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197-096
XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initia They; are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN scanning project. Complete Color items- Pages: Grayscale, halftones, pictures, graphs, charts Pages: Poor Quality Odginal - Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. D Other, No/Type OVERSIZED [] Logs of various kinds Other COMMENTS: Scanned b , ~/y~Mildmd D;relha Nathan Lowell TO RE-SCAN Notes: 1a. Well Status: D Oil DGas D Plugged !HI Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 !HI Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1/30/2006 197-096 306-007 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 06/08/1997 50- 029-22222-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 06/13/1997 PBU 02-35A 863' FNL, 905' FWL, SEC. 36, T11N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 1994' FNL, 1889' FWL, SEC. 36, T11N, R14E, UM 54.7' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 3582' FNL, 3620' FWL, SEC. 36, T11N, R14E, UM 11535 + 9009 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 687654 y- 5950339 Zone- ASP4 11630 + 9014 Ft ADL 028308 ---- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 688666 y- 5949233 Zone- ASP4 Total Depth: x- 690437 y- 5947689 Zone- ASP4 N/A MD ________________ __n__ - -- - 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes !HI No NI A MSL 1900' (Approx.) 21. Logs Run: MWD, GR, 4-Phase RES 22. GASING, LINER AND GEMENTING RECORD CASING .5eTTiNG ]E;PTH Me 5ETTIN.G I E;P'THTVD ~OLe AMOUNT SIZE WT.PER FT. GRADE TOP I BOTTOM ·IOP . troTTOM IZE CeMENTINGRECÔRD PULLeD 20" 91.5# H-40 Surface 110' Surface 110' 30" 11 cu yds Arcticset 13-3/8" 68# L-80 38' 3476' 38' 3476' 16" 594 cu ft CS II, 460 cu ft Class 'G' 9-5/8" 47# L-80 36' 8844' 36' 8545' 12-1/4" 375 cu ft Class 'G' 7" 29# L-80 8435' 8782' 8257' 8503' 8-1/2" 99 cu ft Class 'G', 713 cu ft Class 'G' 4-1/2" 12.6# L-80 8677' 11630' 8430' 9014' 6" 365 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TlJBllIIGRECORD ., Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 8669' 8605' MD TVD MD TVD 25. ACID,. f=fiACTURE,CEMENT SaUEEZE,ETC; DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10698' Set Whipstock / 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR Oil-Bel GAs-McF WATER-Bel CHOKE SIZE I GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED + Oil-Bel GAs-McF WATER-Bel Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ........ .. RECE\VEU .. STATE OF ALASKA . ALASKAIIl!!'JIL AND GAS CONSERVATION COMMTSslON MAR 2. 0 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LOG commission Maska Oil & Gas Cons. ¡\nchorage ~6K ~\·\r Form 10-407 Revised 12/2003 o RIG I f'\f~tD ON REVERSE SIDE R8DMS BFl MAR 2 9 ZOOG ~ G ~ /- 28. GEOLOGIC MARKER5- ~ 29. ..., FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 3 9075' 8681' None Zone 2C 9223' 8758' Zone 2A 9540' 8916' Zone 1 B 9683' 8965' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Signed Terrie Hubble ~^ 1\ "11 H,,-l~ Title Technical Assistant Date 03 ('7 / ~ PBU 02-35A 197-096 306-007 Prepared By NameINumber: Terrie Hubble, 564-4628 Well Number Permit No. I Aooroval No. Drilling Engineer: Barbara Lasley, 564-5126 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e e Well: Field: API: Permit: 02-35A Prudhoe Bay Unit 50-029-22222-02-00 205-002 Accept: Spud: Release: Rig: 01/29/06 02/01/06 02/11/06 Nordic #1 ". ~.="Y~·Y·Y" ,.~=~=.=^ ,.,=",..,... .. =.~ ....~. , N '~'Y'Y"~'Y' ~'v......· y "V PRE-RIG WORK 11/29/05 DRIFTED W/ 3.80" CENT, SAMPLE BAILER TO 9512' SLM. SAMPLE BAILER CAME BACK EMPTY. CALIPER TUBING FROM 8700' SLM, UP. GOOD DATA. 12/01/05 SET 41/2" X CATCHER SUB AT 8649' SLM. PULLED SIO FROM STA 2 AT 6181' MD. PULLED DOME FROM STA 1 AT 4008' MD. 12/02/05 SET 1" INT- DGLV IN STA 1 AT 4008' MD. LOAD lA, SET 1" INT- DGLV IN STA 2 AT 6181' MD. ATTEMPT MIT-IA TO 3000 PSI, NEVER GOT UP TO TEST PSI. CONFIRMED DGLV'S IN STA 1, 2, 3. MIT-IA TO 3000 PSI, PASSED. PULLED EMPTY C-SUB. LRS TO MIT OA AND OOA. 01/26/06 PU WFT 3.675" OD WHIPSTOCK DRIFT. 01/27/06 KILL WELL W/ 141 BBLS 1% KCL AND 40 BBLS METH. RIH WIWFT 3.675" OD WHIPSTOCK. DRIFT TO 10,750'. POOH. CHANGE PACK OFF'S. STAB BACK ON WELL AND FREEZE PROTECT FLOWLINE WITH 95 BBLS 60/40 METH. KILL WELL WITH 100 BBLS 1% KCL AND 35 BBLS 60/40 METH. POP OFF AND MU ICOIL TOOLS AND MHA. SWAB VALVE NOT HOLDING, HAD TO CAP P-SUB. LD TOOLS AND SHUT DOWN FOR NIGHT. 01/28/06 KILL WELL WITH 150 BBLS 1% KCL AND CAP WITH 60/40 METH. MU BHA WITH SPERRY SUN ESS MEMORY ORIENTATION TOOL AND BOTTOM ANCHOR/PACKER OF WHIPSTOCK SYSTEM. RIH AND TIE-IN; TIED INTO MEMORY CNL 10/01/1999. SET ANCHOR AT HyltS,{CORRECTED CTMD (THIS IS THE BOTTOM OF THE TOOL WHICH WILL LEAVE TOWS A+40700' WHEN (" ASSEMBLED) AND POOH. AT SURFACE AND SPERRY DOES NOT HAVE DATA; TOOL FAILED. MU ANOTHER SPERRY ORIENTATION TOOL AND DUMMY WHIPSTOCK LATCH TO DETERMINE ORIENTATION OF ANCHOR. RIH AND LATCH ANCHOR 3 TIMES WAITING 5 MINS. POOH. 01/29/06 VERIFIED WE HAVE GOOD DATA FROM SPERRY SUN ORIENTATION TOOL. ANCHOR POSITION CONSISTENTLY AT 59.7 DEG ROHS. INSPECT TOOLS AND THERE IS GOOD INDICATION THAT DUMMY WHIPSTOCK LATCH SUCCESSFULLY ORIENTATED INTO ANCHOR. KILL WELL WITH 50 BBLS FLOPRO, 1% KCL AND 60/40 METH FREEZE PROTECT. FINAL T/I/O 0/0/0. RDMO. JOB COMPLETE. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/28/2006 1/29/2006 1/30/2006 1/31/2006 ~ ',- - .... Page 1 .- BP EXPLORATION Operati()nsSummary.Rep.ort 02-35 02-35 DRILL+COMPLETE DOYON DOYON 16 Fi0iîì Tv HoUrs Task Code I NPT Phase 16:30 - 18:00 18:00 - 18:30 18:30 - 00:00 00:00 - 15:00 15:00 - 23:00 23:00 - 00:00 00:00 - 03:00 03:00 - 05:00 05:00 - 12:00 12:00 - 16:00 16:00 - 16:45 16:45 - 17:30 17:30 - 18:00 18:00 - 20:00 20:00 - 21:00 21 :00 - 23:00 23:00 - 00:00 00:00 - 01:00 01 :00 - 01 :30 01 :30 - 03:30 03:30 - 11:00 11:00 - 13:30 13:30 - 14:00 14:00 - 19:00 19:00 - 21:00 21 :00 - 22:00 22:00 - 23:30 23:30 - 00:00 1.50 RIGD P 0.50 RIGD P 5.50 RIGU P 15.00 RIGU P 8.00 RIGU N 1.00 RIGU P 3.00 RIGU P 2.00 BOPSUF P 7.00 BOPSUF P 4.00 RIGU P 0.75 RIGU P 0.75 WHIP P 0.50 WHIP N 2.00 WHIP N 1.00 WHIP P 2.00 WHIP P 1.00 WHIP P 1.00 WHIP P 0.50 WHIP P 2.00 WHIP P 7.50 STWHIP P 2.50 STWHIP P 0.50 STWHIP P 5.00 STWHIP N 2.00 DRILL P 1.00 DRILL P 1.50 DRILL P 0.50 DRILL N PRE PRE PRE PRE WAIT PRE PRE PRE PRE PRE PRE PRE WEXIT FLUD WEXIT FLUD WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT RREP WEXIT PROD1 PROD1 PROD1 DFAL PROD1 Start: 1/27/2006 Rig Release: Rig Number: 16 Spud Date: 10/25/1991 End: 2/11/2006 Description of Operations RD rig, Prep rig for move fl Z-11A to 2-35B PJSM wI rig personnel, security and tool service Move rig to DS2. Move rig to DS-02. Wait on site prep. Move over well. Accept rig at 23:00 hrs. RU rig. Continue to RU rig. NU BOP Perform initial BOPE pressure I function test. BOP test was witness by Chuck Schieve wi AOGCC and BP WSL. Meanwhile spot outside shacks. Finish BOP test with the exception of the inner reel valve. Held PJSM on stabbing CT, R/U cable and pulley, P/U injector head, Slip grapple into CT & pull test. Pull CT over pipe shed with winch & stab into injector, M/U injector to stripper, cut 200' of CT, install Weatherford slip-on CTC. Pull test to 35k. Meanwhile fill rig pits with 2 ppb biozan w/2 % KCL RU, pump volume dart, Circ, fill CT w/2 ppb Biozan wI 2% KCL, actual displacement 58 bbls Installed two RA pellets in whipstock tray Check well for pressure, OK, MU Whipstock Assy, RIH, set down around SSV based on measurements Wait on DSO to pump open SSV, DSO activated SSV several times, SSV was opened, RU, pumped out Stack and tree PU joint of CSH tubing tag and spud in ice. PU Nozzel and Checks RIH circulating at 2 bpm @ 1000 psi. RIH 2000'. PJSM. PU WS and setting tool ,jars and 2 jts PH6. /' RIH to 10600. Up wt 35K, Dn wt 21K. RIH tag at 10719'. PU to 38K Set back down. PU shear off at 45K. POH POH LD WS setting tool and PU window milling assembly. RIH tag at 10705. Correct to 10700'. Milling window fl 10700' - 10705.1'. drill new fromatiom to 10715',2.7/2.5 bpm with 2250 psi, FS = 1900 psi. Worked thru window several times, OK, Loss rate 7BPH. POH to BHA, displacing well to Flo-Pro mud LD milling assembly and PU drilling assembly. Reverse circulate into coil 5bb H20 and 1/2 bbl MeOH to freeze protect coil during shut down of SCR's. Repair SCR#2 . Any equipment assigned to SCR#2 runs away at max rate. Electrian changing out SCR controller card. PU drilling assembly. Circulate FP from coil. Rehead , Pull test to 39K. PT to 3500 psi. Stab onto well. RIH to 6400. Check orienter. No Go PU Try again. Orienter failed. POH Printed: 2/1312006 12:02:07 PM , . Page 2'- BP EXPLORATION Operations Summary Report Legal Well Name: 02-35 Common Well Name: 02-35 Event Name: DRILL+COMPLETE Contractor Name: DOYON Rig Name: DOYON 16 Date I From - To I Hours I Task !Code NPT! Phase ; 2/1/2006 00:00 - 00:30 0.50 DRILL N DFAL PROD1 00:30 - 01:15 0.75 DRILL N DFAL PROD1 01 :15 - 02:30 1.25 DRILL N DFAL PROD1 02:30 - 03:30 1.00 DRILL P PROD1 03:30 - 04:40 1.17 DRILL P PROD1 04:40 - 05:45 1.08 DRILL P PROD1 05:45 - 06:20 0.58 DRILL P PROD1 06:20 - 06:30 0.17 DRILL N DFAL PROD1 06:30 - 08:00 1.50 DRILL N DFAL PROD1 08:00 - 08:30 0.50 DRILL P 08:30 - 09:45 1.25 DRILL N 09:45 - 11 :50 2.08 DRILL N 11 :50 - 12:45 0.92 DRILL N 16:45 - 18:30 1.75 DRILL N 18:30 - 21 :00 2.50 DRILL N 21 :00 - 23:00 2.00 DRILL N 23:00 - 23: 15 0.25 DRILL N 23:15 - 23:45 0.50 DRILL N 23:45 - 00:00 0.25 DRILL N 2/2/2006 00:00 - 01:00 1.00 DRILL P 01:00 - 02:00 1.00 DRILL P 02:00 - 03:00 1.00 DRILL P 03:00 - 04:15 1.25 DRILL P 04:15 - 05:15 1.00 DRILL P 05:15 - 06:00 06:00 - 12:30 P P 1.75 DRILL P 2.25 DRILL P 2.25 DRILL P 1.00 DRILL P 2.50 DRILL P PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: Rig Release: Rig Number: 16 I i 1. Spud Date: 10/25/1991 End: 2/11/2006 1/27/2006 Description of Operations Continue to POH for orienter failure. Change out orienter. Surface test orienter OK. RIH to 6400' and shallow hole test orienter. Continue to RIH. Tag TD @ 10715. Orient TF 126R, drill 2.66/2.66 bpm @3280 psi, FS 3040 psi. 240 psi MW. Drill to 10760'. Log tie-in. Correction -2' Attempt to drill MWD pulser quit. Cycle pumps to determine if pulser would start. No Go POH SPILL identified. Cuttings box over flowed 2 bbls. Notified X5700, Anchorage,Drilling HSE Advisor. Begin Incident invistigation. Continued POH. Down load MWD Swab MWD pulser RIH to 6300'. Shallow hole test OK. Continue to RIH. Orient to 70R. nile UI section. 2. pm, 10837'. Pressure increased while trying to orient. No clicks on o' nter. POH for BHA failure. Flagged coil at 10500' EOP. Change out motor and orienter. could not pum~ ru motor at surface with rig air. HYC bi-center Bit was 0 1,1,1]. M/U 1.5 deg Xtreme motor. Surface test oriente K. RIH with build BHA #6 with 1.5 deg tor. Shallow hole test. RIH to flag and correct -14' CT Orient TF to go thru window ent thru window clean. Log GR tie-in with RA t at 10,702'. Added 4' CTD. RIH and tag bottom 10,840'. Orient TF to 90 . Hard to get clicks in build section, pulled to window a t 10 deg clicks. RIH to drill. Drilled d I turn section, 2.8 bpm, 2900 psi, 82 deg incl, drill to 10881'. ent around to 20R. Hard to get clicks. Pull to window to orient. Drilled build I turn section, 2.8 bpm, 2800-3300 psi, 15R, 85 degincl. Drilled to 10,912'. Drilled build I turn section, 2.8 bpm, 2800-3300 psi, 15R, 89 degincl. Drilled to 10,945'. Orient TF to 70R. Had to pull to window to get clicks. Drilled build I tum section, 2.7 bpm, 2900-3300 psi, 50R, 92 degincl. Wiper to window. Orient and directionally drill. Continually have to pull to window to orient. Approaching 60% pipe life. POH for pipe management. Set back injector. LD BHA. MIU SWS CT hyd cutter. Cut off 1,050 ft of CT with hydraulic cutter. M/U CTC, pull 1 press test. MIU BHA #8 with 1.2 deg Xtreme motor and re-built HCC BC Printed: 2/1312006 12:02:07 PM e 'e FRANK H. MURKOWSKI, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Barbara Lasley CT Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 tql- 00/0 Re: Prudhoe Bay, 02-35A Sundry Number: 306-007 s¡¡A,NN~ì_, ,,~~¢;~~O-"; ~)r:.:.; ., ie', 2 fin};, Ä, "~H Dear Ms. Lasley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~ day of January, 2006 Encl. Ancllorsoe 1. Type of Request: II Abandon / o Suspend o Operation Shutdown o Perforate o Other --------- o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. / 197-096 /' 181 Development D Exploratory 3. Address: D Stratigraphic D Service 6. API Number: ./ P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22222-01-00 7. KB Elevation (ft): 54.7' 9. Well Name and Number: PBU 02-35A ~ 8. Property Designation: 10. Field / Pool(s): ADL 028308 Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11630 9014 11535 9009 None 10529 Casino Lenoth Size MD / TVD Burst Collapse Structural 110' 20" 110' 110' 1490 470 3438' 13-3/8" 3476' 3476' 4930 2270 8808' 9-5/8" 8844' 8545' 6870 4760 I inAr 347' 7" 8435' - 8782' 8257' - 8503' 8160 7020 Liner 2953' 4-1/2" 8677' - 11630' 8430' - 9014' 8430 7500 Perforation Depth MD (ft): ..1 Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 9358' - 11530' / 8827' - 9009' 4-1/2",12.6# / L-80 8669' Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer Packers and SSSV MD (ft): 8605' ./ 12. Attachments: 13. Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program 14. Estimated Date for Janua~J006 15. Well Status after proposed work: Commencing Operations: Don DGas D Plugged 181 Abandoned 16. Verbal Approval: D~ DWAG DGINJ DWINJ D WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Barbara Lasley, 564-5126 Printed Name Barbara Lasley Title CT Drilling Engineer r~~, AAf þ' h, Date I III /òfc Prepared By Name/Number: Sianatur -'/7,.., r /. "7,11) A.. ~~" Phone 564-5126 Terrie Hubble, 564-4628 L/ V' /7 Commission Use Only I [ Conditions of approval: Notify Commission so that a representative may witness I Sundry Number:.2O(p ... 00 ( D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance Other: At p ~ lie.d {:or VIA- to - {ol '/'~~V~ J .\or- <;; ck tvO<lc. ~l 02. ~ ~S ß. / 401. R8DMS 8Ft JAN 1 2 2006 s"...q"em~' APPROVED BY /~//-()þ Approved By. j /Y~ COMMISSIONER THE COMMISSION Date Form 10-403 R~ C ~/ - Submit In Duplicate 1_ ' v-JCl,4t- tlLO(z.,OOV œ l-'tl..o'f' e STATE OF ALASKA 0.1/11/--6 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & Gas Cons. COInmiss¡o' h JAN 0 9 2006 ¡^-\ 1"-\ '- e e bp To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Barbara M. Lasley, CTD Engineer Date: January 6,2006 Re: Prep Prudhoe 02-35A for CTD sidetrack Sundry approval is requested to prepare 02-35A for a sidetrack. This well was originally sidetracked in June, 1997 as a horizontal Zone IB producer. Continuous perforations were shot from 10020' - 11530'. The well produced full time for 1-112 years and began cycling in mid-1998. A borax log run in October 1999 did not identify any channels but indicated an interval with good isolation outside the perforated liner across shale. A cmp was set in this interval in April 2001 to reduce gas production. The result of the cmp was a loss of 300 bopd and 7 mmcfd causing the GOR to rise to 45,000 scf/bbl. Following the poor cmp results, the well was SI for 8 months until Z2B adperfs were shot in December 2001. The Z2B perforations provided an initial oil production increase of 1000 bopd. Mter 6 months. the Z2B perfS~d out and end-of-life Z2B oil lenses were perforated. The cmp was milled in April 2004 with minima af t on production. Well 2-35A currently produces 1200 bopd at 50,000 scf/bbl with no healing. The 02-35A is 0 longer healing when shut in and has had minimal uptime in 2005. No intervention options exist for this well. Pre-Rig Work Summary: The pre CTD work is slated to begin approximately ¡an 12. 2005. 1. Set DGL V Done 12/2/05 2. MITIA passed to 3000 psi. Done 12/2/05 3. MITOA passed to 3000 psi. Done 12/3/05 4. Pressure test tree/valves 5. Dummy whipstock drift 6. Set packer/lug for Weatherford 4-112" hollow whipstock. TOWS at 10700' MD. /' 7. Set Weatherford 4-112" hollow whipstock tray with 2 RA tags. 8. Bleed gas lift and production flowlines down to zero and blind flange 9. Remove wellhouse, level pad. T~~ 10 -4o~ &1fYOIfCL(. me Work 1. MIRU Nordic 1 and test BOPE. 2. Mill 3.80" window in Zone IB. 3. Drill sidetrack into Zone IB/2A target with resistivity. 4. Run and cement bonsai completion. 5. Cleanout liner and run cased-hole MCNL log. 6. Freeze protect well and RDMO. post-me Work 1. Install GL V's. 2. Install well house. Hook up flow line. '?~72~~ q:bara M. Lasley ~ CTD Drilling Engineer 564-5126 CC: Well File Sondra Stewmanfferrie Hubble TREE = 4-1/16' McEVOY WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 55' BF. ELEV = NIA KOP= 6461' Max Angle = 93 @ 10553' DatumMD= 9411' Datum TV D = 8800' 55 13-318' CSG, 68#, L-80,ID= 12.415' Minimum ID = 3,812" @ 1997' 4-112" CAMCO BAL-O SSSVN 7' LNR, 29#, L-80, 1):6.184' 7' BKRT1EBAO< SEAL ASSY, Ð= 6.312' 9-518' X 7' BKR HYFLO LNR HANGS'! TOP OF BKR TIEBACK SLEEVE 7' X 4-1/2' BKRZXPPKR, ID = 4.408' 7' X 4-1/2' BKR HM:: HGR, Ð = 4.408' 8664' 8670' 8677' 9-5/8' CSG, 47#, L-80, .0732 bpI. Ð = 8.681' PelFORA 1lON SUMMARY RS: LOG: SPERRY -SUN M\I\ID RESIST/GR 06114/97 ANGLEATTOPÆRF:59 @ 9416' Note: ReIer to Production DB lor historical perf data SIZE SPF MER\lAL OpnlSqz DATE 2-7/8' 4 9416·9420 0 10/20/02 2-7/8' 4 9358 - 9364 0 10/20/02 2-7/8' 4 9492 - 9517 0 12/25101 2-3/4' 4 10020-11530 C 06/17/97 7' LNR, 29#, L-80, I): 6.184' 10122' DA TE REV BY OOt.tÆNTS 08/26/92 ORIGINAL COMPLETION 06116/97 Sl8-SL T FIG SIDETRACK 02-35A) 01/27/02 CH'KAK OORRECTIONS 10/20/02 IJTRIKAK ADPERFS 04/16/04 JADlKAK PERFOORRECTIONS 04/27/04 FWE/KA MILL aBP; FISH 02-35A / SAFETY NOTES: WELL ANGLE> 70 DEG @ 9600' & > 90 DEG @ 9880'. . 1997' 4-1/2' CAMCO BAL-O SSSVN, 10= 3.812' ST ~ TVD 1 4008 4008 2 6181 6179 3 8495 8301 GAS LIFT MANDRELS DEV lYÆ VLV LATŒi roRT DATE o KBG-2LS [)MY INT 0 12/02/05 8 KBG-2LS [)MY INT 0 12/02/05 42 KBG-2LS [)MY INT 0 04/25/01 8408' H 9-518' X 7' BKR JM-ZXP PKR. ID - 6.312' 7' X 4-1/2' BKR 5-3 PKR, 10 - 3.850' 4-1/2' HESX NP,ID= 3.813' 4-112' TBG, 12.6#, L-80, .0152 bpf, Ð = 3.958' 4-1/2' WLEG, Ð = 3.958' 4-1/2' LNR SIDETRACK WNDOW 8782' - 8811' (OFF WHIPSTOCK) 4-1/2' LNR, 12.6#, L-80, .0152 bpf,ID=3.958' DATE REV BY COtJMe.lTS 12/02/05 KOOPAG GLV C/O PRUDHOE BA Y lJIIrr WB.L: 02-35Ä PERMT No: '1970960 AA No: 50-029-22222-01 SEC 36, T11 N, R14E. 863' SNL & 905' EWL BP Exploration (Alaska) SAfETY NOTES: WEll ANGlE> 70 DEG @ 9600' 8< > 90 DEG @ 9880'. 1991' 4-1/2" CAMCO BAL-O SSSVN,ID=3.812" 13-318" CSG, 68#, L-80, 10 = 12.415" Minimum ID:::: 3,812" @ 1997' 4-1/2" CAMCO BAl-O SSSVN ]" LNR, 29#, L-80, 10= 6.184" 7" )(4-1/2" BKRS-3 PKR, 10=3.850" 4-1/2" HES X IIIIP, 10= 3.813' 4-1/2" TEG, 12.6#, L-80. .0152 bpI, 10 = 3.958' -1/2" WLEG, 10" 9-518" CSG, 47#, L-80, .0732 bpI, 10 = 8.681" 7" LiliA, 29#, L-80, 10= 6.184" PERFORA TIOIII SUMMARY REF LOG: SPERRY -SUN MIND RESIST/GR 06114/97 ANGLE AT TOP PERF: 59 @ 9416' Note: ReIer to Production DB lor hist6rìcal ert data SPF INTERVAL 4 9416 - 9420 4 9358 - 9364 4 9492- 9517 4 10020 - 11530 4-1/2" LIIIR, 12.6#, L-80, .0152 bpI, 10=3.958" 11630' PRUDHOE BAY UNIT WELL: 02-35A PERMIT 11I0: II'j 970960 API No: 50-029-22222-01 SS:; 36, T11 N, R14E. 863' SNL 8. 