOH. SUPV:LAP (4J0148) DAILY: $ 133,172 CUM: $ 246,910 EFC: $ 1,717,000 (S1P1) BOPE: 6.0 OTHER: 12.0 TRIP: 6.0 04/06/92 ( 5) RIH W/8.5 STEERABLE ASSY MW: 9.8 VIS: 83 TD: 0' ( 0) RIH. PUMPED SLURRY. ESTIMATED TOP OF CEMENT IS 7908' SUPV:LAP POH. SWITCHED TO DRILLING PHASE. CLEANED AND TESTED BOPS. HOLE ANGLE:34 42 P/U BHA %2. RIH. NOTE: CUMULATIVE COST IS $308,594. (4J0148) DAILY: $ 61,684 CUM: $ 308,594 EFC: $ 1,717,000 (S1P1) DRIL: 14.0 OLD PROB: 8.5 TRIP: 1.5 04/07/92 ( 6) RI~ W/8-1/2 STEERABLE ASS'Y MW: 9.6 VIS: 72 TD: 8056' (8056) DRILLING CEMENT FROM 7841 - 7841' KICK-OFF AT 8015' SUPV:LAP CIRCULATED. POOH. RIH. NOTE: CUMULATIVE COST IS $34~,342. HOLE ANGLE:34 42 (4J0148) DAILY: $ 34,738 CUM: $ 343,332 EFC: $ 1,717,000 (S1P1) DRIL: 23.0 TRIP: 1.0 04/08/92 ( 7) DRLG. MW: 9.5 VIS: 49 TD: 8565' ( 509) RIH TO 8015'. WASH TO 8056'. DRLG F/ 8056'-8565'. NOTE: SUPV:LAP CUMM COST SHOULD BE $405,175. HOLE ANGLE:34 42 (4J0148) DAILY: $ 61,833 CUM: $ 405,165 EFC: $ 1,717,000 (S1P1) DRIL: 14.5 OTHER: 1.5 TRIP: 8.0 04/09/92 ( 8) DRILLING 8-1/2 HOLE MW: 9.5 VIS: 45 TD: 8822' ( 257) RUNNING DD%2. POOH. L/D MWD. M/U BHA %4 & BIT %3. RIH SUPV:DLW TO 4400'. DRILL TO 8822' HOLE ANGLE:34 42 (4J0148) DAILY: $ 68,845 CUM: $ 474,010 EFC: $ 1,717,000 ACTIVITY SUMMARY for WEL~--~ROJECT 4J0148 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : DS 3-34A Page: 2 DRLG RIG : NABORS 2ES WO/COMP RIG: NABORS 2ES (SlP1) DRIL: 24.0 04/10/92 ( 9) TD: 9550' ( 728) SUPV:DLW HOLE ANGLE:34 42 N DRILLING 8-1/2 HOLE TO 9660' MW: 9.5 VIS: 50 (4J0148) DAILY: $ 63,994 CUM: $ 538,004 EFC: $ 1,717,000 (S1P1) CIRC: 2.0 DRIL: 13.0 EVAL: 2.5 TRIP: 6.5 04/11/92 (10) LOGGING OPEN HOLE MW: 9.7 VIS: 48 TD: 9978' ( 428) CONTINUED DRILLING 8-1/2 HOLE TO 9978' CBU. POOH. RUN SUPV:DLW CHT/TEMP/GR/CN/AC DIFL LOGS HOLE ANGLE:34 42 (4J0148) DAILY: $ 34,808 CUM: $ 572,812 EFC: $ 1,717,000 (S1P1) CASG: 9.0 CIRC: 1.5 EVAL: 3.0 OTHER: 1.0 TRIP: 9.5 04/12/92 (11) RUNNING 7" LINER MW: 9.7 VIS: 56 TD: 9978' ( 0) RIH W/BIT #4. RR BIT #1 TO 6198' RIH. CIRCULATE. POOH. SUPV:DLW RUN 7" CHROME LINER. CIRCULATE. HOLE ANGLE:34 42 (4J0148) DAILY: $ 81,689 CUM: $ 654,501 EFC: $ 1,717,000 04/13/92 ( 12) TD: 9978 PB: 9935 SUPV:DLW (COMP) CLN OUT: 8.5 OTHER: 8.0 RUN CSG: 7.5 -- CHANGE OVER TO SEAWATER MW: 8.5 Seawater NOTE CUMULATIVE COSTS IS $799,684. CIRCULATE & RECIPROCATE LINER. TOP OF LINER AT 7742'. PUMP SPACER. PUMPED 426 SX CLASS G CEMENT W/1.0 GPS A600 + .1 GPS D135 + .05 GPS D47 + .3% D65 + .09% D800. RELEASE FROM HANGER. POOH. CIRC. & CHANGE OVER TO SEAWATER. (4J0148) DAILY: $ 161,023 CUM: $ 815,524 EFC: $ 1,717,000 (COMP) CLN OUT: 6.5 OTHER: 0.5 RUN COMP: 16.0 TEST_CSG: 1.0 04/14/92 (--13) RIH W/PRODUCTION TU--BING @ BALE MW: 8.5 Seawater TD: 9978 TEST 7" & 9-5/8". L/D 4-1/2 DP. P/U & RUN PRODUCTION TBG PB: 9935 3-1/2 & 4-1/2 13CR. SUPV:DLW (4J0148) DAILY: $ 290,189 CUM: $ 1,105,713 EFC: $ 1,717,000 (COMP) NU ND: 12.0 RUN COMP: 8.5 04/15/92 ~ 14) MOVI--NG RIG TO DS 4-30ST MW: 8.2 Seawater TD: 9978 RIH W/4-1/2 TUBING. LAND TUBING. INSTALL BPV. ND BOPS. PB: 9935 NU TREE. CIRCULATE. SET PACKER. SET BPV. SECURE TREE. SUPV:DLW RELEASE RIG 0230 HRS. 4/15/92. (4J0148) DAILY: $ 190,912 CUM: $ 1,296,625 EFC: $ 1,296,625 ORIGINAL RECEIVED J u L - ~ GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY PRUDHOE BAY DRILLING COMPANY DS 3-34 A WELL NAME PRUDHOE BAY LOCATION AL392D14 MWD 04/22/92 JOB TYPE SURVEY · NUMBER D~T~ DIRECTIONAL .'3 { o ~· ........... ..... NAME TITLE SIGNATURE TIE IS @ 8010.0 FT 10017.0 FT DEPTH INTERVAL FROM TO 04/02/92 04/09/92 FROM TO DATE SURVEY TAKEN THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. REAT LAND DIRECTIONAL DRILLING, lient .... : ield · 'ell ...... : ection at: :ngineer..: PRUDHOE BAY DRILLING PRUDHOE BAY DS3-34A S,44.09,E BOB MAGOS INC. MEAS DEPTH INCLN ANGLE VERTICAL-DEPTHS BKB SUB-SEA 0 0.00 0.0 -62.0 100 0.25 100.0 38.0 200 0.22 200.0 138.0 300 0.23 300.0 238.0 400 0.45 400.0 338.0 500 0.77 500.0 438.0 600 0.65 600.0 538.0 700 0.50 700.0 638.0 800 0.60 800.0 738.0 900 0.65 900.0 838.0 1000 0.58 1000.0 938.0 1100 0.35 1100.0 1038.0 1200 0.28 1200.0 1138.0 1300 0.32 1300.0 1238.0 1400 0.10 1400.0 1338.0 1500 0.20 1500.0 1438.0 1600 0.25 1600.0 1538.0 1700 0.08 1700.0 1638.0 1800 0.32 1800.0 1738.0 1900 0.72 1899.9 1837.9 2000 1.35 1999.9 1937.9 'Survey Codes: 7/GYRO 'GLDD (c)92 PDS334AD B1.30 8:43 AM 2) RECORD OF SURVEY Computation...: Survey Date...: KB Elevation..: Reference ..... : Magnetic Dcln.: 04/22/92 MINIMUM CURVATURE 04/22/92 62.00 ft 4J0148 30.30 E SECTION DISTNCE DIRECTION BEARING 0.0 N 0.00 E 0.0 S 43.50 W 0.0 S 43.60 W 0.0 S 51.00 W -0.0 S 46.00 W 0.3 S 19.69 W 1.0 S 5.60 W · 1.5 S 21.50 W 1.7 S 43.10 W 1.8 S 43.50 W 1.6 1.3 1.0 0.6 0.3 S 65.39 W S 74.00 W N 84.30 W N 80.19 W N .61.80 W RELATIVE-COORDINATES FROM-WELL-HEAD 0.0 N 0.0 E 0.2 S 0.2 W 0.5 S 0.4 W 0.7 S 0.7 W 1.1 S 1.2 W 2.0 S 1.7 W 3.2 S 2.0 W 4.2 S 2.2 W 5.0 S 2.7 W 5.8 S 3.4 W 6.4 S 4.3 W 6.7 S 5.0 W 6.8 S 5.6 W 6.7 S 6.1 W 6.6 S 6.5 W 0.1 N 19.10 E 6.4 S 6.4 W -0.1 N 19.39 W 6.0 S 6.4 W -0.4 N 48.39 W 5.7 S 6.5 W -0.7 N 21.50 W 5.4 S 6.6 W -0.9 N 56.00 E. 4.8 S ~6.2 W -0.1 N 76.89 E 4.2 S 4.5 W ~CLOSURE DL DISTNCE BEARING /100 0.0 N 0.00 E 0.00 0.2 S 43.50 W 0.25 0.6 S 43.53 W 0.03 1.0 S 45.01 W 0.03 1.6 S 46.00 W 0.22 2.6 S.39.48 W 0.42 3.8 S 31.18 W 0.21 4.7 S 27.31 W 0.22 5.7 S 28.31 W 0.23 6.7 S 30.72 W 0.05 7.7 S 33.80 W 0.24 8.4 S 36.96 W 0.24 8.8 S 39.53 W 0.14 9.0 S 42.36 W 0.05 9.2 S 44.27 W 0.23 9.0 S 44.98 W 0.21 8.8 S 46.77 W 0.16 8.6 S 48.51 W 0.18 8.5 S 50.71 W 0.25 7.8 S 52.24 W 0.72 6.2 S 47.27 W 0.72 I I I i ~ ! I ! t t t i t I ! ! t I ! ~S3-34A MEAS INCLN DEPTH ANGLE 2100 1.12 2200 0.92 2300 0.25 2400 0.13 2500 0.25 2600 1.02 2700 4'.80 2759 5.00 2800 5.85 ~2881 6.50 VERTICAL-DEPTHS BKB SUB-SEA 2099.9 2037.9 2199.9 2137.9 2299.9 2237.9 2399.9 2337.9 2499.9 2437.9 2599.9 2537.9 2699.7 2637.7 2758.5 2696.5 2799.3 2737.3 2879.9 2817.9 2900 7.33 3000 9.00 3003 8.75 3100 10.78 3157 11.50 2898.7 2836.7 2997.7 2935.7 3000.7 2938.7 3096.3 3034.3 3152.2 3090.2 3200 15.18 3281 16.50 3300 18.18 3371 19.00 3400 20.17 3194.0 3132.0 3271.'9 3209.9 3290.1 3228.1 3357.4 3295.4 3384.7 3322.7 3463 21.50 3500 22.05 3557 22.75 3600 23.77 3647 24.24 SECTION DISTNCE 3700 25.00 3800 24.80 3900 25.25 4000 25.75 4100 25.70 0.6 0.8 0.5 0.2 0.3 1.3 5.4 9.4 .12.5 19.0 RECORD OF SURVEY 20.6 30.4 30.7 41.9 49.0 55.2 69.7 73.5 88.6 95.0 3443.6 3381.6 109.5 3477.9 3415.9 118.3 3530.6 3468.6 132.1 3570.1 3508.1 142.9 3613.1 3551.1 154.8 3661.3 3599.3 168.4 3752.0 3690.0 193.8 3842'.6 3780.6 218.7 3932.8 3870.8 244.1 4022.9 3960.9 269.4 'Survey Codes: 7/GYRO DIRECTION BEARING N 56.80 E N 42.60 E N 51.60 W N 50.80 W S 64.5O E S 15.50 E S 6.30 E S 10.00 E S 5.00 E S 1.00 W S 0.50 W S 3.39 W S 3.00 W S 3.60 W S 8.00 W S 6.00 W S 4.00 W S 3.10 W S 5.00 W S 4.80 W S 6.00 W S 6.10 W S 7.00 W S 6.30 W S 8.00 W S 7.89 W S 9.89 W S 9.60 W S 10.10 W S 10.30 W RELATIVE-COORDINATES ,FROM-WELL-HEAD 3.4 S 2.6 W 2.2 S 1.2 W 1.5 S 0.8 W 1.3 S 1.1 W 1.3 S 1.0 W 2.3 S 0.5 W 7.3 S 0.2 E 12.3 S 0.9 E 16.1 S 1.4 E 24.8 S 1.7 E 27.1 S 1.6 E 41.3 S 1.1 E 41.8 S 1.1 E 58.2 S 0.1 E 69.1S 1.0W 79.0 S 2.2 W 101.0 S 4.1 W 106.7 S 4.4 W 129.2 S 6.1 W 138.9 S 6.9 W 161.2 S 9.0 W 174.9 S 10.4 W 196.4 S 12.9 W 213.3 S 14.9 W 232.3 S 17.3 W 254.2 S 20.3 W 295.7 S 26.8 W 337.4, S 34.0 W 379.9 S 41.4 W 422.6 S 49.0 W Page 2 04/22/92 CLOSURE DISTNCE BEARING 4.2 S 37.14 W 2.5 S 27.97 W 1.7 S 28.36 W 1.7 S 39.43 W 1.6 S 36.01 W 2.3 S 13.17 W 7.3 S 1.27 E 12.3 S 4.10 E 16.2 S 4.86 E 24.9 S 3.81 E 27.2 S 3.42 E 41.3 S 1.53 E 41.8 S 1.48 E 58.2 S 0.12 E 69.1 S 0.83 W 79.0 S 1.59 W 101.1 S 2.32 W 106.7 S 2.39 W 129.4 S 2.68 W 139.1 S 2.84 W 161.5 S 3.20 W 175.2 S 3.42 W 196.9 S 3.76 W 213.8 S 3.99 W 232.9 S 4.25 W 252.0 S 4.57 W 297.0 S 5.18 W 339.1 S 5.75 W 382.1 S 6.21 W 425.4 S 6.62 W /lOO 0.49 0.32 0.97 0.12 0.38 0.88 3.80 0.63 2.37 1.13 4.38 1.72 8.57 2.10 1.95 8.62 1.76 8.95 1.44 4.04 2.22 1.49 1.37 2.46 1.78 1.44 0.87 0.47 0.54 0.10 S3-34A RECORD OF SURVEY Page 3 04/22/92 MEAS. INCLN DEPTH ANGLE 4139 25.75 4200 25.88 '4300 26.20 4400 26.73 4500 26.62 4600 26.73 4636 26.75 4700 27.05 4800 26.85 4900 27.00 5000 26.97 5072 27.25 5100 25.68 5200 27.02 5300 26.70 5400 27.63 5500 26.67 5600 26.97 5631 27.00 5700 27.25 5800 27.52 5900 27.40 6000 27.28 6067 27.50 6100 27.57 6200 27.75 6300 28.02 6400 28.27 6500 28.13 6594 28.00 VERTICAL-DEPTHS BKB SUB-SEA 4058.1 3996.1 4113.0 4051.0 4202.8 4140.8 4292.3 4230.3 4381.7 4319.7 4471.1 4409.1 4503.2 4441.2 4560.3 4498.3 4649.4 4587.4 4738.6 4676.6 4827.7 4765.7 4891.8 4829.8 4916.8 4854.8 5006.5 4944.5 5095.7 5033.7 5184.6 5122.6 5273.6 5211.6 5362.9 5300.9 5390.5 5328.5 5451.9 5389.9 5540.7 5478.7 5629.4 5567.4 5718.3 5656.3 5777.7 5715.7 5807.0 5745.0 5895.6 5833.6 5984.0 5922.0 6072.1 6010.1 6160.3 6098.3 6243.2 6181.2 SECTION DISTNCE 279.2 294.4 319.7 345.2 370.6 395.9 405.1 421.3 445.7 469.5 DIRECTION BEARING S 11.00 W S 10.80 W S 10.60 W S 11.30 W S 11.69 W RELATIVE-COORDINATES FROM-WELL-HEAD 439.2 S 52.2 W 465.3 S 57.2 W 508.4 S 65.3 W 552.2 S 73.8 W 596.2 S 82.8 W S 11.60 W 640.1 S 91.8 W S 11.00 W 656.0 S 95.0 W S 12.80 W 684.4 S 101.0 W S 13.80 W 728.5 S 111.4 W S 14.69 W 772.3 S 122.5 W 492.8 S 15.30 W 816.2 S 134.3 W 509.3 S 16.00 W 847.8 S 143.1 W 515.5 S 16.30 W 859.8 S 146.6 W 536.9 S 17.80 W 902.2 S 159.6 W 558.3 S 17.50 W 945.2 S 173.3 W 579.9 601.0 