905' EWL SF £¡¡ploration (Alaska) reserves As reserves is not MSTB a I PRUDHOE BAY, PRUDHOE OIL PBU_DS2 5 02-35A _Oil Rate (CD) (Mbbl/d) ___ Water Rate (CD) ( M bbl/d ) GasRate (CD)(MMcf/d) Cum 011 Prod (MMbbl) Gas I Oil Ratio ( M cf/bbl ) Water Cut % " 100 50 10 0,5 'I!ii 0.1 1997 98 99 2000 01 02 03 04 05 Date Fhæe 01 Cæe Nare Cæe1 b 0 IJ O.ZQ28Ae. q 773. ïæ ttUd ti 12!3112J1j te œl2f!I2ffJl Ern Ráe 58J ttUd FiM Ráe o Em.:n2ttUd Cum R'ai : 172B.431\i'1':ti Cum Dáe : œt3112J1j Rssaves : 2B2.5161\i'1':ti 8.R : æ1Q961\i'1':ti Fcra::æt Erœ:I B/ 0 Ráe Fcra::æt Dáe 1crn 1a:IJ :;roJ 2fID Cum 01 R'ai I\i'I':ti a:IJ o a::m ;g J:! J:! 1crn <I> ro cr Õ a:IJ ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Suspend 0 Repair Well 0 Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate 0 WaiverD Stimulate D Time ExtensionO Re-enter Suspended WellO Name: BP Exploration (Alaska), Inc. Development Œ] Stratigraphic D 9. Well Name and Number: 02-35A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Exploratory 0 Service 0 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 54.70 8. Property Designation: ADL-0028308 11. Present Well Condition Summary: Total Depth measured 11630 feet true vertical 9014.2 feet Plugs (measured) Junk (measured) Effective Depth measured 11529 feet true vertical 9008.7 feet Casing Length Size MD TVD Conductor 80 20" 91.5# H-40 39 - 119 39.0 - 119.0 Intermediate 8724 9-5/8" 47# L-80 36 - 8760 36.0 - 8487.7 Liner 2966 4-1/2" 12.6# L-80 8664 - 11630 8420.8 - 9014.2 Production 10087 7" 29# L-80 35 10122 35.0 - 8998.2 Surface 3452 13-3/8" 68# L-80 38 3490 38.0 - 3489.9 Perforation depth: Measured depth: 9358 - 9364,9416 - 9420,9492 - 9517,10020 -10540,10540 -11530 True vertical depth: 8827.45 - 8830.59,8857.52 - 8859.57,8894.54 - 8905.84,8993.85 - 9010.77,9010.77 - 9008.7 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 33 8669 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-112" Baker ZXP Packer 7" Baker JM-ZXP Packer @ 8605 @ 8670 @ 8408 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaae Production or Injection Data Oil-Bbl Gas-Met 13 Water-Bbl 0 Prior to well operation: Subsequent to operation: 56.5 45.8 20 1125 1177 14. Attachments: 15. Well Class after proposed work: ExploratoryD Other~ Mill CIBP 5. Permit to Drill Number: 197-0960 6. API Number 50-029-22222-01-00 R~CEIV€D JUN 1 6 ?OO4 ~ Q'/1t'ð:s LOns. ~ ' 1~~~vJ ' . Burst 1490 6870 8430 8160 4930 Casing Pressure 700 700 Development ŒJ Collapse 470 4760 7500 7020 2270 Tubing Pressure 1536 1750 ServiceD 16. Well Status after proposed work: Operational Shutdown D OilŒ] GasO WAG 0 GINJO WINJO WDSPLO Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Copies of Logs and Surveys run- Daily Report of Well Operations, ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron J1~ Crdz;;.-, Title Production Technical Assistant Signature !\pr- ne 564-4657 :1 . ~ i il ,¡".'; Form 1 0-404 Revised 12/2003 8ft", Date 6/15/04 ~UK 17 10(V~ ( ( 02-35A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/27/04 Mill CIBP: MIRU CTU #4. RIH with WFD 3.65" 6 blade, flat junk mill. Tag CIBP @ 105341. Mill with 1-4 klbs on bilt to release CIBP. Push through perf interval from 10530-115291, hanging up intermittently. Push CIBP to PBTD at 115291. POOH. Displace well with crude to underbalance. Well left 81, night D80 will POP to LP. FLUIDS PUMPED BBLS 400 100 160 660 1 % XS KCL 50/50 Methonal Crude TOTAL Page 1 TREE = 4-1/16" MeBJOY WELLHEAD = Ftv'C ACTUA. TOR = AXELSON KB. 8.EV = 55' BF. 8.EV ,;, , NlA' KOP = 6461 ' r.æx Angle =' 93 @ 10553' Datum MD = 9411' Datum TVD = 8800' SS 113-318" CSG, 68#, L-80, ID = 12.415" H 3490' I J Minimum ID = 3.812" @ 1997' 4-112" CAMCO BAL-O SSSVN 17" LNR, 29#, L-80, ID = 6.184" H 8407' 17" BKR llEBACK SEAL ASSY, ID = 6,312" H 8424' 19-5/8" X 7' BKR HYFLO LNR HA.NGER I~ 8425' ITOP OF BKR llEBACK SLEEVE -1 8664' \ 17' X 4-1/2" BKR ZXP A<R, ID = 4.408" - 8670' 7' X 4-1/2" BKR HMC 1-K3R, ID = 4.408" - 8677' I 9-5/8" CSG, 47#, L-80, .0732 bpt, ID = 8.681" 1-1 8760' J-----A ÆRFORA TON SUMMARY RS= LOG: SÆRRY -SUN MWD RESIST/GR 06/14/97 ANGLE AT TOP PERF: 59 @ 9416' Note: Refer to Produetion DB tor historieal perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2- 7/8" 4 9416 - 9420 0 10/20/02 2-7/8" 4 9358 - 9364 0 10/20/02 2- 7/8" 4 9492 - 9517 0 12/25/01 2-3/4" 4 10020 - 11530 C 06/17/97 I 7' LNR, 29#, L-80, ID = 6.184" 1-1 10122' I DATE REV BY COMMENTS 08/26/92 ORIGINAL COMPLETION 06/18197 SIS-SL T RIG SIDEfRACK (02-35A) 01/27/02 CH/KA K CORREGfIONS 10/20/02 DTRlKAK ADPERFS 04/16/04 JAD/KAK PERF CORREellONS 04/27/04 PWElKAKMLL CIBP; ASH DATE REV BY ( 02-35A SAFETY NOTES: WELL ANGLE> 70 DEG @ 9600' & > 90 DEG@ 9880'. I> 1997' H4-1/2" CAMCO BAL-O SSSVN, ID= 3.812" 1 ~ L ST MD 1 4008 2 6181 3 8495 GAS LIFT MA.NDRELS TVD DBI lYÆ VLV LATCH RJRT DATE 3953 0 KBG-2LS DOME NT 16 04/25/01 6124 8 KBG-2LS SlO NT 20 04/25/01 8246 42 KBG-2LS OJ NT 0 04/25/01 ~ L !&~i f J . 8408' H 9-5/8" X 7' BKR JM-ZXP PKR, ID = 6.312" I Z I 8605' 17"X4-1/2" BKRS-3PKR, D=3.850" I 8647' 1-14-1/2" HES X NIP, ID = 3.813" I 8668' 1-14-1/2" TBG, 12.6#, L-80, .0152bpf, ID= 3.958"1 8669' 1-14-1/2" WLEG, ID = 3.958" 1 Z I L ~ ,I ~ ~ 4-1/2" LNR SIDErRACK WINDOW 8782' - 8811' (OFF WHIPSTOCK) 1-1 FISH - MILLEDCIBP 1 .£. ~ I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 11630' I COMMENTS PRUDHOE BAY UNIf WELL: 02-35A ÆRMT No: 1970960 API f\b: 50-029-22222-01 SEe 36, T11 N, R14E, 863' SNL & 905' EWL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X ADD PERES Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 55 feet 3. Address Explorato~_~ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 863' FNL, 4374' EEL, Sec. 36, T11 N, R14E, UM (asp's 687654, 5950339) 02-35A At top of productive interval 9. Permit number / approval number 2319' FNL, 3070' EEL, Sec. 36, T11 N, R14E, UM (asp's 688995, 5948917) 197-096 At effective depth 10. APl number 2832' FNL, 2449' EEL, Sec. 36, T11 N, R14E, UM (asp's 689629, 5948419) 50-029-22222-01 At total depth 11. Field / Pool 3582' FNL, 1660' EEL, Sec. 36, T11 N, R14E, UM (asp°s 690438, 5947689) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11630 feet Plugs (measured) CIBP set @ 10540' (04/17/2001) true vertical 9014 feet Effective depth: measured 10540 feet Junk (measured) true vertical 9011 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 99 cf AS 148' 148' Surface 3438' 13-3/8" 2594 cf CS II, 460 cf 3476' 3476' Class 'G' Intermediate 8808' 9-5/8" 2375 cf Class 'G' 8844' 8545' Liner 347' 7" 499 cf Class 'G', 713 cf 8435' - 8782' 8256' - 8503' Class 'G' 2953' 4-1/2" 365 cf Class 'G' 8677' - 11630' 8430' - 9014' Perforation depth: measured Open Perfs 9358'-9364', 9416'-9420', 9492'-9517', 10020'-10462', Open Perfs below CIBP 10610'-11150' true vertical Open Perfs 8827'-8831', 8858'-8860', 8894'-8906', 8994'-9011', Open Perfs below CIBP 9008'-9010', 9009'-9009' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-8O, TBG @ 8605' MD; 4-1/2", 12.6#, L-80, Tubirlg.,_Tail ~_866_9'_M_D. __ Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker 'S-3' Packer @ 8605'. 