620.9 627.0 640.4 S 17.80 W 988.7 S 187.2 W S 19.00 W 1032.0 S 201.6 W S 20.50 W 1074.5 S 216.8 W S 20.00 W 1087.7 S 221.7 W S 21.39 W 1117.1 S 232.8 W S 22.00 W S 22.60 W S 23.19 W S 22.00 W S 24.00 W CLOSURE DISTNCE BEARING 659.3 677.7 695.7 707.9 713.8 731.2 748.7 766.5 784.5 801.3 442.3 S 6.77 W 468.8 S 7.01 W 512.6 S 7.32 W 557.1 S 7.61 W 601.9 S 7.90 W 646.7 S 8.16 W 662.9 S 8.24 W 691.8 S 8.39 W 736.9 S 8.69 W 782.0 S 9.01 W 827.1 S 9.34 W 859.8 S 9.58 W 872.2 S 9.68 W 916.2 S 10.03 W 961.0 S 10.39 W DL /lOO 0.79 0.26 0.33 0.61 0.21 0.12 0.75 1.36 0.50 0.43 0.28 0.59 5.63 1.50 0.35 1006.3 S 10.72 W 0.94 1051.5 S 11.05 W 1.11 1096.2 S 11.41 W 0.74 1110.1 S 11.52 W 0.74 1141.1 S 11.77 W 0.99 1159.9 S 249.8 W 1186.5 S 12.15 W 1202.5 S 267.3 W 1231.9 S 12.53 W 1244.8 S 285.2 W 1277.1 S 12.90 W 1273.3 S 297.0 W 1307.5 S 13.13 W 1287.3 S 303.0 W 1322.5 S 13.24 W S 23.89 W 1329.8 S 321.8 W S 23.89 W 1372.5 S 340.7 W S 23.69 W 1415.7 S 359.8 W S 23.30 W 1459.0 S 378.6 W S 24.00 W 1499.5 S 396.4 W 1368.1 S 13.60 W 1414.2 S 13.94 W 1460.7 S 14.26 W 1507.3 S 14.55 W 1551.0 S 14.81 W 0.39 0.30 0.30 0.88 2.81 0.19 0.27 0.27 0.23 0.38 'Survey Codes: 7/GYRO S3-34A MEAS DEPTH INCLN VERTICAL-DEPTHS SECTION ANGLE BKB SUB-SEA DISTNCE 6600 28.22 6248.5 6186.5 802.3 6700 28.13 6336.7 6274.7 820.7 6800 28.43 6424.7 6362.7 839.3 6900 28.43 6512.7 6450.7 858.0 7000 28.42 6600.6 6538.6 877.1 7100 28.27 6688.6 6626.6 896.0 7200 28.27 6776.7 6714.7 915.2 7211 28.25 6786.4 6724.4 917.3 7300 27.77 6865.0 6803.0 934.7 7400 27.40 6953.6 6891.6 954.6 7500 26.87 7042.6 6980.6 974.2 7538 27.50 7076.4 7014.4 981.5 7600 27.12 7131.5 7069.5 993.7 7700 26.75 7220.6 7158.6 1013.3 7800 26.57 7310.0 7248.0 1032.6 7900 26.37 7399.5 7337.5 1051.8 8000 25.77 7489.3 7427.3 1070.3 8010 25.70 7498.3 7436.3 1072.1 8194 ~ 29.10 7662.0 7600.0 1120.5 8319 31.40 7770.0 7708.0 116.6.6 8413 32.20 7850.0 7788.0 1206.2 8507 33.20 7929.1 7867.1 1250.5 8601 34.50 8007.2 7945.2 1299.1 8721 34.70 8106.0 8044.0 1365.2 F 10017 34.80 9171.0 9109.0 2096.7 RECORD OF SURVEY DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD S 23.30 W 1502.1 S 397.5 W S 22.69 W 1545.6 S 415.9 W S 23.00 W 1589.2 S 434.3 W S 22.39 W 1633.2 S 452.7 W S 22.30 W 1677.2 S 470.8 W S 22.50 W S 21.50 W S 22.00 W S 20.69 W S 20.39 W S 20.50 W S 21.00,W S 20.10 W S 20.60 W S 20.30 W S 20.50 W S 21.30 W S 21.30 W S 1.00 W S 3.30 E S 11.40 E S 18.50 E S 26.30 E S 34.30 E S 38.30 E 1721.1 S 1765.0 S 1769.8 S 1808.8 S 1852.1 S Page 4 04/22/92 1894.9 S 1911.1 S 1937.7 S 1980.2 S 2022.2 S 2064.0 S 2105.1 S 2109.1 S 2191.2 S 2254.2 S CLOSURE DISTNCE BEARING 2303.2 S 2352.1 S 2400.4 S 2459.2 S 3054.2 S 1553.8 S 14.82 W 1600.6 S 15.06 W 1647.5 S 15.29 W 1694.7 S 15.49 W 1742.0 S 15.68 W DL /lOO 6.61 0.30 0.33 0.29 0.04 488.9 W 1789.2 S 15.86 W 0.18 506.6 W 1836.3 S 16.02 W 0.47 508.6 W 1841.5 S 16.03 W 2.16 523.8 W 1883.1 S 16.15 W 0.88 540.0 W 1929.2 S 16.25 W 0.40 555.9 W 1974.7 S 16.35 W 0.53 562.1 W 1992.0 S 16.39 W 1.76 572.1 W 2020.4 S 16.45 W 0.91 587.8 W 2065.6 S 16.53 W 0.43 603.5 W 2110.4 S 16.62 W 0.22 2154.9 S 16.70 W 0.22 2198.7 S 16.78 W 0.70 2203.0 S 16.79 W 0.70 2286.1 S 16.56 W 5.37 2346.1 S 16.09 W 2.53 2391.5 S 15.62 W 2435.3 S 15.01 W 2476.9 S 14.28 W 2525.8 S 13.19 W 3057.4 S 2.61 W 619.1 W 634.7 W 636.3 W 651.6 W 650.3 W 643.9 W 630.8 W 610.8 W 576.5 W 139.3 W 4.62 4.21 4.82 3.79 0.18 'Survey Codes: 3/MWD 7/GYRO J/PROJECTED S3-34A Page 5 04/22/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA DEPTH 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 MEAS INCLN TVD MD-TVD 'VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT BEARING 162 0.23 162 0 0 262 0.23 262 0. 0 362 0.37 362 0 0 462 0.65 462 0 0 562 0.70 562 0 0 662 0.56 662 0 762 0.56 762 0 862 0.63 862 0 962 0.61 962 0 1062 0.44 1062 0 1162 0.31 1162 0 1262 0.30 1262 0 1362 '0.18 1362 0 1462 0.16 1462 0 1562 0.23 1562 0 1662 0.14 1662 0 1762 0.23 1762 0 1862 0.57 1862' 0 1962 1.11 1962 0 2062 1.21 2062 0 2162 1.00 2162 0 2262 0.50 2262 0 2362 0.18 2362 0 2462 , 0.20 2462 0 2562 0.73 2562 0 2662 3.37 2662 0 2762 5.07 2762 0 2863 6.36 2862 1 2964 8.40 2962 2 3065 10.05 3062 3 0 0 1 1 1 RELATIVE COORDINATES FROM WELL HEAD S 43.56 W 0.35 S S 48.19 W 0.62 S S 47.90 W 0.93 S S 29.69 W 1.59 S S 10.95 W 2.79 S 0 S 15.46 W 3.86 S 0 S 34.90 W 4.69 S 0 S 43.35 W 5.47 S 0 S 57.08 W 6.21 S 0 S 70.73 W 6.61 S 0 S 87.46 W 6.75 S 0 N 81.75 W 6.71 S 0 N 68.78 W 6.61 S 0 N 11.60 W 6.48 S 0 N 4.78 W 6.14 S 0 N 37.38 W 5.81 S 0 N 31.71 W 5.59 S 0 N 26.59 E 4.97 S 0 N 68.96 E 4.36 S 0 N 64.42 E 3.73 S 0 N 47.98 E 2.68 S 0 N 15.91 W 1.62 S 0 N 51.10 W 1,37 S 0 N 52.49 E 1.20 S 0 S 34.06 E 1.72 S S 9.78 E 4.62 S 'S 9.57 E 12.59 S S 0.33 E 22.82 S S 2.35 W 35,85 S S 3.38 W 51.90 S 0.33 W 0.61 W 0.96 W 1.51 W 1.88 W 2.06 W 2.44 W 3.14 W 3.95 W 4.79 W 5.38 W 5.89 W 6.35 W 6.48 W 6.34 W 6.47 W 6.57 W 6.53 W 5.30 W 3.22 W 1.64 W 0.93 W 1.00 W 1.05 W 0.63 W 0.08 W 0.93 E 1.67 E 1.40 E 0.51 E S3-34A Page 6 04/22/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA DEPTH 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT BEARING RELATIVE COORDINATES FROM WELL HEAD 3701 25.00 3662 39 10 S 7.91 W 254.49 S 20.37 W 3811 24.85 3762 49 10 S 9.86 W 300.32 S 27.62 W 3921 25.36 3862' 59 10 S 9.71 W 346.49 S 35.53 W 4032 25.73 3962 70 11 S 10.16 W 393.69 S 43.83 W 4143 25.76 4062 81 11 S 10.99 W 441.07 S 52.53 W 4255 26.05 4162 93 11 S 10.69 W 488.75 S 61.64 W 4366 26.55 4262 104 12 S '11.06 W 537.25 S 70.86 W 4478 26.64 4362 116 12 S 11.60 W 586.50 S 80.76 W 4590 26.72 4462 128 12 S 11.61 W 635.68 S 90.90 W 4702 27.05 4562 140 12 S 12.82 W 685.21 S 101.16 W 4814 26.87 4662 152 12 S 13.93 W 734.64 S 112.91 W 4926 26.99 4762 164 12 S 14.85 W 783.88 S 125.57 W 5039 '27.12 .4862 177 12 S 15.67 W 833.06 S 138.95 W 5150 26.35 4962 188 12 S 17.05 W 880.87 S 152.92 W 5262 26.82 5062 200 12 S 17.61 W 929.05 S 168.20 W 5374 27.39 5162 212 12 S 17.72 W 977.51 S 183.56 W 5487 26.79 5262 225 13 S 18.84 W 1026.51 S 199.66 W 5599 26.97 5362 237 12 S 20.49 W 1074.09 S 216.65 W 5711 27.28 5462 249 12 S 21.46 W 1121.97 S 234.69 W 5824 27.49 5562 262 13 S 22.14 W 1170.14 S 253.97 W 5937 27.36 5662 275 13 S 22.82 W 1218.09 S 273.81 W 6049 27.44 5762 287 13 S 22.32 W 1265.71 S 293.91 W 6162 27.68 5862 300 13 S 23.93 W 1313.63 S 314.65 W 6275 27.95 5962 313 13 S 23.89 W 1361.85 S 336.02 W 6388 28.24 6062 326 13 S 23.71 W 1410.69 S 357.58 W 3167 12.36 3162 5 2 S 7.53 W 71.19 S 1.28 W 3271 16.33 3262 9 4 S 4.26 W 98.08 S 3.89 W 3376 19.20 3362 14 5 S 4.97 W 130.82 S 6.19 W 3483 21.79 3462 21 7 S 6.05 W 168.49 S 9.77 W 3591 23.56 3562 29 8 S 6.44 W 209.77 S 14.50 W ~S3-34A Page 7 04/22/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA DEPTH 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8000 8100 8200 .8300 8400 8500 8600 8700 8800 8900 9000 MEAS INCLN TVD MD-TVD VERT DIRECTION DEPTH ANGLE BKB DIFF CRRT BEARING RELATIVE COORDINATES FROM WELL HEAD 7070 28.32 6662 408 14 S 22.44 W 1707.85 S 483.40 W 7183 28.27 6762 421 14 S 21.67 W 1757.65 S 503.72 W 7297 27.79 6862 435 13 S 20.74 W '1807.31 S 523.22 W 7409 27.35 6962 447 13 S 20.40 W 1856.21 S 541.53 W 7522 27.23 7062 460 12 S 20.79 W 1904.14 S 559.44 W 7634 26.99 7162 472 12 S 20.27 W 1952.37 S 577.47 W 7746 26.67 7262 484 12 S 20.46 W 1999.70 S 595.14 W 7858 '26.45 7362 496 12 S 20.42 W 2046.57 S 612.54 W 7970 25.95 7462 508 12 S 21.06 W 2092.72 S 629.94 W 8081 27.01 7562 519 11 S 13.46 W 2139.17 S 645.66 W 8194 29.11 7662 532 13 ~ 0.96 W 2191.41 S 651.61 W 8310 31.23 7762 548 15 S 2.98 E 2249.29 S 650.55 W 8427 32.35 7862 565 18 S 12.48 E 2310.62 S 642.33 W 8546 33.75 7962 584 19 S 21.77 E 2372.57 S 623.29 W 8668 34.61 8062 606 21 S 30.74 E 2433.59 S 592.80 W 8789 34.71 8162 627 22 S 34.51 E 2491.15 S 554.58 W · 8911 34.71 8262 649 22 S 34.89 E 2548.10 S 515.15 W 9032 34.72 8362 670 22 S 35.26 E 2604.81 S 475.34 W 9154 34.73 8462 692 22 S 35.64 E 2661.27 S 435.14 W 9276 34.74 8562 714 22 S 36.01 E 2717.49 S 394.55 W 9397 34.75 8662 735 22 'S 36.39 E 2773.45 S 353.59 W 9519 34.76 8762 757 22 S 36.76 E 2829.16 S 312.25 W 9641 34.77 8862 779 22 S 37.14 E 2884.61 S 270.54 W 9763 34.78 8962 801 22 S 37.52 E 2939.80 S 228.45 W 9884 34.79 9062 822 22 S 37.89 E 2994.72 S 185.99 W 6502 28.13 6162 340 13 S 23.31 W 1459.87 S 378.98 W 6615 28.21 6262 353 13 S 23.21 W 1508.77 S 400.34 W 6729 28.22 6362' 367 13 S 22.78 W 1558.10 S 421.17 W 6842 28.43 6462 380 14 S 22.74 W 1607.84 S 442.17 W 6956 28.42 6562 394 14 S 22.34 W 1657.86 S 462.85 W )S3-34A Page 8 04/22/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB 9100 10006 34.80 9162 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 844 22 S 38.27 E 3049.37 S 143.16 W )S3-34A Page 9 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 04/22/92 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES DEPTH ANGLE BKB SUB-S DIST BEARING 0 0.00 0 -62 1000 0.58 1000 938 2000 1.35 2000 1938 3000 9.00 2998 2936 4000 25.75 3933 3871 CLOSURE FROM-WELLHEAD DIST BEARING 0 N 0.00 E 0 N 0 E 2 S 65.39 W 6 S 4 W -0 N 76.89 E 4 S 5 W 30 S 3.39 W 41 S 1 E 244 S 10.10 W 380 S 41 W DL/ 100 0 N 90.00 E 0.0 8 S 33.80 W 0.2 6 S 47.27 W 0.7 41 S 1.53 E 1.7 382 S 6.21 W 0.5 5000 26..97 4828 4766 493 S 15.30 W 816 S 6000 27.28 5718 5656 696 S 23.19 W 1245 S 7000 28.42 6601 6539 877 S 22.30 W 1677 S 8000 25.77 7489 7427 1070 S 21.30 W' 2105 S 9000 34.72 8335 8273 1522 S 35.16 E 2590 S 134 W 827 S 9.34 W 0.3 285 W 1277 S 12.90 W 0.3 471 W 1742 S 15.68 W 0.0 635 W 2199 S 16.78 W 0.7 486 W 2635 S 10.63 W 0.2 10000 34.80 9157 9095 2087 S 38.25 E 3047 S 145 W 3050 S 2.73 W 0.2 PRUBHOE ,, , , #arker Zdenttl'tcatton I~ H/S &) I'IE-IN 8010 2i09 BI TD 10017 3054 BAY DRILLING 6,6 t39 ~ CLOSURE .... ' DECLINATION ' SCALE · =DRAWN · DS 3-34A PLAN VIEW 3057 f[ at S 2.6! 30.26 E i inch--500 feet 04/23/92 ~eat Land £JrectJona] t750 i§O0 i250 tO00 750 500 250 0 250 500 ,. 750 iO00 t250 <- WEST · EAST -> PR"ODHOE BAY Marker Identification MD BKB SECTN INCLN Al TIE-IN 80tO 7498 t072 25.70 B) TD 10017 917t 2097 34.80 DRILL-~'NG DS 3-34A VERTICAL SECTION VIEW i Section at: S 44.09 E TVD Scale.' .., ....................................... Oep Scale.' , .................... Drawn .... ! t inch : 300 feet t inch = 300 feet 04/23/92 Great Land Directional D~illin# Section Departure PRUDHOE BAY DRZLLZNG PRUDHOE BAY/3-34A 500292113201 NORTH SLOPE COMPUTATZON DATE: 4 SPFRRY-SUN /13/92 DRZLLZNG SERVZCES ; O ~ I 6 IN A [ "-'PAGE ANCHORAGE ALASKA ,,~,~ ~ DATE OF SURVEY: 04/11/92 ESS CORE ORIENTATION SURVEY JOB NUHBER: AK-EZ-2OO20 KELLY BUSHING ELEV. = 62.00 FT. OPERATOR: ARCO ALASKA ZNC TRUE SUB-SEA MEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH 8010 7498.00 7436.00 8116 7592.97 7530.97 8209 7675.35 7613.35 8303 7756.40 7694.40 8398 7837.26 7775.26 COURS COURSE DLS TOTAL ZNCLN DZRECTZON RECTANGULAR COORDZNATES VERT. DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST SECT. -. 25 42 S 21.30 W .00 2109.003 636.00W 2157.68 27 40 S 4.96 W 7.14 2155.073 646.51W 2204.51 29 17 S 1.52 W 2.46 2199.673 649.00W 2249.!5 31 8 S .13 W 2.11 2246.863 649.66W 2296.22 32 6 S 10.56 E 5,99 2296.233 '645.09W 2344.97 8492 7916.58 7854.58 8585 7994.20 7932.20 8677 8070.13 8008.!3 8770 8i46.44 8084.44 8864 8224.54 8162.64 32 51 S 16.10 E 3.26 2345.313 633.44W 2392.80 34 20 S 23.97 E 4.94 2393.633 615.74W 2439.32 34 42 S 30.18 E 3.84 2440.073 591.99W 2483.45 34 4 S 35.15 E 3.!1 2484.0!S 563.84W 2524.68 33 20 S 35.04 E .78 2526.693 533.85W '2564,49 8959 8304.23 8242.23 9054 8384.94 8322.94 9148 8466.24 8404.24 9244 8549.70 8487.70 9339 8633.81 8571.81 32 35 S 34.91 E .78 2563.993 31 21 S 34.~ ~ 1 .31 2610.333 30 6 S 34.79 E 1.31 2650.0!S 28 34 S 34.02 E 1.66 2688.7!S °6 48 S 32 ~o ~ 1 q9 ?725 613 504.25V,/ 2603.95 475 · 45¥,1 2642 . 53 44.7 . 86V,/ 2679 . 56 ~I.35.W 27'~~,~.72 397. ! 1W 2750.29 9433 8718.37 8656.37 9528 8803.89 8741.89 9622 8889.22 8827.22 9716 8975.33 8913.33 9811 9061.87 8909.87 25 17 S 31.41 E !.70 2760.663 24 52 S 31.85 E .49 2794.7~S 24 35 S 32.64 E .46 2827.983 24 3! S 32.63 E .06 '2861.t23 24 28 S 32.84 E .11 2394.293 375.22W 2783.23 354.23W '28i5.23 333.27W 2846.50 o 12· 04~t ~'~877 .~.~ '~ 290.72W 2903.7,1 9906 9147.41 9085.41 9926 916~.60 9103.60 24 34 S 32.50 E .19 2927.153 24 37 S 3© 57 E 04 ~934 17c THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF THREE-DZMENSZON HZNIHUM CURVATURE ~ETHOD. o69 65W 203¢: 54 ,°65,17~i _0946.!3 HORIZONTAL DIoPLACE~4ENT - 2946. iS FEET AT SOUTH 5 DEG. 9 MIN. WEST AT HD = 9926 VERTTCAL SE3TfON RELAT'I"VE TO !,"/ELL HEAD VERTZCAL ,:.:,E...,~ TON COH, PUTED ALONG 185. 16 DEG. , PAGE 2 SF" '~RY-SUN DR]'LL]'NG SERVT. T. CES ANCHORAGE ALASKA """'"~ PRUDHOE BAY DRZLLZNG PRUDHOE BA¥/3-34A 500292113201 NORTH SLOPE CONPUTATZON DATE: 4/13 /92 DATE OF SURVEY' 04/11/92 JOB NUMBER: AK-EZ-20020 KELLY BUSHZNG ELEV. = 62.00 OPERATOR: ARCO ALASKA ]'NC FT,. ZNTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COQRDZNATES NORTH/SOUTH EAST/WEST MD-TVD VERTZCAL DZFFERENCE CORRECTZON 8010 7498.00 7436.00 2109.00 S 636.00 9!.310 8347.06 828'5.06 2591.39 S 488.63 9926 9165.60 9103.60 2934.17 S 265.!7 512.00 662.94 150.94 . 760.40 97.46 THE CALCULATZON PROCEDURES ,&RE BASED Oki THE Ub~ up THREE-D]'HENS]'ON HZNZHUH CURVATURE HETHOD. SP:RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PRUDHOE BAY/3-34A 500292113201 NORTH SLOPE COHPUTATION DATE: 4/13/92 DATE OF SURVEY' 04/11/92 JOB NUMBER' AK-ET-20020 KELLY BUSH~'NG ELEV. = 62,00 · "",t"' 1 OPERA ICR ARCO ALASKA ]'NC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH FT. MEASD VER DEPTH TRUE SUB-SEA TOTAL TZCAL VERTICAL RECTANGULAR COORDZNAT DEPTH DEPTH NORTH/SOUTH EAST/WE ES ND-TVD VERTICAL ST DIFFERENCE CORRECT]'ON 8010 74 8081 75 8194 76 8310 77 98.00 7436.00 2109.00 S 636.00 W 512.00 62.00 750'0.00 2139.30 S 644.38 W 519.33 7.33 62.00 7600.00 2192.18 S 648.80 Vi 532.58 13.25 62.00 7700.00 2250.25 S 649.64 N 548.23 15.66 8427 8546 8667 8789 8909 7862.00 7800.00 2311.50 S 641.99 W 565,82 17.53 7962.00 7900.00 2373.55 S 623.99 \d 584.90 19.09 8062.00 8000.00 2435.t9 S 594.78 W 605,99 21.09 8162.00 8100.00 2492.62 S 557.78 W 627.12 21.13 8262.00 8200.00 2546,81 S 519,74 W 647,06 19,94 9027 9144 9258 9371 9482 8362.00 8300.00 2598,86 S 483.43 W 665.50 18.44 8462.00 8400.00 2647,99 S 449,26 W 682.04 16.55 8562.00 8500.00 2694.26 S 417.60 W 696.70 14.66 8662.00 8600.00 '2737.61 S 389.46 W 709.28 12.58 8762.00 8700.00 2778.21 S 364.49 W 720.06 10.78 9592 9702 9812 9926 8862.00 8800.00 2817.49 S 339.98 W 730.26 10,20 8962.00 8900.00 2856.00 S 315.32 ~ 740.22 9.96 9062.00 9000.00 2894.34 S 290.68 W 750.12 9.90 9165.60 9103.60 2934.17 S 265.17 N 760.40 10.29 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUH CURVATURE) POINTS ANADRILL 2401 Ci,'~-NABAR LOOP ANCHORAGE, ALASKA 99507 (907) 349-6575 O[{i61NAL April 1_ 3, 1992 Prudhoe Bay Unit P. O. Box 196612 Anchorage, Alaska 99519-6612 Attention: Terry Jordan and Larry Parnell Sirs: I have compiled a summary of Anadrill's MWD performance on DS 3-34A SERVICES PROVIDED Directional Survey Service was picked up after opening the casing window and setting a plug. On 04/06/92 the cement was drilled out and the kick off was begun. After sliding fi'om 8015' to 8057' the motor apparently failed. A tap was made and the motor and bit were changed. The kickoff was resumed and completed on 04/07/92 at 8781'. A tap was made for worn out bit and MWD was laid down at this point. ()Pt~RATING STATISTICS Total M\VD operating time (over 200 gpm) for the well was 51.7 hours. No M\\'D to()l failures occurred while drilling this well. Total footage for M\VD, not count, ing cement, was 766' and was accomplished in 1 M\VI) run. No M\VD thilures or Service Quality problems occurred during this well. J()t~ PERFORMANCE A total of 39 MWD surveys were taken and 6 were used in the final survey calculation. At a measured depth of 8721' the MWD survey showed an inclination of 34.7 deg. and an azimuth of 145.7 degrees. The survey was projected to 8781 which gave a true vertical depth of 8154.99', Latitude 2486.64' South, a Departure of' 555.81' West and a Total Displacement of 2548.00' at an azimuth of 192.6 de~4'rees. F()~' ,,our convenience ] have included an ASCII file of the M\VI) surveys with this rel)<)rt,. Anadril] certainly al~preciates the opportunity to supply the Prudhoe Bay U~it wit]~ MWI) services and we look forward to continuing active pm'ticipation on y()u~' upcoming wells. Sincerely, PRE NO. COMPANt' WELL NA~]~ DS 3-34A LOCATION 1 PRtE)HD~ BAY L~TI~ 2 DATE: ~LL ~d~:~ WD.L H~AD LO~ATION: LAT(hL/-S) 0o00 ~IMLrrF ~KOM ROTarY TAB~ TD TAR~I~T IS TIE IN ~DI~(TIP) : M~,A~iRED DEPTH TI;?dE VERT DEPTH INCLINATIO~ A,:..mulH ~TITUDE(H/-S) DEF'ART~:E (E/-W) 8010.00 7496.00 25.72 20i,34 -606,00 D~'(L!-W) 0,00 135.9i D~'TH D~TH SECTION I~LH. N/-S ft ft ft ft deo dec ft 80i0,00 0,0 7498,00 1072,28 ~,72 ~i.~ 831';',00 125,0 ~9,72 1!66,70 31,30 175.50 ~13.~J ?4.0 7~.67 12~,~' ~,~3 1~.4:~ -2~J2.87 8507,00 94,0 7926.82 1~0,74 ~.20 161.50 -~5i.83 I)S 3-34A L~TI~dDF I)EPAF, TURE DI~PI.A31~gD, ff at AZI~LrH E/-W deo/ it ft d6.p lO:)ft -~.~.',.00 22c:2+01 176.76 '0.~ -65J.35 ~85.89 1~6,56 -~%~, 2~5.77 19~.~ 2.52 -643,37 239l .06 I~5,61 4,63 -~.16 24~.79 l'fS.~, 4.10 8601,03 94,0 E~tK)6.?2 1299,33 34.5D 153,70 6721.00 120.C 8105,75 1365.~. ~.70 145.70 -2458.84 878i.~ ~,0 8154.~k 13~k,30 35,~D 142,70 -248.f.,64 ~:VE)' AT 8791' IS A F~,~?~ S~:~i' AT' T,D. OF IIC~ OFF RtIN. -610,19 2476.48 1;z,26 -~75.~, 2525.38 195.16 -555.61 2546,00 1~2.60 4,82 3,79 2.90 WELL t,~EE ~ 3-34A I.,OCATiON 1 PR~HO~ BAY L~Ti~ 2 ~ ~ ~G~IC DECLINATION ~,30 WELL H~A~: LOCATION: LAT(N/-S) 0.00 AZi~H FR~DM R~}TARY T~ TO T~R3ET IS TIE IN POINT(TIP) ~P~A~:~D DEFq~'H TRUE VB::T DEPTH INCLINATIO~ AZI~]TH LATITdDE(N/-S) DE~AETU~E/-W) 8010,00 7498,00 7.5. ,7,?. 201,34 -636,00 D~'(E./-W) 0,00 135,9i ~ASOg~ED IN',,~RVAL Utt:TJCAL D~F'TH D~fH ft Tt Tt 8010.-00 O,C 74)'8,00 8319,00 1£5.C 7767.72 ~13.0<J 74,0 7849,6? 8507.00 94,C 7928,82 ***,****w,-**.,~ ANADRILL ~**-*~.*.*-**~* SECTI~ I~LN. ft de~ de~: ft ~072,2& ~,72 251.3~ -2107.00 1i~,70 31.30 176.50 -~53.~ 1~0,74 ~,20 161.50 -~51,83 £/-W deg/ ft ft d~o -636,~ 2202.81 196.78 O,C~:' -65~.~ 2285.89 I9J,56 5.38 -649.90 2345.77 19~.06 2,52 -643.37 2391.06 195,61 4,63 -63~'),16 2434,79 195,30 4,10 6601,00 94.0 8606.92 12r~:y.33 24,50 153,70 -2+>0,13 8721.00 120,C 8105,75 1~5,~ ~,70 145.70 -2456,~ 878i,~3 .f~,.O 8154,99 13~',~ ~,~::' 142,70 -2~,64 ~:VE'Y AT 879'I' IS A F~O,~H~ S~'7~Y AT T.D. OF )'.IC): OFF RUN, -610,19 2476,48 -57/5,&5 2525,38 192.18 -555,8I 2546,00 I92,60 4.E.2 3,79 2.90 PA~ NOo ****~** ~B~ ~**~*~ ***~,~ ********************************--**** COM?~¥ AR~ ALASi~iA INC WE~L NAKE ~S 3-34A LOCATION 1 PR~OE BAY L~TI~ 2 ~SB. ~ ~T~: 06-APR-?2 MA:~TiC D~LI~TI~ ft f: cleo deo de~/l~t de~ deo ~/100f~ ft de~ de~/l¢,3it deo/1OOft*~ 80!0,0 74?6,00 0,~ C,O0 0,00 0,~' 9,00 0,00 -1'~-~,~ 0,00 0,¢0 0,0,3 ~,I'~4,0 7~I .