4-1/2" Camco BAL-O SLVN SSSV Nipple @ 1997' MD. 13. Stimulation or cement squeeze summary NUV [~ 6 ~U{)~ Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure A~ Off& Gas 00ns. C0mmlssl0n ~nrhnr~na 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcr Water~Bbl Casing Pressure Tubing Pressure Prior to well operation 10/11/2002 545 22138 3 1865 Subsequent to operation 10/23/2002 1219 25633 0 2002 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~V~'~,~,tj~~~/'~ Title: Technical Assistant Date Oc to ber 28, 2002 DeWayne R. Schnorr ~ Prepared by DeWar/ne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 02-35A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/23/2001 PERF(ADD-PERF): DRIFT W/2-7/8" DUMMY PERF GUN (PRE-PERF) 12/25/2001 PERF(ADD-PERF): 2 7/8" HSD 4 SPF POWER]ET 08/28/2002 TESTEVENT--- BOPD: 927, BWPD: 0, MCFPD: 30,476, AL Rate: 0 10/17/2002 PERFORATING: DRIFT/TAG 10/20/2002 PERFORATING: PERFORATING 10/21/2002 TESTEVENT--- BOPD: 1,470, BWPD: 0, MCFPD: 27,293, AL Rate: 0 EVENT SUMMARY 12/23/01 DRIFTED TO 9,685' WLM W/2 7/8" DUMMY GUN. RETURNED WELL TO DSO. 1 2/25/01 SHOT 2-7/8 IN HSD PJ 4 SPF RANDOM. PERFORATION INTERVAL 9492' TO 9517'. CCL STOP DEPTH 9486.7 FT. CCL TO TOP SHOT 5.3 FT. **** WELL BACK ON PRODUCTION **** 08/28/02 TESTEVENT --- BOPD: 927, BWPD: 0, MCFPD: 30,476, AL Rate: 0 I 0/17/o2 DRIFT W/3 3/8" X 12' DUMMY GUN TO 9480'SLM. TURN WELL OVER TO PAD OPERATOR TO POP. I O/20/O2 SHOT 2-7/8 IN HSD 2906-PJ 4-SPF STANDARD PHASE. PERFORATION INTERVAL 9416-9420 & 9358-9364. CCL STOP DEPTHS WERE 9409.8' & 9350.33' AND CCL TO TOP SHOTS -- 6.166' & 7.666'. FIRED BOTH GUNS UNDERBALANCED BY 200 PSI BY FLOWING WELL PRIOR TO SHOOTING. CHARGE DATA: PENETRATION=27.7", ENTRANCE HOLE DIAMETER--0.36", MAX. EXPLOSIVE LOAD-15g. POP WELL. 10/21/02 TESTEVENT --- BOPD: 1,470, BWPD: 0, MCFPD: 27,293, AL Rate: 0 Fluids Pumped BBLS 3 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 3 TEST) 3 TOTAL ADD PERFS THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-7/8" PJ 4 SPF, RANDOM ORIENTATION. 12/25/2001 I O/2O/2OO2 9492' - 9517' 9358' - 9364' 9416' - 9420' Page I TREE= 4-1/16" McL:VOY SAFETY NOTES: WELL ANGLE> 70 = 6461' jr v lax Angle = 93 @ 10553' ~4~, ~ I leo?' H4-1/2" CAMCO BAL-O SSSVN, ID= 3.812"I Datum TVD = 8800' SS 113-3/8"CSG, 68#, L-80, ID= 12.415" H 3490' ~.~ Minimum ID = 3.812" @ 1997' I GAS LIFT MANDRELS ,~-,--i'~'-'~/~" CAMCO BAL-O SSSVN ST IvD 'FVD DEV TYPE VLV LATCH FORT DATE 1 40081 3953 0 KBG-2LS DOME NT 16 04/25/01 b 2 6181 6124 8 KBG-2LS S/O IHT 20 04/25/01 3 8495 8246 42 KBG-2LS DV HT 0 04/25/01 I 7" LNR, 2~t, k-80,ID= 6-184'' H 840~'i 17"BmTIEBACKS~,t_ASS¥,~D=6.312"H 8424' ,I LI ] 19-5/8" X 7" BKR HYFLO Lm HANGER 8425' I = ~ 8647' ~4-1/2' Hm X~IR ID= 3.813" I I 9-5/8" CSG, 47#, L-80, .0732 bpf, ID = 8.681" 8760' PERFORATION SUE, IVIARY ~ 4-1/2" LNR SIDETRACK WINDOW 8782'- 8811' (OFF WFIPSTOC~) REF LOG: SPERRY-SUN MWD RESIST/GR 06/14/97 Note: Refer to ~oduction DB for historical peff data 4-1/2" BKR CBP (04/17/01 ) SIZE! SPF I ~NTERVAL Opn/Sqz DATE 2-7/8"1 4 i 9416-9420 0 10120102 2-7/8- 4 9358-9~4 0 10120102 .~ 2-7/8 4 9492-9517 0 12~25/01 2-3/4" 4 i 10020- 10462 0 06/17/97 2-3/4" 4 10610 - 11150 C 04/t7/01 DATE I REV BY COMIVENTS I DATE REV BY COMIVENTS PRUDHOEBAY UNIT 08/26/92 ORIGINAL COMFLETION WELL: 02-35A 06/18/97 SIS-SLT RIG SDETRACK (02-35A) PE~IVIT No: 1970960 i 01/02/01 SIS-SLT CONVERTED TO CANVAS APl No: 50-029-22222-01 02/21/01 SIS-LG REVISION SEC36, Tll/~ R14E 863' SNL& 905'EWL 101/27/02 CH/KAK CORRECTIONS 10/20/02 DTPJKAK ACPERFS BP Exploration (Alaska) PERFORATION S UIVIVIARY REF LOG: SPERRY-SUN MWD RESIST/GR 06/14/97 ANGLE AT TOP PERF: 59 @ 9416' Note: Refer to Production DB for historical pen' data SIZE! SPF INTERVAL Opn/Sqz DATE 2-7/8"I 4 9416 - 9420 O 10/20/02 2-7/8" 4 9358 - 9364 O 10/20/02 2-7/8 4 9492 - 9517 O 12/25/01 2-3/4" 4 10020 - 10462 O 06/17/97 2-3/4" 4 10610 - 11150 C 04/t7/01 2-3/4" 4 11210 - 11530 C 04/17/01 DATE REV BY COMIVENTS DATE REV BY COMIVENTS 08/26/92 ORIGINAL COMFL ETLON 06/18/97 SIS-SLT RIG SDE'DRACK (02-35A) 01/02/01 SIS-SLT CONVERTED TO CANVAS 02/21/01 SIS-LG REVISION 01/27/02 CI-VKAK CORRECTIONS 10/20/02 DTR/KAK ACPERFS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well_ Other _X (CIBP) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 54.7 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 863' FNL, 4374' FEL, Sec. 36, T11 N, R14E, UM (asp's 687654, 5950339) 02-35A At top of productive interval 9. Permit number / approval number 2319' FNL, 3070' FEL, Sec. 36, T11 N, R14E, UM (asp's 688995, 5948917) 197-096 At effective depth 10. APl number 50-029-2222-01 At total depth 11. Field / Pool 3582' FNL, 1660' FEL, Sec. 36, T11 N, R14E, UM (asp's 690437, 5947690) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11630 feet Plugs (measured) Set ClBP @ 10540' MD on 4/17/2001. true vertical 9014 feet Effective depth: measured 10540 feet Junk (measured) true vertical 901 1 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 11 yards AS 110' 110' Surface 3421' 1 3-3/8" 2594 cuft CS II & 460 cuft Class 3476' 3476' G Production 8789' 9-5/8" 2375 cutt Class G 8844' 8545' Liner 347' 7" 499 cuft Class G & 713 cuft 8782' 8503' Class G Liner 2953' 4-1/2" 365 cuft Class G 11630' 9014' Perforation depth: measured 10020' - 10540'; (Isolated below CIBP 11540' -11530'). true vertical 8993' - 9011'; (Isolated below ClBP 9011' - 9008'). ? -i !' 