~. 3.3-8, 3,38 1,64 , -~:v,~ -20,[.~ -11,~; -1~'2.~' 0.00 5.3_A 2.93 831'?,0 776'.';,72 2,20 5,58 1,76 -4,S0 -24,64 -3.60 -FJ35,05 0,00 2.52 2.29,' 84i3,0 764'~,57 0,90 6,48 0,$'6 -8,10 -3~,94 -~,62 -2C~,41 0,00 4,63 2,24 8507,0 7928,82 1,00 7,48 1,06 -6,~, -3~,64 -7,34 O,OC- 0,00 4.10 0,56. &f.'~;,l,O &?,K~-'..~'2 1.30 8,78 1,3~ -7,80 -47.64 -8,30 -21~,~ 0.00 4,82 0,76 8721,0 8105,75 O, ~,[) E.?6 0,17 -8,~ -55,~ -6,67 -2t24,4~ 0.00 3.7~ 0,86 &781,0 81:'~,fi' 0,~ 9,28 0.50 -3,0C; -~,~ -5.~:, -21~?.~. ~!,31 ~.~ ~'" 1.48 , , ( check off or list data as it is-~receiYed i cored inie~als ,core,,an~l~sis .... d~ ditch in~e~als , digital data ,, ! ...... LoG TYPE ....... RUN INTERVALS '" scALE NO. " = .... ...... . , ]o] .......... , ...... ...... , .... 17] ......... , , ARCO ~l~_~k_~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 6-19-92 REFERENCE: _ ~ (,3-34A 4-11-92 ~C.. ~ ~'J~ 9-306~ 31~619~ 14-19ST / 6-12-92 f..~ ..y-/ 16-25 5/21-6/2/92 ARCO DIRECTIONAL DATA MWD Directional Survey Job#AKMW20011 MWD Directional Survey ESS Core Orientation Survey Job~AKEI20020 MWD Directional Survey MWD Directional Survey Magnetic Multi-Shot Survey Job~AKEI20036 MWD Directional Survey Job#867 Please sign and return the attached copy as receipt of data. RECEIVED BY ~_ ~~' Have A Nice Day! Sonya Wallace ATO-1529 RECEIVED JUN 2 3 1992 Alaska Oil & Gas Cons. Commission Anchorage CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON MOBIL APPROVED Trans# 0212~.-~ PHILLIPS # PB WELL FLS (2 COPIES) R&D # BPX # ST. OF AK. (2 COPIES) TEXACO Sperry Ana Sperry Aha Ana Sperry Teleco MAY 29, 1992 DAVE NAKAMURA BP EXPLORATION ALASKA INC. P O BOX 196612 ANCHORAGE, ALASKA 99518-6612 RE: 84-0097 PRUDHOE BAY UNIT DS3-34 /P&A 92-0018 PRUDHOE BAY UNIT DS3-34A 407 78-0064 PRUDHOE BAY UNIT DS14-5 P&A 92-0001 PRUDHOE BAY UNIT DS14-5A 407 81-0147 PRUDHOE BAY UNIT DSll-3 P&A 92-0008 PRUDHOE BAY UNIT DS4-34A 407 91-0077 PRUDHOE BAY UNIT DS4-39 407 90-0110 PRUDHOE BAY UNIT L5-26 407 DEAR MR. DAVE NAKAMURA, A REVIEW OF OUR FILES INDICATE THAT BP EXPLORATION ALASKA INC. IS THE OPERATOR OF THE SUBJECT WELL. OUR MONTHLY PRODUCTION REPORTS SHOW THAT THESE WELLS ARE PRODUCING OIL AND WE HAVE NOT RECEIVED COMPLETION REPORTS (407'S) FROM YOU OR THE PLUG AND ABANDONMENT PAPERWORK FOR THE ORIGINAL WELL AS PER OUR CONVERSATION MAY 27. A FORM 407 FOR PLUG AND ABANDONMENT OR WELL COMPLETION WITH DAILY WELL OPERATIONS SHOULD OF BEEN FILED WITH THE COMMISSION WITHIN THIRTY DAYS AFTER THESE WELL WERE COMPLETED. PLEASE LET ME KNOW IF THERE IS ANY PROBLEM WITH SUBMITTING THESE FORMS AS REQUIRED IN A TIMELY MANNER. S I NCERELY, STEVE MC MAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-8-92 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS 30~~/~3~2 7292 DIFL/BHCA/~ Job#102152 Please sign and return the attached copy as receipt of data. RECEIVED BY Have A Nice Day! Sonya Wallace ATO-1529 ~,i~.,"~ 'i ~ ~,99~ APPROVED__....= ~- Oil & Gas Cons. Commission ~S~ ~Z~--/ Anchorage CENTRAL FILES (CH) CHEVRON D&M # DEDE SCHWARTZ (OH/GCT) # EXXON MARATHON MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF 2kT~,~K,A TEXACO * The correct APl# for 9-30ST is 50-029-21411. ARCO Alaska, Inc. P. O23ox 100360 Anchorage, Alaska 99510 DATE: 4-29-92 REFERENCE: ARCO CASED HO!.~ ~ ~}~-/ 3-26 3-9-92 Prod Profile Run 1, 5" Camco @z-t~ 3-34A 4-23-92 PFC/GR Run 1, 5" Atlas ¥/-fz/ 5-34 4-24-92 PDK-100/GR/CCL R-- 1, 5" Atlas ? o-//r 9-45 4-21-92 Perf Record Run 1, 5" Sch ~Y~/ 12-3 3-15-92 CSN/GR Run 1, 5" HLS ~/-/z / 13-6 4-20-92 Perf Record Run 1, 5" Sch 31-z~ 13-23A 4-20-92 CCL/Perf Run 1, 5" Atlas E E E I V E D RECEIVED BY ,~- d ~9 ~ve A Nice ~y! AI~G~ Cons. Commissio~ ~n~ W~ce APPROVED ~~ Knchorage ATO- ~ 52~ ~=s~ # CENTRAL FILES # CHEVRON · D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO ARCO Alaska~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-24-92 REFERENCE: ARCO OPEN HOLE FINALS ~ 3-34A 4-11-92 SSTVD 3-34A 4-11-92 BI-ICA-GR 3-34A 4-11-92 DIFL-GR 3-34A 4-11-92 C~R 3-34A 4-11-92 GR RECEIVED BY Run 1, l'&2' R-~ 1, 2"&5" Run 1, 2"&5" R~m 1, 2"&5" R.n 1.2"&5' ~e sign and return the attached copy as receipt of data. Have A Nice Dayt Sonya Wallace ATO- 1529 APPROVED Trans# 92083 # CENTRAL FILES # CHEVRON #D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLn~ # PB WELL ~ R&D # BPX # STATE OF ALAS~ # TEXACO A. PR 3 0 ~99P- Alaska Oil & Gas CoDs. commission AnChorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 February 20 1992 Michael Zanghi Area Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 3-34A ARCO Alaska, Inc. Permit No: 92-18 Sur. Loc. 97'FSL, 846'FWL, Sec. 11, T10N, R15E, UM Btmhole Loc. 2348'FSL, 676'FWL, Sec. 14, T10N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope Pager at 659-3607. Sincerely, ~r ' man Alaska Oz~ and]Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill EIIlb. Type of well. Exploratoryl'-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB -- 62feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADI ~ .~ 5 3 ~ ,~,~_ 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 97' FSL, 846' F~L, Section 11, TION, R15E, UM Prudhoe Bay Unit At,top of proc).u, ctive,.,, interval 8. Well number Number 2530 FSL, 500 FEI_, Section 14, TION, R15E, UM DS 3-34 A 2S100302630-277 At total depth 9. Approximate spud date Amount 2348'FSL, 676'F~, Section 14, TION, R15E, UM February 21, 1992 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line 97 feet N/A: Redrill feet 2560 10022' MD / 9170' TVD~eet :i6. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 9~9ofeet Maximum hole an~)le 40.9 o Maximum surface 3330psig At total depth (TVD) 8800SS/4380psig 18. Casing program Specifications Setting Depth size Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" Cond. H-40 Weld 110' Surface Surface 110' 110' 1865# Poleset 17-1/2" 13-3/8" 72# L-80 BTC 2439' Surface Surface 2501' 2501' 2300 sx CSIII 12-1/4" 9-5/8" 47# L-80 B TC 7948' Surface Surface 8010' 7498' 500 sx CIG & 300 sx CSI 8-1/2" 7" 29# 13Cr-8~ FOX 2272' 7750' 7266' 10022' 9170' 405 cuft Cl G 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~ "'" '"' '" "' -- Present well condition summary Total depth: measured 9860feet Plugs (measured) FEB 1 8 true vertical 9231 feet Alaska 0il & Gas Cons. C0mm'tss[0~ Effective depth: measured 9822feet Junk (measured) Anchorage. true vertical 9196feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 20" 1865# Poleset 110' 110' S u rf ac e 2439' 13-3/8" 2300 sx CSIII 2501' 2501' Intermediate 9262' 9-5/8" 5OOsxClG&JOOsxCSI 9324' 8720' Production Liner 779' 7" 300 sx Cl G 9860' 9231' Perforation depth: measured 9422'-9550'; 9576'-9594' true vertical 8815'-8938'; 8963'-8980' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby certify/~( t~~ng~_~a~correct to the best of my knowledge Si~ned . T it l e Area Drilling Engineer Date'7-~ (-"/C,~ Commission Use Only Permit Number JAPI number IApproval date ~ ~ ISee cover letter ?~-/~, I50-o-z':t- ~//a'=.--,~, I,',~-,~ ~'~ Ifor other requirements Conditions of approval Samples required [] Yes ~'No Mud log required []Yes~No Hydrogen sulfide measures [] Yes ~ No Directional survey requ~re~ ~' Yes [] No Required workin rg~.p__.~_~_urefo~M; 1-13M; /[~5M; I-I10M; I-'115M; Other.~....--------~ . ~-~,~~---~ .... by order of Appro Commissioner [ne commission Date Form 10-401 I ::)-1-85. ~ Submit triplicate D.° -34 PLUGBACK PROCEDUR Procedure Outline: (Refer to attached weilbore schematic) 1. Notify an AOGCC representative prior to commencing operations. 2. Rig up coiled tubing unit. , RIH with coil tubing circulating seawater. Lay a cement plug from current PBTD of + 9581' MD to at least 100' above the top perforation (top perforation at 9422' MD -- cement top no deeper than 9322' MD. 4. RU slickline unit. RIH and confirm cement top at least 100' above top perforations. Note' Tag to be witnessed by AOGCC representative. ; 5. RU E-line and make a tubing cut at +/-8500' MD baSed on completion tubing tally. 6. Circulate well over to seawater and freeze protect well to 2000'. 6. Bleed tubing, inner annulus, and outer annulus to 0 psi. 7. Set 5-1/2" BPV and prepare Pad for RWO. 8. MIRU rig. Pull BPV. Circulate out freeze protection. 9. RIH with a 9-5/8" bridge plug and set at 8490' MD. weight. 10. Pull 5-1/2" tubing. Test w/15,000#'s of pipe Spot 200' of cement on top of the bddge plug (8290'- 8490' MD). Note: Steps #9 and 10 are a variance of.state regulation 20 ACC 25.105(h)(2) on the placement of a liner top cement. Although the liner top plug is higher above the liner top than as specified in the regulations, an bridge plug, a weight test of the bridge plug, and 200' of cement on top of the bridge plug set 600' above the 7" liner top is believed to be a competent plugback. REC[IV[D BP EXPLORATION ENGINEERING DATA SU BJ ECT . BASED ON ENGINEER BUDGET/AFE NO. DEPT. APP'VL DATE 2.--tl-Cl'Z.