2 0 0 i Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 8669' MD. Packers & SSSV (type & measured depth) 7"x 4-1/2" BAKER S-3 PACKER @ 8605' MD. ,a, II(;l 4-1/2" CAMCO BAL-O SLVN SSSV Nipple @ 1997' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 605 18329 0 2178 Subsequent to operation 701 25824 0 828 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. Signed ' Title: DS 2 Surveillance Engineer Date May 17, 2001 Robert Younger III Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 02-35A DESCRIPTION OF WORK COMPLETED SET CIBP FOR GSO Date Event Summary 4/06/2001- 4/17/2001' 4/24/2001 - 4/25/2001' RIH & drifted to 9720' SLM (HAW). A CIBP was set for gas shutoff as follows: MIRU CTU. PT'd equip to 4000 psi. RIH & killed well w/135 bbls of 1% KCl Water. Set a 4-1/2" Baker Cast Iron Bridge Plug @ 10540' MD to isolate the following perforations: 10540'- 11530' MD (Zone 1) Reference Log: DGWD 11/20/1991. Verified set & POOH w/setting tool. Pumped Crude down BS to lighten column. FP'd well. RD CTU. RIH & set generic GLV's. Placed well BOL & obtained a welltest. Well has been shut in since 4/29/01 due to high GOR. Options are currently beinging evaluated for this well. Page 1 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE M P L ATE E IA L U N D W E R TH I$ M A R K E R AOGCC Individual Well Geolo~ical Materials Inventory PERMIT DATA T DATA PLUS Pa~e: 1 Date: 05/24/99 RUN RECVD % . 97-096 PERRY MPT/GR 97-096/ DS~/~w~4-~D ~8811011630 97-096! DGR/WER4-TVD ~/~503-9014 10-407 ~R~MPLETION DATE @6ff~/~?/ DA~LY WELL OPS /'0 £/>o/~?/ TO ~//?/g?/ Are dry ditch samples required? yes ~ received? Was the well cored? Mes ~.~-~alysis & descrip~ion received? Are well tests required? es ~R~ce~ved,~~' no Well is in compliance ~ I~itial CO~ENTS ~ 08/27/97 4 10/15/97 FINAL 10/30/97 FINAL 10/30/97 ~¢ ~?/ ~ no T D BOX -- Memory Multifinger Caliper Log Results Summary Company: Log Date: Log No.: Run No.: Pipe Desc.: Pipe Use: ARCO Alaska Sept. 4, 1999 1008 1 4.5' 12.6//Buttress Tubing Well: 02-35A Field: Prudhoe Bay State: Alaska Top Log Intvl: Surface Bot. Log Intvl: 8669 Ft. (MD) Inspection Type' Corrosive Damage Inspection COMMENTS: This survey was run to assess the condition of the tubing with respect to corrosive damages. The caliper recordings indicate that the tubing is in good condition, with light to moderate corrosive damage generally ranging from 0 to 15 percent wall penetrations throughout. Penetrations as deep as 18 percent wall are recorded in four joints. Light scaling, as thick as 0.02" is also indicated throughout much of the tubing. No areas of significant cross-sectional wall loss are indicated, with the most severe area showing only 5% metal loss in Pup Jt. 95.1, just above GLM 3. No abnormal restrictions or projections were recorded. MAXIMUM RECORDED WALL PENETRATIONS: Shallow Pitting (18%) Jt. 90 @ 3779' MD Shallow Pitting (17%) Jt. 98 @ 4136' MD Shallow Pitting (17%) Jt. 185 @ 7742' MD Shallow Pitting (17%) Jt. 193 @ 8083' MD Shallow Pitting (16%) Jt. 192 @ 8045' MD MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Gen. Shallow Corr. (5%) Jt. 95.1 @ 3991' MD RECEIVED 1999 c orage No other areas or cross-sectional metal loss in excess of 5% recorded throughout tubing. MAXIMUM RECORDED ID RESTRICTIONS: Minimum restriction of 3.791" recorded in X Nipple @ 8647' MD. The scaling recorded throughout the tubing is significantly less restrictive than the seating nipple in the tubing. I Field Engineer'Steve Adcock Analyst: JoeyBurton Witness: Doug Cismoski ProActive Diagnostic Se,~/ices, Inc, / P,O, Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-i369 E-mail; PDS~memowIog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Sondex Caliper Overview Body Region Analysis Well: 0~35A Survey Cate: Sept 4, 1999 Field: Prudboe Bay Tool Type: PDS Multi-Finger Memory Company: ARCO Alaska Tool Size: 23~4 ins Country: USA No, of Fingers: 40 J, Burton ~ Tubing: Size Weight Grade & Thread Nora. OD Nora. ID Nora. Upset 4.5 ins t2.6 ppf L-80 BUTTRESS 4.5 ins 3.958 ins 4.5 ins ~,penetration body ~metal loss body 2OO 100 5O 0 0to lio 10to 20to 40to above 1% 10% 20% 40% 85% 85% Numberof joints anal'/sed(total = 220) Pene 13 179 28 0 0 0 Loss 177 43 0 0 0 O 60 Number of ioints damaged (total = 60) 59 1 0 0 0 Da~oOe Profile (% w~ll) penetration body ~ metal loss body 0 5O 100 GLM 3 GLM 2 188 GLM 1 Bottom of Survey = 204.6 Analysis Overview page 2 SONDEX CALIPER JOINT TABULATION SHEET Pipe: 4,5ins 12.6 ppf L-80 BUTTRESS Watt thickness. Body:0,271ins Upset=0,271ins Nominat ID: 3.958 ins Well: 02-35A Field: Prudhoe Bay Company: ARCO Alaska Country: USA Date: Sept 4. 1999 penetration body metal loss body Joint Penetration ,4etal Projection ~ nimum No. Upset Body Less Upset Body ID ;omments inches inches % % inches inches inches I 0 ,02 6 I 0 0 3.88 PUP .2 0 .02 7 I 0 0 3,91 PUP 3 0 .01 2 1 0 0 3.90 PUP ,4 0 ,02 7 1 0 0 3.93 PUP 1 0 02 7_ 1 0 0 3.92 1ST Fall Length Jr. Be'l~w"~ree 2 0 .02 7 1 0 o 3,92 3 0 .00 2 1 0 0 3.90 4 0 01 6 0 o 0 3.91 5 o 01 2 1 o 0 3.90 6 0 .02 7 1 0 0 3.90 7 0 .01 5 t 0 0 3 90 8 o .Ol 3 1 0 0 3.92 9 o ,02 7 1 0 0 3.90 10 0 .02 7 2 0 _ 02 390 Light deposits. 11 0 .02 6 I 0 0 3.89 12 0 .02 6 0 0 0 3.91 _,,1,,3. .......... 0 02 8 1 0 O 3.91 Isolated shallow pi[ting. 14 0 .02 7 I 0 0 3.88 15 0 .02 7 1 0 0 3.89 16 0 02 7 1 0 0 3.90 17 0 .02 7 1 0 0 3,91 18 0 .01 4 1 0 0 3.89 19 0 .02 7 I 0 0 391 20 0 ,02 6 1 0 0 3.89 21 0 .01 5 1 0 0 3.88 22 0 .~.02 I 7 1 0 0 3,91 23 0 .01/ 2 1 0 0 391 24 0 .02 7 , 0 0 3 92 25 0 .02 7 1 0 0 3.91 26 0 ,02 7 1 0 0 3.91 27 0 01 5 I 0 0 3.89 28 0 .00 1 ! I 0 I, 0 3.90 29 0 .............. :,02 7 I 1 0I 0 3.90 __ 30 0 02 6 I 1 0 0 3.91 31 0 .00 1 i 1 0 0 3,92 32 0 .01 5i 1 0 ,,,i 0 3,89 33 0 .02 7! 1 0 0 3.91 34 0 ,01 5 I 1 0 0 3.89 35 0 00 1 i t 0 0 3.91 36 0 .00 1 1 0 0 3.90 ~ 0 .01'"' '"'~ I 0 0 3.91 38 0 ,02 7 1 0 0 3~89 39 0 .02 7 2 0 0 3.9t 40 0 t .02 7 1 0 0 3.90 Pipe Tabulations page 1 Damage profile (% wall) 50 10( SONDEX CALIPER JOINT TABULATION SHEET Pipe: 4.5 ins 12,6 ppf L-80 BUTTRESS Walt thickness Body: 0.271ins Upset = 0.271ins Nominal ID: 3.958 ins Well: 02-35A Field: Prudhoe Bay Company: ARCO Alaska ~ penetration body Country: USA ~metal loss body Date: Sept. 4, 1999 Joint i Penetration ~etal Projection linimum Damage profile No i Upset Body Lose Upset ~ody tD ;omments (% wall) inches inches % % nches inches inches 50 1( 41 0 .002 l_,j 0 0~ 3.86 , 42 0 02 6 1 0 0 3.91 i 43 0 02 7 2 0 .{~'2 3.89 !Lightdeposits. i44 0 02 7 1 0 0 3,91I_ 4145 0 02 7 2 0 0 391 _,,? .02 7 1 0 .02 3.91 ~ deposits. ~ 0 .02 8 2 0 0 3.94 PUP isolated shallow pitting, 1472 0 0 0 0 i 0 0 3,81 SSSV 't,,48'? 0 02 ,1, 0 0 388 , 0 .02 8 2 0 .02 3.91 salated shallow pitting. 