- , FILE NO. SHEET NO. OF AK 2337-t (6/86) b~3-34A Summary Procedure Procedure Outline; o , o 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 5-1/2" tubing at 8500' MD. Freeze protect. MIRU workover rig. Pull 5-1/2" BPV. Circulate diesel from well. Set two-way check valve. ND tree. NU & test BOP's to 5000 psi. PU on 5-1/2" tubing. Pull and lay down tubing. RIH w/9-5/8" EZSV and set at 8490' MD. Lay cement plug from 8290'- 8490' MD. Test 9-5/8" packoff to 3000 psi and replace if necessary. RIH with section mill and cut 80' window in the 9-5/8" casing from 8010'-8090' MD. Set a cement plug from 7710'-8190' MD. RIH w/steerable system and kickoff through the section. POOH. RIH with 8-1/2" packed assembly and drill to TD (+ 10022' MD). Run open hole logs. Run and cement 7" 13 CR liner in the 8-1/2" hole w/+/- 250' of lap. Clean out liner to PBTD and test to 3000 psi. Displace well to seawater w/ corrosion inhibitor. RIH w/7" packer and set at +/- 9350' MD. RIH with 3-1/2" x 4-1/2" 13CR completion stdng w/7" packer. Space out, land completion, set packer. Test down tubing to 4000 psi. Set two-way check valve. ND BOP's. NU and test new 5-1/8" 5M chrome tree to 5000 psi with diesel. Pull two way check valve. Set BPV. Release rig. Perforate well. Anticipated BHP: 7.9 ppg equivalent. Drilling Fluid' 9.5-9.7 ppg, Workover Fluid' 8.4 ppg. PROPOSED..__~{ILLING AND COMPLETION--_,~IOGRAM WELL 3-34A [14-10-15] OBJECTIVE: A redrill is requested to replace the existing 3-34 wellbore that is shut-in due to a high watercut. Due to numerous mechancal problems on the current wellbore combined with a more desirable target away from a fault, a sidetrack redrill is desired. The objectives of the 3-34A redrill are to plug and abandon the original perforations, pull the 5-1/2" 17# L-80 PC tubing, section mill a 80' window in the 9-5/8" casing, lay a cement plug across the section, kickoff and drill a new 8-1/2" hole to a target 750' southeast from the original wellbore, run open hole logs, run and cement a 7" 29# 13CR liner, recomplete with 3-1/2" 9.2# x 4-1/2" 12.6# 13CR tubing, and perforate the pay zorle. CURRENT STATUS: Well 3-34 is currently shut-in due to confirmed corrosion and tubing leaks @ 6905' and 8966' MD ELM. High watercuts (over 80%) have plagued this well since 1989. The watercuts have been blamed primarily on faulting in close proximity of the current wellbore. A fault has been mapped paralleling the current wellbore providing communication to underlying water zones. Additionally, the lower perforations are covered with fill and a fish (1-1/2" GLV and latch). The 3-34 was drilled in 1984 with the Rowan 35 rig. The current wellbore has 13-3/8" surface casing set at 2501' MD / TVD, 9-5/8" production casing set at the top of the Sadlerochit at 9324' MD / 8721' TVD, and a 7" production liner at total depth of 9860' MD / 9232' TVD. The well was completed with a 9-5/8" packer and 5-1/2" tubing. PROPOSED PLUGBACK PROGRAM: (Operation to be Approved Under Sundry Notice) Rig up coiled tubing unit. Lay a cement plug from the bottom of fill at 9581' MD to at least 100' above the upper perforation (upper perforation @ 9422' MD -- cement top to be no deeper than 9322' MD). RU slickline unit. RIH and confirm cement top. RIH with jet cutter and cut 5-1/2" tubing at 8500' MD. Circulate well over to seawater and freeze protect well to 2000'. Set 5-1/2" BPV. When the rig moves on location, the tubing will be pulled from 8500' MD. A 9-5/8" bridge plug will be run and set and weight tested @ 8490' MD. A 200' cement plug will be laid on top of the bridge plug leaving the top of the cement @ 8290' MD. R'ECEIVED FEB 18 1992 Alaska Oil & Gas Cons. Commission Anchora[fe PRO,POSED~L-~..~ILLING AND COMPLETION ~OqiRAM WELL 3-34A .... [14-10-15] PROPOSED DRILLING PROGRAM: (Operations to be Approved Under Drilling Permit) The milling/drilling fluid program will consist of a 9.5 - 9.8 ppg water based mud in the 8- 1/2" hole. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. The plan consists of pulling the 5-1/2" tubing and milling an 80' section in the 9-5/8" casing from 8010' - 8090'. A cement kick-off plug will be set in the 9-5/8" casing across the window area from 7710'- 8190'. An 8-1/2" hole will be directionally drilled to a new target +/- 750' southeast of the present well. A 7" chrome liner will be run from TD to 250' inside the 9-5/8" casing kickoff point and cemented with Class G cement. The liner will be cleaned out to the 7" landing collar. The mud will be changed over to filtered and inhibited seawater completion fluid. The 9-5/8" casing, 7" liner and lap will be tested to 3000 psi A 3-1/2" x 4-1/2" 13CR tubing completion will be run with the production packer in the 7" liner. A subsurface safety valve with dual control lines will be located about 100' below the base of permafrost. The well will be freeze protected with diesel. The production packer will be set and tested. A production tree will be installed and tested. The well will be perforated through tubing after the rig leaves. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. RECEIVED Anchorage PRELIMINARY WELL PLAN APl No.: LOCAT,,JO,,N: 3-34A [14-10-15] PBU 50-029-21132-00 Surface: 97' FSL, 846' FEL, Sec. 11, T10N, R15E Target: 2750' FNL, 500' FEL, Sec. 14, T10N, R15E @ 8815' ss TVD BHL: 2932' FNL, 676' FEL, Sec. 14, T10N, R15E @ 9108' ss TVD ESTIMATED START: 5 March, 1992 (::;)PR,. DAY.$ TO COMPLETE: 15 (5 days prep & mill, 5 days drill, 5 days complete) CONTRACTOR: Nabors rig 2ES MAX ANGLE / SE(~TIQN. COURSE/ KOP / DOGLEG: 41° / S44.09°E / 8010' / 2.5°-100' WELLBORE: Item . .TVDss ~ Mud Wt. 20" CONDUCTOR 110' 110' N/A 13-3/8" SHOE 2439' 2501' N/A KOP 7436' 8010' 9.5 TOP SAG RIVER SANDSTONE 8707' 9490' 9.8 TOP SADLEROCHIT 8815' 9634' 9.8 TARGET 8815' 9634' 9.8 HOT 8995' 9872' 9.8 TOTAL DEPTH 9108' 10022' 9.8 LOGGING PROGRAM: Open Hole - Record all logs on magnetic tape where applicable. 8-1/2" Hole: Resisitivity / Gamma Ray / SP / Sonic / Neutron MUD WEIGHT CALCULATIONS; Mud Wt. (8-1/2" Hole): 9.8 ppg. Pore Press. Sag River: Pore Press. Sadlerochit: 4075 psi. 3456 psi. OB Sag River: OB Top Sadlerochit: 362 psi. 1036 psi. Top Sag River Top Sadlerochit Current HOT: 8707' TVD ss 8815' TVD ss 8995' TVD ss LINER DETAILS: CASING 7" 29# 13CR-80 FOX DEPTH 775o'-1o022' MD (7266'-9170' TVD) BURST 8160 psi COLLAPSE 7030 psi · TENSILE 676 klbs CEMENT CALCULATIONS: 7" LINER: Measured Depth: Basis: Total Cement Vol: 7750' (Hanger)- 10022' (Shoe) 1.35 X Ann. vol. (10022' to 8010') + 150 cuft for lap & excess 405 cuft or 349 sxs of Class G blend @ 1.16 Cu ft/Sk TUBING DETAILS: 3-1/2" 9.2# 13CR-80 Fox (7700' - 9400') 4-1/2" 12.6# 13CR-80 Fox (0'- 7700') 3-34A MUD PROGRAM DEPTH DENSITY PV YP INT 10 MIN FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) TYPE 8010' 9.5 10 10 5 7 8 0 5 Water to to to to to to to to to Base 10022' 9.8 16 15 10 15 5 0 7 Mud NABORS RIG NO. 2ES MUD SOLIDS CONTROL EQUIPMENT,, 2 - Continental Emsco Fl000 Mud Pumps 1 - Derrick FIoLine Cle~-~ner Shale Shaker 1 - Mud Cleaner 1 - DRECOGas Buster 1 - Pioneer Sidewinder Mud Hopper 1 - 5 HP Flash Mixer Agitator. 3 - Abcor 10 H P Agitators 1 - 50 bbl. Trip Tank 1 - Recording frilling fluid pit level indicator with both visual and audio warning devices at driller's console. 1 - Drilling fluid flow sensor with readout at driller's console RECEIVED Alaska Oil & Gas Cons. Gorem~'ss~°~ Lcit. 7'0°!3' 49.:54~: Y §, 936, 820.13 Long. 148° 16' 41.390 X 713,298.~2 ~ WELL NO. 28 EL. 28.28 .~ Long. 148°16' 40.664" X 713,326.61 .~ ~ ~ 13° 39' 49" WELL ~. 29 EL. 28.30 - Lot. 7~ 13' 47.035" Y 5, 936, 586.87 ~ ~ Long. 148016'39.937" X 71~,354.96 m~ ~ WE~ No. 30 EL. 28.29 Lot. 70° 13' 45.881" Y 5,936,470.32 ~J L°ng' 148°16' 39'2~" X 713' '83'53 ~ WE~ No. 31 EL. 27.20 Lat, 7~ 13' 46.095" Y 5~ 956~ 511.24 Long, 148016' 19,589" X 714~057.70 21,/~ell 27 ,WELL No. 32 EL. 27.65 L~t. 70° 13' 44.94[" Y 5~ 936,394.63 Long. 148°16' 18.863" X 714,086.01 --'~ ~ [ Gyro WELL No. 33 - :L. 27.89 ~ . .731' ~ ~ Lat. 70°13',43,785',', Y 5, 936,277.89 71'~J / j ell~ _ Long. 148°i6 18.136 X 714,114.38 Well 31 Lot. 70015' 4Z.63~" Y 5,936,161.37 771' - ~ ~g. 1~16'17.411 X 714,142.6Z Gyro _j 9 I 82t' Well 33 WE~ GYhO ' L~. 148° 16" ~8.846" X 713,40Z.TZ Well 34 -~ ' I0 // .. ~ I .. Lon~ 148°16 20.756 X 714,012.22 . 15 14 Pr~oct~ S~f/on Line . NOTES ~ Loren H. Lounsbu~ F~:B 1 .. I. Elevations or~ ARCO cloture ~.L.L.W. .. .87:-S ,; 0ii & BaS ~0~S. 2. ~11 distances ore ~rid. ,.,.._~...~ ~ ~t ..... ..~ LHD . ~c~ , ~~ I I I AR CO Alaska 1 nC. ~ ~:CTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT 'H'.S :LAT REPRESENTS A LOCATION SURVET MADE BY ME OR UNDER ASBUILT ~'~ Sd:ERvISION AHD ALL DIMENSIONS AND OTHER DETAILS A~ // . / DRILL SITE No. 3 ',~,, ..."~ Wells 2~ 28~ 22~ ~ 31, 32, 33, 34 ;~'~ ~' "S~r,~or ~ LOCATED IN PROTRACTED SECTION I1~ TION~ R 15 E; U.M. "O~TE: 4-24-84 ~ SCALE: I,".: ~00' CK'O: LMH ~,~D.,BK- GREAT LAND DIRECTIONAL DRILLING, INC. Corporate Office 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING Well ......... : DS 3-34A Field ........ : PRUDHOE BAY DRILL SITE 3 Computation..: MINIMUM CURVATURE KB elevation.: LOCATIONS LEGAL DESCRIPTION X ASP ZONE 4 Y Surface ...... : 97 FSL 846 FWL Sll T10N R15E UM 714142.62 5936161.37 Tie-in ....... : 2012 FNL 206 FWL S14 T10N R15E UM 713566.23 5934036.10 Target ....... : 2750 FNL 500 FWL S14 T10N R15E UM 713881.72 5933305.54 BHL .......... : 2932 FNL 676 FWL S14 T10N R15E UM 714063.24 5933128.25 Prepared ..... : 02/12/92 Section at...: S,44.09,E 62.00 ft PROPOSED WELL PROFILE STATION IDENTIFICATION TIE-IN END TURN & BUILD TARGET 8995 SS TD MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES DL/ BEARING FROM-WELLHEAD 100 8010 25.72 7498 7436 1072 S 21.34 W 2109 S 8100 25.50 7580 7518 1090 S 16.16 W 2146 S 8200 25.47 7670 7608 1113 S 10.34 W 2188 S 8300 25.67 7760 7698 1140 S 4.57 W 2231 S 8400 26.10 7850 7788 1170 S 1.08 E 2274 S 8500 26.74 7940 7878 1204 S 6.51 E 2319 S 8600 27.57 8029 7967 1242 S 11.68 E 2364 S 8700 28.58 8117 8055 1282 S 16.53 E 2409 S 8800 29.76 8204 8142 1326 S 21.06 E 2455 S 8900 31.08 8290 8228 1374 S 25.26 E 2502 S 9000 32.52 8375 8313 1424 $ 29.13 E 2549 S 9100 34.08 8459 8397 1477 S 32.70 E 2596 S 9200 35.73 8541 8479 1534 S 35.98 E 2643 S 9300 37.46 8621 8559 1593 S 39.01 E 2690 S 9400 39.26 8700 8638 1655 S 41.80 E 2737 S 9488 40.90 8767 8705 1712 S 44.09 E 2779 S 9634 40.90 8877 8815 1807 S 44.09 E 2847 S 9872 40.90 9057 8995 1963 S 44.09 E 2959 S 10022 40.90 9170 9108 2061 S 44.09 E 3030 S 636 W <TIE 649 W 2.5 659 W 2.5 664 W 2.5 666 W 2.5 663 W 2.5 656 W 2.5 644 W 2.5 628 W 2.5 608 W 2.5 584 W 2.5 556 W 2.5 524 W 2.5 487 W 2.5 447 W 2.5 408 W 2.5 342 W 0.0 234 W 0.0 165 W 0.0 P~DHOE BAY DRILLING Al ?IE-IN 8010 ,tog 9 6~8 W A 81 END TURN g eUZLO 9488 ,779 S 408 W DI BS 3-34A PLAN VTEW CLOSURE ..... : 3034 f~ aG S DECLINATION.: 30.32 E SCALE ....... : ! inch = 500 DRAWN ....... : 02/t2/98 SPear Land Dinectional Drillin# ~7§0 t500 t250 tO00 750 500 250 0 ,50 500 750 1000 t850 1500 t750 <- WEST: EAST-> p~o~ BA-Y OR IL~ Harker Identification ND BKB SERTN ]N6LN A) TIE-IN B0t0 7498 i072 25.72 B) ENO TURN ~ BUILD 9488 8787 t7i8 40.90 C) TARGET 9634 8877 i807 40.90 0) 8995 86 9872 9057 i963 40.90 E) 78 10022 9t70 20Oi 40.90 DS 3-34A VERTICAL SECTION VIEW Section at: S 44.09 E TVD Scale.: t ~nch = 300 feet Deo Scale.: t inch = BO0 feet Drawn ..... : 02/I2/92 G~eat Land Directional Drilling <OP BUILD ~; TUBN 2.5/t00 DDBLEB 40.80 OEGREE$ 2400 2550 2700 2850 3000 900 t050 t200 t350 t500 i650 t800 i950 2t00 2250 Section Departure Spud Date: 7-13-84 Original RKBE: 62" top of Sadlerochit: 9422' Maximum Hole Angle: 28~ Angle Through Sad.' Annulus Ruid:, Diesel/9.0~ Na(~l Reference Log: BHCS 7-24-84 All Depths are RKB Drilling MD to_.Top of Equipment except where noted. 4 Alaska Inc. - Prudhoe Bay ~ E]-029-21132-00 Well Type: Producer Completion Date: 2-26-86 New I~ Workover r-1 Hanger Type: McEvoy Gen III Hanger: 29' 15~ 2 Tubing Leaks. Jewel~ 5-1/2' Otll R~M SSSV Nipple ID=4.562" BOT PBR Assembly BOT 3H Packer Crossover 5-1/2" x 4-1/2" Otis XN Nipple ID-3.725" BOT Shear Out Sub Tubing Tall 4-1/2" ELM Tubing Tail: 4-10-86 Fish 1.5" GL Valve & Latch Lost 3-T7-88 1 2214' 2* 8995' 3 9015' 4 9025' 5 911Z 6 9123' 7 9124' 7 ~7/7' 8 · ' Ran 4-1/2' 'PXN' tubing plug for LDL 11/20/91 12 9 10 11 To. aoftom 13-3/8" 72~ L-80 0 2~1' C~ing 9-5/8' 47~ L~ 0 93~' C~ing 7" ~e L~ ~' 9~ ~ner 5-1 / 2' 17e L~ 0 ~ ~ Tubi~ 4-1/2' 12.~ L-~ ~ 91~' PC.Tubing Tail 5 10 12 G~ Uti Infom~tlen (Valve ~ I~lte: 10-30-91] 2984' (2982') 1 CA-MMIC MC VR-STD R K 4363' (4258") 2 CA-MMIG MC VI~-STD R K 5770' (5513")3 CA-MMIC MC VI~-STD R K 6820' (6442) 4 CA-MMIC C,A RD RK ~ (6638") 5 CA-MMIC MC VI~-STD R K 7941' (7436") 6 CA-MMIC TE D-14R R K 8052" (7536~ 7 CA-MMIC TE 02-20R R K 6817' (8238") 8 CA-MMIC CA RD R K 8929' (8343") 9 CA-MMIC CA RKED RKP 1/4' 1721 1/4' 17133 1/4' 1692 3/8' 1813 10-(72-91 7/16" ORIF 10-30-91 13 Peroration Data (ELM 9422~ 4 128 4 9576-q594 4 18 4 FRAC 12-11~9 Comments · LeaklOGLM #$ and pup Jolnt above PBg. (11-24-91) 8 11 PBTD - 9823' TD = 9860' D~ 8700' SS = 9367' MD 8800* SS = 9470' MD Revl~on Dale: 11-28-91 by ENH Reason: ANN COMM/PXN PLUG Previous Revision: 11-03-91 We, 3-34 RECEIVED FEB 1 8 1992 ,Alaska 0il & 6as Cons. Comm~ssio~ Anchorage ARCO ALASKA INC. PRUDHOE BAY DIRECTIONAL SURVEY REPORT 18:4q TUESDAY, MARCH 29, 1988 1972 WELL DESCR I PT I ON: I SURVEY OESCR I PT I ON: , I FRAGMENT #1 FRAGMENT #2 FRAGMENT #3 AP I # 50-029-21132-00 I SURVEY m O. 0 WELL NAME 03-34 I COMPANY NL SPERRY SUN OPERATOR ARCO ALASKA I NC I I DENT AK-BO-60013 ^ LAT/LONG 70.228.51 N / 148.27150 W I METHOD GYROSCOPIC Y/X COORD ' .5936161.37 / 714142.62 I DATE , 26FEB86 ' ~ ~ SURFACE LOc TION R15E Sll UMIAT I START DEPTH 0.0 KBE 62.00 I STOP DEPTH 9860.0 ~ . ~(~/f~ SECTION FT 97 O0 S 846 O0 W I .................................... · · ~ ~ ~ SPUD DATE 13JULSq I SUBSEA CORRECT IONS' I ZONE '6~ /~0- ' ............................ = ............... I DEPTH . ~ o-Om ~ ' STATUS: PRODUCING OIL I CORRECT I ON 0.00 ............... ... .......................... ..... ...................... ................................................ ' CORRECTED ~ -X- -Y- SUB~EA SUBSEA DELTA DELTA -"' STATE STATE DEPTH I NGL I NE ~ I MUTH TVD TVD TVD -X- -Y- RAD I US PLANE PLANE 0.00 0.000 0.00 0.00 62.00 62.00 0.00 0.00 0.00 714142.62 5936161.37 100.00 0.250 223,50 100.00 -38.00 -38.00 -0.15 -0,16 0,22 714142.#7 5936161.21 200,00 0,220 223.60 200.00 -138.00 -138,00 -0.43 -0.46 0,63 714142.20 5936160.90 300.00 0.230 231.00 300.00 -238.00 -238.00 -0.72 -0.72 1.02 714141.92 5936160.63 400.00 0.450 226.00 ~00.00 -338.00 -338.00 -1.16 -1.12 1.61 714141.#9 5936160.22 500.00 0.770 199.69 499.99 -437.99 -437.99 -1.67 -2.03 2.62 714141.01 5936159.30 600.00 0.650 185.60 599.98 -537.98 -537.98 -1.95 -3.22 3.77 714140.76 5936158.09 700.00 0.500 201.50 699.98 -637.98 -637.98 -2.17 -~.19 q.72 71~1~0.57 5936157.12 800.00 0.600 223.10 799.97 -737.97 -737.97 -2.68 -4.98 5.66 714140.08 5936156.31 900.00 0.650 223.50 899.97 -837.97 -837.97 -3.43 -5.78 6.72 714139.35 5936155.50 1000.00 0.580 245.39 999.96 -937.96 -937.96 -4.28 -6.40 7.70 714138.52 5936154.85 1100.00 0.350 254.00 1099.96 -1037.96 -1037.96 -5.04 -6.69 8.38 71~137.78 5936154.54 1200.00 0.280 275.70 1199.96 .-1137.96 -1137.96 -5.57 -6.75 8.75 714137.2~ 5936154.46 1300.00 0.320 279.81 1299.96 -1237.96 -1237.96 -6.09 -6.68 9.0~ 71~136.72 5936154.52 1~00.00 0.100 298.20 1399.95 -1337.95 -1337.95 -6.4~ -6.59 9.22 714136.37 593615~.60 1500.00 0.200 19.10 1499.95 -1437:95 -1437.95 -6.46 -6.39 9.09 714136.3~ 5936154.80 1600.00 0.250 340.61 1599.95 -1537.95 -1537.95 -6.48 -6.01 8.84 714136.32 5936155.17 1700.00 0.080 311.61 1699.95 -1637.95 -1637.95 -6.60 -5.76 8.76 714136.18 5936155.42 -1800.00 0.320 338.50 1799.95 -1737.95 -1737.95 -6.76 -5.46 8.69 71#136.02 5936155.72 1900.00 .0.'720 56.00 1899.95 -1837.95 -1837.95 -6.34 -~.85 7.98 71~136.42 5936156.35 2000.00 1.350 76.89 1999.93 -1937.93 -1937.93 -4.67 -4.23 6.30 714138.07 5936157.01 2100.00 1.120 56.80 2099.91 -2037.'91 -2037.91 -2.71 -3.42 4.36 714140.01 5936157.87 2200.00 0.920 42.60 2199.89 -2137.89 -2137.89 -1.34 -2.30 2.66 71~141.34 5936159.03 2300.00 0.250 308.40 2299.89 -2237.89 -2237.89 -0.97 -1.57 1.85 7141~1.69 5936159.77 2#00.00 0.130 309.20 2399.89 -2337.69 -2337.89 -1.23 -1.36 1.84 7141~1.#3 5936159.97 2500.00 0.250 115.50 2~99.89 -2437.89 -2437.89 -1.12 -1.39 1.78 714141.54 5936159.95 2600.00 ,1.020 164.50 2599.88 -2537.88 -2537.88 -0.69 -2.3~ 2.h~ 71~142.00 5936159.01 2700.00 4.800 173.70 2699.7~ -2637.74 -2637.74 0.01 -7.36 7.36 714142.8~ 593615~.02 2759.00 5.000 170.00 2758.52 -2696.52 -2696.52 0.73 -12.3~ 12.36 714143.70 59361#9.05 2800.00 5.850 175.00 2799.34 -2737.34 -2737.3q 1.22 -16.18 16.23 714144.30 5936145.23 2881.00 6.500 181.00 2879.87 -2817.87 -2817.87 1.50 -24.88 24.92 71q144.83 5936136.54 2900.00 7.330 180.50 2898.73 -2836.73 -2836.73 1.47 -27.17 . 27.21 7141~4.86 5936134.26 ' · DEPTH I NCL I NE AZ I MUTI:/' TVD ARCO ALASKA INC. PRUDHOE BAY DIRECTIONAL SURVEY REPORT 18:q~ TUESDAY, MARCH 29, 1988 1973 CORRECTED -X- -Y- SUBSEA SUBSEA DELTA DELTA STATE STATE TVD TVD -X- -Y- RADIUS PLANE PLANE 3000.00 9.000 183.39 3003.00 8.750 183.00 3100,I~0 10.780 183.60 3157.00 11.500 188.00 3200.00 15.180 186.00 328T~00 16.500 184.00 3300.00 18.180 183.10 3371.00 19.000 185.00 3400.00 20.170 184.80 3#65.00 21.500 106.00 3500.00 22.050 186.10 3557.00 22.750 187.00 3600.00 23.770 186.30 36~7.00 2#.250 188.00 3700.00 25.000 187.89 3800.00 2#.800 189.89 3900.00. 25.250 189.60 #000.00 25.750 190.10 #100.00 .25.700 190.30 #139.00 25.750 191.00 ~200.00 25.880 190.80 ~300.00 26.200 190.60 4400.00 26.730 191.30 #500.00 26.620 191.69 4600.00 26.730 191.60 4636.00 26.750 191.00 4700.00 27.050 192.80 4800.00 26.850 193.80 4900.00 27.000 194.69 5000.00 26.970 195.30 5072.00 27.250 196.00 5100.00 25.680 196.30 5200.00 27.020 197.80 5300.00 26.700 197.50 5400.00 27.630 197.80 5500.00 26.670 199.00 5600.00 26.970 200.50 5631.00 27.000 200.00 5700.00 27.250 201.39 5800.00 27.520 202.00 5900.00 27.400 202.60 6000.00 27.280 203.19 6067.00 27.500 202.00 6100.00 27.570 204.00 6200.00 27.750 203.89 6300.00 28.020 203.89 6400.00 28.270 203.69 6500.00 28.130 203.30 6594.00 28.000 204.00 6600.00 28.220 203.30 2997.71 -2935.71 -2935.71 0.95 -41.36 41.37 714144.75 5936120.06 3000.68 -2938.68 -2938.68 0.93 -41.82 41.83 714144.73 5936119.60 3096.27 -3034.27 -3034.27 -0.03 -58.24 58.24 714144.2~ 5936103.15 3152.19 -3090.19 -3090.19 -1.15 -69.19 69.20 714143.43 5936092.18 3194.03 -3132.03 -3132.03 -2.34 -79.03 79.07 714142.52 5936082.30 3271.95 -3209.95 -3209.95 -4.25 -101.06 101.15 714141.24 5936060.23 3290.08 -3228.08 -3228.08 -4.60 -106.71 106.81 714141.05 593605~.57 3357.38 -3295.38 -3295.38 -6.21 -129.28 129.43 714140.09 5936031.96 3384.70 -3322.70 -3322.70 -7.0~ -138.97 139.15 714139.53 5936022.26 3~#3,58 -3381.58 -3381.58 -9.15 -161.27 161.53 714138.05 5935999.90 3477.94 -3~15.94 -3415,94 -10.60 -174.92 175.2~ 71~136.99 5935986.22 3530.64 -3468.64 -3468.64 -13.08 -196.50 196.9~ 714135.12 5935964.58 3570.14 -3508.14 -3508.1B ' -15.0~ -213.37 213.90 714133.6~ 5935947.66 3613.08 -3551.08 -3551.08 -17.43 -232.3~ 232.99 714131.80 5935928.63 3661.26 -3599.26 -3599,26 -20.48 -254.21 255.04 714129.37 5935906.68 3751.96 -3689.96 -3689.96 -26.98 -295.81 297.03 714124.05 593586~.92 3842.58 -3780.58 -3780.58 -34.14 -337.50 339.22 714118.07 5935823.0~ 3932.83 -3870.83 -3870.83 -41.51 -379.91 382.17 714111.91 5935780.