50 0 .02 7 2 0 0 3.89 I15~ 0 02 7 ~ 0 0 3'SSi o ,o2 o o 3.89 53 0 '- .02 7 1 0 0 3.91 ~llarli lar111~ "' .02 9 3 0 .02 3.92 solated shallow pitting. 55 0 ,02 8 1 0 0 3.91 selated shallow pitting, 57 0 .02 7 1 0 0 3.90 __ 58 0 ,02 6 0 0 ,02 , 3,91 , ight deposits. 59 0 .03~ 1,,,~1 ~1 ~ 0 3.90 solated shallow p~n§: 60 0 .03 13 2 0 .02 3.;,91~ solatedshallowpttling. 61 0 .02 8 2 0 .02 3.91 sotated shallow piiting, 62 0 .01 3 2 0 0 [ 3.87 _ 63 0 ,02 7 2 0 0 3,92 84 0 ,03 10 2 0 .03 388 selated shallow pitting. 65 0 02 8 0 0 0 3.91 selated..shallow illin 66 0 ,02 8 1 0 0 3.85 setated shallow pitting. 67 0 .02 7 I 0 0 3.88 68 0 .02 8 1 0 .03 3.88 sotated shallow pitting. 69 0 .03 10 1 0 0 3.91 solated shallow pitting, -- 70 0 .03 12 2 0 .03 [ 3.9"~- solated shallow piiling. 171 0 .02 7 2 0 .03 3.88 selated shallow pitting. 0 ,02 7 0 0 0 3.90 , 0 03 11 1 0 0 39~'- solated shaliow~ ....... 74 0 .02 8 2 0 .05 I 3.91 solated shallow pitting. 7576 00 02'03 1 71 23 00 0'03II 33'87,89 selated shal~ 77 0 .01 3 1 0 0 3.89 __ _ _. 78 0 .03 11 2 0 .03 I 3.91 isolated shallow pitting. 79 _0 .04 14 1 0 .02 ] 3.87 Isolated shallow pitting. 80 0 ,03 12 t 0 0 3.90 isolated shallow itt. in,. 81 0 .02 ,,, ~ , , 2 0 0 I 3,90 isolated shallow pitting. Pipe Tabatafions page 2 SONDEX CALIPER JOINT TABULATION SHEET Pipe:4.51ns 12.6 ppf L-80 BUTTRESS Wall thickness. Body: 0.271ins Upset = 0.271ins Nominal ID: 3.958 ins Well: 02-35A Fietd: Prudhoe Bay Company: ARCO Alaska ~ penetration body Countl¥: USA ~ metat loss body Date: Sept. 4, 1999 Joint Penetration ,4etal Projection I~ nimum [ Damage profile NO. Upset Body Less Upset Body ! ID ;omments ! (%wall) inph~ !n~b~ % % inches in~ch~EJ !nc~ ~ 50 10 83 0 .03 11 2 0 0 [ 3.88 ~sotated shallow pit~g~ ~ ~ ,~ ~ ~ ~ ......... 0 ! 3.90 85 0 00 2 0 0 0 I 391ELIl 86 ~ ~4 ~ ~ 0 0 i 3.90 Isolatedsha~owp~ng. 87 0 .03 12 1 0 0 [3.87 [solatedshatiowp~fin 88 0 :~2 7 ~ 0 0 ~ 3.92 ' ';'~ ;;~ ';~'; BI I 89 o .02 7 i o .04 3.89 Isolaed shallow pBing, ~ ~ ~ ~ - ~ ~ .02 3.~ isolated shallow piton el o _:o~ %.,., ~ o o ~,9o , , ~ II 92 ~ 01 ~ 0 0 .02 3.91 Light deposes. 93 0 .04 13 I 0 .03 3.92 Isolated shallow ¢,E, ng 94 0 .02 7 0 0 0 ~ 95 0 .02 8 2 0 .82 ~ I~iate~';'~;]low ¢~ng ~ """~' ........ .04 15 5 0 0 3.89 PUP Isolated shatt~f,~ 953 0 .02 8 1 0 ~ 3.89 PUP - -';~*1 96 .03 .04 ; 14 t 0 .03 3.~ Isola~ ;~;ii;;pi~i~ 97 0 .03 13 ~ ~ .03 3.90 General shallow corrosioE 98 .02 ;~ ~7 1 .......... 0 0 3.88 Is~shall~E,~ . 99 0 ,02 ~ 0 0 0 .... ~:~'~ ~J ~"'""0 02i z ~ 0 0 ...... ;'5~ ' , .... Blt ~Z'~"' .02 I ~: Z ~ 0 3,88 ¢11/ 103 0 .01 [ 3; 1 0 0 3.90 __ _ I04 0 .03 110 ~ --0 ; 0 3.91 ls~atedshaliowpittin~ ~0~ 0 .02t ~i 2 0 0 ....... 5;'~ 106 0 ;~ ~ ~i ~ 0 i 0 3~91 ~~ - ~11/ ,o~ 0 :o7 ~ ~ o o 3.. . Eli/ 108 0 .01 4 0 0 ~ - 3.89 ' ~ - ~ll/ 109 __0 01 i 3 0 ...... 0 [-~' 3.89 ~ : ~11/ 1:0 0 .0~i 2~ 2 0 I 0 3.~ ............ '~':~ 0 .01 i ~ ~ ~ I'o ~.~z 114 0 ~ ~i~ .03~ .o3 ~:gs '*~~ - ~1/ 115 0 ~ ~i 2 0 ~ 3.91 116 0 .02 6l 0 0 0391.... ~1 I1 ii~ ~" o~ 3[ 0 0 ~- 3.92 . ~ ~ .Ol ~, o o ;:, -- -~11/ ~o o a ~i o o o .... 3, .. E/I/ ~ o .Ol ~ '""'~ o o ~.~ _ ' &l I/ ~ o .o~ ~ o o 6 ,] ,,,.~.a~ - ~11~ Pipe Tabulabons page 3 SONDEX CALIPER JOINT TABULATION SHEET Pipe: 4.5 ins 12.6 ppf L-80 BUTTRESS Well: 02-35A Waif thickness. Body: 0.271ins Upset = 0.271ins Field: Prudboe Bay Nominal ID: 3.958 ins Company: ARCO Alaska ~ penetration body Country: USA ~ metal loss body Date: Sept. 4, 1999 Joint PenCration Viet.¢ Projection N [nimum Damage profile No. Upset Body Loss Upset Body iD ;omments (%walt) inches inches i % % inches inches incbes 50 16 124 0 .00 t ...... ~ 0 0 3.89 I25 0 .01 6 iii ir ,nC ~ 0 3.85 .............. 128 0 02 7 I 0 0 3.89 127 10__ .0. _.~1 I 3 2 0 0 3.86 __ 128 0 00 I 1 1 0 0 3.92 i'29 0 .............. lbo I 2 I 0 .02 3.90 i~0 0 ~'-I 7 2 0 0 387 ........ I' 'l'la"l~ 131 0 .01 I 4 2 0 0 3.90 t32 0 .01 I 3 3 0 0 3.87 133 0 .01 t 5 I 0 0 3.91 134 0 .02 7 1 0 O 3.86 135 0 .01 "T, 0 0 0 3.90-,] 136 0 027f 0 0 "['"0 390 .... I ............. 137 0 02 7 I I 0 0 3.88 ........... 138 0 .01~i31~;; t 0 0 389 '1 0 3.86 -- 139 0 .81 'i'" 0 .... 14.~0 0 01 2 I 1 0 0 3.9I I41 0 .02 7 t 0 0 0 3.88 142 0 .02 "'~i 1 0 0 3.89 -- ~ 143 0 .02 7 I 1 0 0 3.86 144 0 .01 3 ! 1 0 0 3.90 145 0 .02 7 I 1 0 0 3.90 -- 14~6 0 .00 1 i 1 0 0 3.87 -- 147 0 .01 ...4 t 0 0 3.88 ........ 147.1 0 .00.......i.....! 0 0 0 3.89 PUP 147.2 0 00 0 0 0 3.90 GLM 2 I47.3 0 .01 5 1 0 ....... 0 390 PUP ~ 149 0 .. ~¢~........7.. 1 0 0 3.90 __ i150 0 .02 7 1 0 0 3.89 i l5~ 0 .o2 7 1 0 o_ 3..90 152 i 0 I ,0~ 3 0 0 0 3.89 __ 153 0 I .01 4 1 0 0 3.87 i154 0 .01 4 1 0 0 3.89 [155 0 ,00 I 0 0 0 3,91 0 o2_ _1.7 0 0 0 3.89 - [157 I 0 .02 7 1 ] ....0 ............ 0 ..... .3~89 !158 I 0 .01 4 0 t ~ ~ ..... ~,~E9 i 159 0 .03 10 0 I 0 0 3.90 solated shallow pitting. j180 0 .01 4 1 0 0 "~8 l~61 0 .01 6 0 ...0 0 3.90 lt62 0 .02 6 0 0_ ~0 3.90 1163 0 .02 9 0 0 0 3.89 solated shatlow piSJn9. . Pipe Tabulations page 4 SONDEX CALIPER JOINT TABULATION SHEET Pipe: 4,5 ins 12.6 ppf L-80 BU-fTRESS Wall thickness. Body: 0.271ins Upset = 0.271ins Nominal ID: 3.958 ins We. ii: 02-35A Field: Prudhoe Bay Company: ARCO Alaska ~ penetration body Country: USA ~ metal loss body Date: Sept, 4, I999 Joint Peneb'ation ~etal Projection fi,~inimum Damage profile No, Upset Body Loss Upset Body ID :ommests (%watl) inches inches % % inches inches inches 50 10 164 0 .01 8 1 0 0 3.90 165 0 , ~,0,~,,1.1,,, 1 0 0 3.91 [;~)tated ~,h~,l,low pilling. ' ........ I i 166 0 .01 4 I 0 0 3.87 167 0 .02 6 1 0 0 389 188 0 02 6 3 0 0 3,88 169 0 .02 7 0 0 0 3.88 1~0 0 .... .0""--~- "i5 1 0 0 3,87 Iso,l,~i~i"~tlow pitting. -- ..... ~ 171 0 .03 10 0 0 0 3.89 isolated shallow pitting,. ........ 172 0 .03 12 1 0 0 3.90 rTrTT1I,E,o,,!~ted shallow pitting. _.., 173 0 .03 1I 0 0 0 3.90 Isola ~d,.s,,hallow pitlJn9. 174 0 .02 7 0 0 0 3.89 175 0 04 14 0 0 0 3,15 m Isolated shallow pitting. ~ t76 0 .02 6 0 0 .02 3.89 Ught deposits. , .... 177 0 .03 10 __0 0 .03 3.89 isolated shallow pitting; ...... 178 0 .03 10 0 0 0 3.88 Isolated shall~r,l~i~ing 17~9 0 .02 8 O 0 0 _ 388 Isolated shallow pitting. , .......... 180 0 ,02 7 0 0 0 3.86 181 0 .01 3 0 0 0 3.85 182 0 .02 8 0 0 0 3.90 Isolated shallow,p!~n9,. ......... 183 0 .02 7 0 0 0 3,90 I84 0 __ .02 7 I 0 0 ............. ,3,88 185 0 05 I 17,,, 0 0 0 3.85 Isolated sh,,a,,!!.o,,w pititng. i,!r~i 0 .02 8 I 0 ,02 3.89 lS~!¢t~,d,rghallow pitting , , 187 0 .02 7 0 0 0 3,88 188 0 .03, 10 1 0 0 3,88 Isolated shallow pit!!ng. 189 0 ,02 6 0 0 0 387 190 0 ...,,._;03 12 1 0 0 3.8I__ Iset~ed shallow pitting, ~ 1_~!