#3 #022.92 -3960.92 -3960.92 -49.19 -422.63 ~25.48 714105.44 5935737.51 4058.06 -3996.06 -3996.06 -52.32 -439.27 ~42;37 714102.79 5935720.79 4112.97 -4050.97 -4050.97 -57,34 -~65.35 468.87 714098.51 593569#.58 ~202.82 -4140.82 -4140.82 -65.49 -508.49 512.69 71~091.59 5935651.23 #292.34 -4230.34 -4230.34 -73.96 -552.24 557.17 714084.36 5935607.25 4381.70 -4319.70 -4319.70 -82.91 ' -596.23 601.97 71~076.67 5935563.02 4471.05 -4409.05 -4409.05 -91.97 -640.20 646.77 714068.86 5935518.82 4503.20 -4441.20 -4441.20 -95.14 -656.09 662.95 71~066.1~ 5935502.85 4560.28 -4498.28 -4498.28 -101.12 -684.42 691.84 714060.97 5935474.36 4649.42 -4587.42 -4587.42 -111.54 -728.52 737.01 714051.81 5935429.98 4738.58 -4676.58 -4676.58 -122.68 -772.41 782.09 714041.91 5935385.79 4827.69 -#765.69 -4765.69 -134.42 -816.24 827.23 71#031.42 59353~1.6# 4891.78 -~829.78 -4829.78 -143.27 -847.83 859.85 714023.47 5935309.81 4916.85 -4854.85 -4854.85 -146.74 -859.82 872.25 714020.3~ 5935297.73 5006.46 -4944.46 -4944.46 -159.77 -902.24 916.28 714008.53 593525#.95 5095.67 -5033.67 -5033.67 -173.47 -945.30 961.08 713996.05 5935211.53 5184.6~ -5122.64 -5122.64 -187.31 -988.80 1006.39 713983.~5 5935167.65 5273.62 -5211.62 -5211.62 -201.71 -1032.10 1051.63 713970.29 5935123.96 5362.86 -5300.86 -5300.86 -216.96 -107~.56 1096.25 713956.25 5935081.O8 5390.49 -5328.49 -5328.49 -221.83 -1087.76 1110.15 713951.76 5935067.75 5~51.90 -5389.90 -5389.90 -232.95 -1117.19 1141.21 7139~1.48 5935038.02 5540.69 -5478.69 -5478.69 -249.95 -1159.92 1186.55 713925.70 5934994.82 5629.42 -5567.42 -5567.42 -267.45 -1202.59 1231.97 713909.42 5934951.67 5718.25 -5656.25 -5656.25 -285.31 -124~.90 1277.17 713892.76 593~908.88 5777.74 -5715.74 -5715.74 -297.15 -1273.35 1307.57 713681.73 5934880.09 5807.01 -5745.01 -5745.01 -303.12 -1287.39 1322.60 713876.17 5934865.89 5895.58 -5833.58 -5833.58 -321.96 -1329.82 1368.24 713858.54 5934822.95 5983,97 -5921,97 -5921,97 -340,90 -1372,58 1414.28 713840,82 5934779.66 6072.14 -6010.14 -6010.14 -359.92 -1415.75 1460.78 713823.03 5934735.98 6160.27 -6098.27 -6098.27 -378.76 -1459.08 1507.44 713805.~3 5934692.12 6243.22 -6181.22 -6181.22 -396.50 -1499.59 1551.13 713788.84 5934651.13 6248.51 -6186.51 -6186.51 -397.64 -1502.18 1553.92 713787.78 5934648.51 DEPTH INCLINE AZIMUTH TVD 6700.00 28.130 202.69 6336.66 6800.00 28.430 203.00 6~2h.73 6900.00 28.~30 202.39 6512.67 7000.00 28.420 202.30 6600.61 7100.00 28,270 202.50 6688.62 7200.00 28.270 201.50 6776.70 7211.00 28.250 202.00 6786.38 7300.00 27.770 200.69 686#,96 7#00.00 27.~00 200.39 6953.59 7500.00 26.870 200.50 70#2.59 7538.00 27,500 201,00 7076.$9 7600.00 27.120 200.10 7131.#8 7700.00 26.750 200.60 7220.63 7800.00 26.570 200.30 7310,00 7900.00 26.370 200.50 7399.51 8000.00 25.770 201.30 7~89.3~ 8100.00 25.250 201.69 7579.59 8106.00 25.750 202.00 7585.01 8200.00 2~.680 202.19 7670.05 8300.00 2#.170 202.89 7761.10 8~00.00 23.520 20~.19 7852.56 8500.00 23.130 204.89 79~.39 8600.00 22.770 205.10 8036.h7 8700.00 21.570 206.80 8129.08 8800.00 20.800 207.39 8222.32 8900.00 ,9.570 209.89 8316.18 9000.00 ~q.550 210.80 8~10.70 9100.00 17.100 213.39 8~05.90 9200.00 16.230 216.30 8601.70 9300.00 15.050 218.50 8697.99 9336.00 16.000 '218.00 8732.68 9h00.00 15.1'30 218.10 879~.33 9500.00 16.020 216.39 8890.66 9600.00 16.600 21h.89 8986.63 9700.00 18.820 213.60 9081.89 9750,00 20.520 212.60 9128.97 9800.00 '20,520 212.60 9175.80 9860.00 20.520 212.60 9231.99 oi/ / 8 7992 ARCO ALASKA INC. PRUDHOE BAY DIRECTIONAL SURVEY REPORT CORRECTED SUBSEA SUBSEA DELTA TVD TVD -X- DELTA -y- -6274.66 -627h.66 -h16.08 -6362.73 -6362.73 -434.48 -6450.67 -6h50.67 -~52.85 -6538.61 -6538.61 -#70.94 -6626.62 -6626.62 -h89.03 -6714.70 -6714.70 -506.78 -6724.38 -6724.38 -508.71 -6802.96 -6802.96 -523.92 -6891.59 -6891.59 -5~0.17 -6980.59 -6980.59 -556.10 -7014.39 -7014.39 -562.25 -7069.h8 -7069.h8 -572.2~ -7158.63 -7158.63 -587.99 -72h8.00 -72~8.00 -603.67 -7337.51 -7337.51 -619.20 -7h27.34 -7427.34 -634.88 -7517.59 -7517.59 -650.66 -7523.01 -7523.01 -651.62 -7608.05 -7608.05 -666.68 -7699.10 -7699.10 -682.53 -7790.56 -7790.56 -698.67 -7882.39 -7882.39 -715.11 -797h.h7 -797h.~7 -731.59 -8067.08 -8067.08 -748.08 -8160.32 -8160.32 -76h.5~ -8254.18 -8254.18 -781.06 -83h8.70 -83h8.70 -797.55 -8hh3.90 -84#3.90 -813.78 -8539.70 -8539.70 -830.15 -8635.99 -8635.99 -8#6.50 -8670.68 -86?0.68 -8?32.33 -8?32.33 -863.05 -8828.66 -8828.66 -879.29 -892~.63 -892~.63 -895.65 -9019.89 -9019.89 -912.75 -9066.97 -9066.97 -921.93 -9113.80 -9113.80 -931.38 -9169.99 -9169.99 -942.71 -15h5.65 -1589.31 -1633.23 -1677.26 -1721.15 -1765.06 -1769.90 -1808.83 -1852.19 -1894.93 -1911.16 -1937.79 -1980.27 -2022.31 -206h.08 -2105.14 -21h5.21 -21h7.61 -2184.71 -2222.90 -2259.97 -2295.99 -2331.33 -2365.26 -2397.h3 -2~27.72 -2#55.90 -2481.84 -2505.38 -2526.81 -253#.37 -25#7.9O -2569.28 -2592.10 -2617.26 -2631.36 -26~6.12 -2663.84 18:hq TUESDAY, MARCH 29, 1988 197~ RADIUS -X- -Y- STATE STATE PLANE PLANE 1600.67 713770.58 593460h.53 1647.63 713753.43 593h560.37 1694.85 713736.32 593~515.94 1742.12 713719.q8 5934~71.42 1789.28 713702.6~ 593b427.03 1836.38 713686.15 5934382.63 1841.56 713684.36 5934377.7~ 1883.18 713670.26 593~338.#~ 1929.35 713655.25 593#29~ 5 1974.84 713640.53 ;593#251.#~ 1992.15 713634.85 593~235 02 2020.52 713625.62 593~208.11 2065.72 713611.08 593h165.21 2110.48 713596.60 5934122.7~ 215h.96 713582.26 593~080.54 2198.79 713567.76 593#039.06 2241.71 713553.12 5933998.55 2244.29 713552.23 5933996.13 2284.17 713538.23 5933958.61 2325.33 713523.~7 5933919.99 2365.50 713508.39 5933882.~8 2~0~.77 713492.97 59338#6.01 2hh3.h2 713477.51 5933810.22 2~80.7h 713~61.98 5933775.83 2516.39 713#~6.#~ 59337#3.20 2550.27 713~30.79 5933712.~6 2582.16 713~15.11 5933683.82 2611.86 713399.62 5933657.43 2639.33 713383.93 5933633.43 266~.83 713368.18 5933611.55 2673.90 713362.4~ 5933603.82 2690.10 71~352.2~ 5933590.0~ 2715.57 713336.62 5933568.1 27h2.h8 713320.91 59335k~.89 2771.85 71330~.53 5933519.26 2788.19 713295.75 593350h.90 2805.25 713286.73 5933~89.87 2825.73 713275.91 5933471.84 '' 500.0 P$...I B.b'P STACK I I I I ii i I ANNULAR PREVENTER 7 ACCUMULATOR CAPACIT'Y TEST 1. CHECK AND FILL ACCU~TOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 30<:X:) PSI WITH 1500 PSI DOWNSTREAM OF THE RE(3ULATOR. 3, OBSERVE TIME, THEN CLOSE ,ALL UNITS SIMULTANEOUSLY AND RECORD THE TIIVE AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUIV~ OFF, 4. RECORD ON THE [ADC REPORT. THE ACCEPTABLE LOWER LIMIT I$ 45 SECONDS CLOSING TIIVI~ AND 1200 PSI REMAININ(3 PRESSURE. BLIND RAMS 5 DRILLINO! SPOOL 4 TUBING HEAD 2 _ i ii ii _ I i 1.13.&/8' CASING HEAD 2. 5000 PS1 TUBING HEAD 3.13-5/8' . 5000 PSI PIPE RAW 4. $O00 PSI DRILLING SPOOL 5. 13-,M~' . 5000 PSI BLIND ~ 6. 1 3-5/~' . 5CX:)0 PSI PIPE RAm 7.13-5~8' . 5000 PSI AN~ BOP STACK TES'[ 1. FILL BOP STACK AND MANIF~ WITH ARCTIC DIESEL IN WINTER OR SEAWATER DURING SUMMER MONTHS. 2. CHECK TFIAT ALL H(:X.D-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4, TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5, INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLE~D TO 71:::RO PSI. ~. OPEN ,M,~ULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7, INCREASE. PRE~E TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTR~ OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WrTH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI [:X3WNST~E. AM. BLEED SYSTEM TO ZERO PSI. g. OPEN PIPE [~. Et~CKOFF RUNI~ING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD ANO LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION, 11, TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY ~K8 AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP 13, RECORD TEST INFORMATION ON BI. OWOUT PREVENTER TEST FORM. $.G,~ AND SEND TO DRILUNG SUPF. RVISOFL ! 4, PEI::t~-ORM COI~3LETE BOP TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY FOR DRILLING OPERATIONS. FOR COMPLETIC,% W~OVER OPEP~ONg, PERFORM COMPLETE BOP TEST EVERY 2 ! DAM 11/20/89 F~!~ ~ ~ '~9~ BOP SCH Alaska OJJ & Gas. CoJ'i$, fSoi-r~issi~).¢', (FOR: ~B 2ES) Anchorage ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE [3 thru 8] [9 thru 13] [10 & 13] [14 thru 22] (5) BOPE ~-~,~.,~/~-/¢ - ~ ~--, [23 thru 28] (6) Other [29 thru 31] (6) Addl e 3. 4. 5. 6. 7. 8. 9, 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Compa n y /Z~ ~, c~, ~ Is permit fee attached .............. ;,. ............................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force .................. ' ................. Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of ebi~=g~e-t~BOPE attached .... Does BOPE have sufficient pressure rating -- test to~'"~O~ .psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. Lease & Well YES NO P_. 3 z ' l°S (_..e .. DS 3-$?',,9 REMARKS geology' DWJj_~ eng ! nee r i' ng' MTM,~ ECS 7'~Y'' BEW .. P~AD5 ~-~l JH~t~.~ rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE '-to /,-o,'/ "-) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN1 77048 J. DAHL B. MENSING / D.S. 3 - 34A 500292113201 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 08-MAY-92 RUN2 RUN3 s, MiCROFIL MED 11 _ I I//. .... 15E ~ ' RECEIVED 846 MAY 11 1992 62.00 6 1.0 0 Alaska 011 & Gas Cons. Commission 2 8.0 0 Anchorage OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 8.500 9.625 8010.0 REMARKS: CIRCULATION STOPPED: 2200 10-APR-92. LOG REFERENCE TO ORIGINAL RKB - 62.0' (DS 3-34). $ **** FILE HEADER **** FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; all runs merged; no case hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 8019.0 BCS 9219.5 DIL 9243.0 2435 9196.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 9941.0 9966.0 9992.0 9943.0 BASELINE DEPTH 8019.0 9208.0 9215.0 9227.5 9232.5 9248.5 9254.0 9262.5 9275.0 9275.5 9282.0 9282.5 9297.0 9297.5 9298.0 9305.0 9305.5 9306.0 9327.0 9327.5 9333.0 9340.5 9341.5 9347.5 9348.5 9349.5 9355.5 9366.0 9367.0 9368.0 9374.5 9379.5 9380.0 9385.0 9389.0 9391.0 9393.5 9401.0 9402.0 9406.5 9413.5 9423.0 9425.0 9425.5 9426.0 9426.5 9429.0 9433.5 9440.0 9441.0 9443.5 9452.5 9465.0 9466.5 9467.0 9469.0 9469.5 9476.5 EQUIVALENT UNSHIFTED DEPTH DT NPHI LL8 ILM 8019.0 8019.0 8019.0 8019.0 9208.0 9215.0 9227.5 9227.5 9232.5 9248.0 9254.0 9254.0 9263.0 9275.0 9275.0 9282.0 9282.5 9298.0 9297.5 9297.5 9298.0 9305.5 9305.5 9305.5 9305.5 9326.5 9328.0 9341.0 9341.0 9347.0 9348.5 9349.0 9355.5 9366.0 9366.0 9366.0 9366.0 9368.0 9374.0 9380.0 9380.0 9385.5 9390.0 9390.0 9394.0 9401.5 9407.0 9413.5 9422.5 9425.5 9425.5 9426.0 9428.5 9433.5 9440.5 9443.0 9453.5 9465.5 9467.0 9469.5 9476.5 9469.5 ILD 8019.0 9298.0 9306.0 9333.0 9355.5 9402.0 9425.5 9441.0 9467.0 9479.0 9480.0 9503.0 9508.0 9509.0 9516.5 9519.0 9519.5 9520.0 9530.5 9532.0 9533.5 9534.0 9535.5 9540.0 9542.5 9543.0 9549.5 9559.5 9560.0 9560.5 9561.0 9566.5 9568.5 9569.0 9569.5 9570.0 9577.0 9578.0 9578.5 9579.0 9584.0 9584.5 9585.0 9587.5 9592.5 9593.5 9601.5 9621.0 9624.0 9625.0 9640.5 9642.0 9651.0 9652.5 9653.5 9664.0 9664.5 9682.0 9686.5 9702.5 9703.5 9715.5 9716.0 9718.0 9719.0 9729.5 9735.5 9736.5 9737.0 9479.5 9509.0 9516.5 9519.0 9532.5 9535.0 9543.0 9560.5 9569.5 9579.5 9585.0 9588.0 9602.5 9624.5 9642.0 9682.0 9716.0 9728.0 9736.0 9504.0 9519.0 9530.5 9535.0 9543.0 9560.5 9567.0 9569.5 9579.5 9585.0 9588.5 9594.0 9642.0 9653.5 9686.5 9716.0 9736.0 9479.0 9509.0 9518.5 9535.0 9543.0 9560.5 9569.5 9579.0 9585.0 9594.0 9621.0 9716.5 9508.5 9550.0 9560.5 9569.0 9578.5 9593.5 9625.0 9651.5 9664.5 9703.5 9717.0 9508.0 9519.5 9540.0 9569.0 9579.0 9594.0 9621.0 9652.5 9664.5 9704.0 9720.0 9736.5 9740.0 9751.0 9751.5 9754.0 9760.5 9765.5 9773.5 9778.5 9780.0 9789.5 9798.5 9812.0 9813.0 9819.0 9821.5 9824.0 9825.0 9836.5 9837.0 9846.5 9850.0 9877.5 9892.5 9893.0 9902.5 9903.0 9909.5 9956.0 9980.0 MERGED DATA SOURCE PBU TOOL CODE GR GR BCS DIL 2435 $ REMARKS: CN WN FN COUN STAT 9751.0 9760.0 9765.5 9774.5 9790.5 9798.5 9814.0 9825.5 9836.5 9892.5 9902.5 9751.0 9811.5 9823.5 9837.0 9902.5 9909.5 9751.5 9780.0 9741.0 9755.0 9779.5 9779.5 9819.5 9850.0 9877.5 9821.5 9846.5 9892.5 9956.5 9980.5 9980.0 RUN NO. PASS NO. MERGE TOP MERGE BASE 1 5 8019.0 9206.0 1 3 9206.0 9941.0 1 3 9219.5 9966.0 1 3 9243.0 9992.0 1 3 9196.0 9943.0 TENS, TEND, & MTEM WERE SPLICED (FILES 5 & 3) AT 9249'. FUCT & NUCT WERE SHIFTED WITH NPHI. SP WAS SHIFTED WITH LLD. TENS, TEND, & MTEM WERE SHIFTED WITH LL8. GAMMA RAY FROM TOP OF LOGGING SUITE INTERVAL TO WINDOW CUT IN ORIGINAL CASING. GR, TENS, TEND, & MTEM DATA GOES UP TO LOGGERS CASING DEPTH (8019'). $ : ARCO ALASKA INCORPORATED : D.S. 3 - 34A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 5 MTEM BCS 68 1 DEG 4 6 ILD DIL 68 1 OHMM 4 7 ILM DIL 68 1 OHMM 4 8 LL8 DIL 68 1 OHMM 4 9 SP DIL 68 1 MV 4 10 NPHI 2435 68 1 PU-S 4 11 FUCT 2435 68 1 CPS 4 12 NUCT 2435 68 1 CPS 4 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 20 789 90 0 4 01 741 76 6 4 01 741 76 6 4 01 741 76 6 4 01 741 76 6 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 * DATA RECORD (TYPE~ 0) 994 BYTES * Total Data Records: 211 Tape File Start Depth = 10014.000000 Tape File End Depth = 8019.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet 48 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 51884 datums Tape Subfile: 2 442 records... Minimum record length: 58 bytes Maximum record length: 994 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 0.2500 VENDOR TOOL CODE START DEPTH GR 9184.0 AC 9219.0 DIFL 9242.0 2435 9190.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : STOP DEPTH 9942.0 9977.0 10005.0 9948.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP GR CN PCM KNUL KNUL AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT BHC-ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): Il-APR-92 FSYS256 REV:G002 VER:2.0 2200 10-APR-92 517 il-APR-92 9978.0 9993.0 8000.0 9990.0 1500.0 TOOL NUMBER 3974 3967 2806 1309 2435 3506 30037 20036 1603 1503 8.500 8010.0 8019.0 XCD/KCL POLYMER 9.70 48.0 9.0 5.8 MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 3 - 34A : PRUDHOE BAY : NORTH SLOPE : ALASKA 173.0 0.457 0.190 0.402 0.000 0.612 0.000 THERMAL SANDSTONE 0.00 7.875 1.5 68.0 173.0 68.0 0.0 68.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 GR AC 68 1 2 AC AC 68 1 3 ACQ AC 68 1 4 CHT AC 68 1 5 TTEN AC 68 1 6 TEMP AC 68 1 7 SPD AC 68 1 8 CILD DIFL 68 1 9 RFOC DIFL 68 1 10 RILD DIFL 68 1 11 RILM DIFL 68 1 12 SP DIFL 68 1 13 CLSN 2435 68 1 14 CN 2435 68 1 15 CNC 2435 68 1 16 CSSN 2435 68 1 GAPI US/F LB LB DEG F/MN MMHO OHMM OHMM OHMM CPS PU-L PU-S cpS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 008 99 5 4 4 61 094 30 1 4 4 34 704 23 6 4 4 27 515 24 6 4 4 04 903 06 0 4 4 06 213 78 0 4 4 53 419 67 0 4 4 84 023 70 1 4 4 52 326 75 5 4 4 98 211 23 1 4 4 83 368 34 1 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 238 Tape File Start Depth = 10014.000000 Tape File End Depth = 9182.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 64 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 56594 datums Tape Subfile: 3 318 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 4 is type: LIS **** FILE HEADER **** FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8000.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9250.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP GR CN PCM KNUL KNUL AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT BHC-ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): il-APR-92 FSYS256 REV:G002 VER:2.0 2200 10-APR-92 645 il-APR-92 9978.0 9993.0 8000.0 9990.0 1500.0 TOOL NUMBER 3974 3967 2806 1309 2435 3506 30037 20036 1603 1503 8.500 8010.0 8019.0 XCD/KCL POLYMER 9.70 48.0 9.0 5.8 173.0 0.457 68.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 0. 190 0.402 0.000 0.612 O.000 173.0 68.0 0.0 68.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: GAMMA RAY FROM TOP OF LOGGING SUITE INTERVAL TO WINDOW CUT IN ORIGINAL CASING. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 3 - 34A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CHT GR 68 3 TTEN GR 68 4 TEMP GR 68 5 SPD GR 68 1 GAPI 4 1 LB 4 1 LB 4 1 DEG 4 1 F/MN 4 4 21 990 60 6 4 10 579 41 1 4 10 579 41 1 4 45 987 88 5 4 76 115 41 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 120 Tape File Start Depth = 9250.000000 Tape File End Depth = 7994.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 20 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 82035 datums Tape Subfile: 4 198 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS **** FILE HEADER **** FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 4 0.2500 VENDOR TOOL CODE START DEPTH GR 9223.0 AC 9258.0 DIFL 9280.0 2435 9228.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9938.0 9974.0 10002.0 9945.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP GR CN PCM KNUL KNUL AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT BHC-ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) il-APR-92 FSYS256 REV:G002 VER:2.0 2200 10-APR-92 559 il-APR-92 9978.0 9993.0 8000.0 9990.0 1500.0 TOOL NUMBER 3974 3967 2806 1309 2435 3506 30037 20036 1603 1503 8.500 8010.0 8019.0 XCD/KCL POLYMER 9.70 48.0 9.0 5.8 173.0 MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 3 - 34A : PRUDHOE BAY : NORTH SLOPE : ALASKA 0.457 0. 190 0.402 0.000 0.612 0.000 THERMAL SANDSTONE 0.00 7.875 1.5 68.0 173.0 68.0 0.0 68.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 GR AC 68 1 2 AC AC 68 1 3 ACQ AC 68 1 4 CHT AC 68 1 5 TTEN AC 68 1 6 TEMP AC 68 1 7 SPD AC 68 1 8 CILD DIFL 68 1 9 RFOC DIFL 68 1 10 RILD DIFL 68 1 11 RILM DIFL 68 1 12 SP DIFL 68 1 13 CLSN 2435 68 1 14 CN 2435 68 1 15 CNC 2435 68 1 16 CSSN 2435 68 1 GAPI US/F LB LB DEG F/MN MMHO OHMM OHMM OHMM CPS PU-L PU-S CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 008 99 5 4 4 61 094 30 1 4 4 34 704 23 6 4 4 27 515 24 6 4 4 04 903 06 0 4 4 06 213 78 0 4 4 53 419 67 0 4 4 84 023 70 1 4 4 52 326 75 5 4 4 98 211 23 1 4 4 83 368 34 1 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 227 Tape File Start Depth = 10011.000000 Tape File End Depth = 9219.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 64 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 110468 datums Tape Subfile: 5 Minimum record length: Maximum record length: 305 records... 62 bytes 958 bytes Tape Subfile 6 is type: LIS **** TAPE TRAILER **** 92/ 5/ 6 01 **** REEL TRAILER **** 92/ 5/ 6 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 6 MAY 92 4:59p Elapsed execution time = 56.69 seconds. SYSTEM RETURN CODE = 0