_. __0 02 8 1 0 0 3.88 Isolated shallow pitting. , ,, __ 192 0 ,04 16 1 0 i 0 3.88 Isolated shallow pittin, 193 0 .05 17 ~ ' 1 _0I 02 3.85 Isolated shallow pitting, 194 0 .04 15~ t 1 0 .02 3.91 Isolated shallow pitting. "~ 0 .012 I 1 0 .02 ~'~'""' Light deposits. -- i 196 0 .02 ";"] 0 0 .03 3.88 Ughtdeposit,, ~I 197 0 .03 10 J 2 0 0 3.75 Isolated shallow p~n,.~,~,, 198 0 ,02 7 J I 0 0 3.87 I99 O .02 7 0 0 0 3.87 200 O .01 4 i 0 0 0 3.89 ..... ~ - ~Q,,1 8 .o2 7 1 0 o~ 388 ,, __ ~. _..0 ,02 9 2 0 0 3.87 Isolated sfiallow pit~ng. ~ .... 202.1 0 ,00 1 2 0 0 3.85 PUP 202.z. 0 ..... 0 0 0 0 0 3.89 GLM 1 __ 202,31 0 ~ ~00 ,~2 .,, 1 I 0 0 3,89 PUP i203 I 0 I .02 9 1 I 0 .03 3.89 Iselatedshallowt~i~'~r~. .~0~ I 0 I 0t 3 1 t 0 .02 3.86 Li hide osits, Pipe Tabolafions page 5 SONDEX CALIPER JOINT TABULATION SHEET Pipe: 4.5 ins I2.6 ppf L-80 BUTTRESS Wail thickness. Body: 0271ins Upset = 0.271ins Nominal ID: 3.958 ins Well: 02-35A Field: Prudhee Bay Company: ARCO Alaska ~ peeetration body Country: USA ~?atat loss body Date: Sept. 4, 1999 Joint Penetration Vletat Projection 1~ inimum Damage profile No. Upset Body Loss Upset Body iD ~,omments (%wall) inches inches % % inches inches inches 50 16 204,1 0 0 0 0 0 0 384 PuP .... 204.2 0 .01 4 0 0 0 3.84 PACKER 204.3 0 .0I t 2 ,,, 1 0 .03 3.87 PUP 204.4 0 0 I 0 , , 0 0 0 379 HESXNIPPLE 204.5 0 .00I 1 1 0 0 3.89 PUP 204.6 0 .00I 1 0 0 0 "~:I~;~ ilrli ITT~E ~ Damage Classifications Penetration / projection class, in older of damage sevedty Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 75% of circumference, but depth range does not exceed 2 * pipe ID Line - damage depth range exceeds 10 * pipe lB, but extends less than 20% of circumference General - damage dep[h range exceeds 2 * pipe ID and/or extends more than 20% of circumference Isolated w damage depth range does not exceed 10 * pipe iD or extend more than 20% of circumference Damage repolling threshold = 20 thou inches deviation in body, 40 thou in upset, Modal line leng~ = 0.130 feet. I~ultifinger Caliper Cross-section ARCO Alaska Field: Prudhoe Bay We#: 02~35A Date: Sept. One o£ Deepest Pits = 0.05" or 18% in Jr. 90 @ 3779' MD. Mulfifinger Caliper Cross-section ARCO Alaska Field: Prudhoe Bay Well: 02-35A Date: Sept. 4, t999 One of Deepest Pits = 0.05" or 18% in Jr. 193 @ 8083' MD. SONDEX CALIPER JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 BU'I-rRESS Wall thickness. Body: 0.271ins Upset = 0.271ins Nominal ID: 3.958 ins Joint. Depth Length Measured Type No. ID feet feet inches .1 -1.29 2.50 3.960 Pup .2 1.21 7.89 3.969 Pup .3 9.10 3.13 3.973 Pup ,4 12.23 7.42 3.975 Pup 1 19.65 41.55 3.980 2 61.20 42,09 3.983 3 103.29 41.13 3.974 4 144.42 39.97 3.963 5 184.39 42.24 3.971 6 226.63 41.90 3.967 7 268.53 42.18 3.968 8 310.71 40.35 3.970 9 351.06 41.93 3.971 10 392.99 42.20 3.977 11 435.19 42.20 3.963 12 477.39 41.70 3.962 13 519.09 41.93 3.962 14 561.02 41.01 3.968 15 602.03 41.67 3.967 16 643.70 41.38 3.973 17 685.08 42.28 3.973 18 727.36 40.92 3.962 19 768.28 41.43 3.975 20 809.71 42.12 3.966 21 851.83 42.05 3.963 22 893.88 41.55 3.955 23 935.43 41.92 3.972 24 977.35 42.06 3.977 25 1019.41 41.56 3.963 26 1060.97 42.48 3.964 27 1103.45 42.14 3.964 28 1145.59 41.70 3.970 29 1187.29 42.01 3.961 30 1229.30 41.74 3.966 31 1271.04 42.13 3.965 32 1313.17 40.15 nominal 33 1353.32 41.73 3.965 34 1395.05 39.92 3.962 35 1434.97 41.59 3.975 36 1476.56 42.47 nominal 37 1519.03 41.22 3.968 38 1560.25 42.17 3.959 39 1602.42 41.91 3.970 40 1644.33 42.18 3.963 Well: 02-35A Field: Prudhoe Bay Company: ARCO Alaska Country: USA Date: Sept. 4, 1999 Joint Depth Length Measured fype No. ID feet feet inches 41 1686.51 37.81 3.966 42 1724.32 41.78 3.959 43 1766.10 42.56 3.962 44 1808.66 41.86 3.972 45 1850.52 41.90 3.965 46 1892.42 39.38 3.961 ~7 1931.80 41.72 3.964 47.31 1973.52 9.83 3.964 47.2 1983.35 5.30 nominal SSSV 47.1 1988.65 9.90 3.963 48 1998.55 42.17 3.954 49 2040.72 41.81 3.960 50 2082.53 42.02 3.962 51 2124.55 42.02 3.964 52 2166.57 42.05 nominal 53 2208.62 41.77 3.964 54 2250.39 41.34 3.969 55 2291.73 41.45 3.971 56 2333.18 38.35 3.951 57 2371.53 41.39 3.959 58 2412.92 42.55 nominal 59 2455.47 41.75 3.966 60 2497.22 41.89 3.953 61 2539.11 41.75 3.960 62 2580.86 41.93 3.954 63 2622.79 42.32 3.967 64 2665.11 41.90 3.956 65 2707.01 41.23 3.955 66 2748.24 39.33 3.953 67 2787.57 41.91 3.963 68 2829.48 42.03 3.962 69 2871.51 40.51 3.973 70 2912.02 41.77 nominal 71 2953.79 42.29 3.955 72 2996.08 39.15 3.962 73 3035.23 41.65 3.955 74 3076.88 38.16 3.965 , 75 3115.04 41.08 3.952 76 3156.12 42.02 nominal 77 3198.14 41.98 3.953 78 3240.12 39.55 nominal 79 3279.67 42.26 3.954 =,, 80 3321.93 41.69 nominal 81 3363.62 41.87 3.965 Joint Tally page 1 SONDEX CALIPER JOINT TALLY SHEET Pipe: 4.5ins 12.6 ppf L-80 BUTTRESS Wall thickness. Body: 0.271ins Upset = 0.271ins Nominal ID: 3.958 ins Joint Depth Length Measured Type No, ID feet feet inches 82 3405.49 41.89 3.960 , 83 3447.38 41.80 3.959 84 3489.18 41.76 3.956 85 3530.94 41.84 3.966 86 3572.78 41.67 3.953 87 3614.45 41.77 3.956 , 88 3656.22 42.06 3.970 89 3698.28 41.40 3.967 90 3739.68 41.43 3.959 91 3781.11 42.17 3.962 92 3823.28 41.36 3.970 93 3864.64 41.92 3.956 94 3906.56 41.56 3.952 95 3948.12 41.67 nominal 95.1 3989.79 9.83 3.959 Pup 95.2 3999.62 6.93 nominal GLM 3 95.3 4006.55 10.09 nominal PuD 96 4016.64 42.19 3.956 97 4058.83 42.03 nominal 98 4100.86 40.43 nominal 99 4141.29 41.16 3.952 100 4182.45 41.51 3.956 101 4223.96 42.33 3.953 102 4266.29 41.18 3.961 103 4307.47 41.75 3.964 104 4349.22 39.85 3.949 105 4389.07 42.18 3.951 106 4431.25 41.33 3.966 107 4472.58 42,09 3.954 108 4514.67 42.16 3.953 109 4556.83 40.84 3.953 110 4597.67 42.74 3.954 111 4640.41 40.69 3.953 112 4681.10 41.22 3.955 113 4722.32 40.23 3.951 114 4762.55 41.75 3.952 115 4804.30 41.68 3.950 116 4845.98 41.91 3.963 117 4887.89 41.03 3.969 118 4928.92 40.41 nominal 119 4969.33 42.75 3.949 120 5012.08 42.00 3.951 121 5054.08 42.06 3.961 122 5096.14 38.20 3.944 Well: 02-35A Field: Prudhoe Bay Company: ARCO Alaska Country: USA Date: Sept. 4, 1999 Joint Depth Length Measured Type No. ID feet feet inches 123 5134.34 39.90 3.953 124 5174.24 41.16 nominal 125 5215.40 40.18 3.953 126 5255.58 41.25 3.948 127 5296.83 41.79 3.954 128 5338.62 41.28 3.960 129 5379.90 41.78 3.950 130 5421.68 41.81 3.950 13t 5463.49 40.81 3.953 132 5504.30 42.17 3.952 133 5546.47 41.23 3.955 134 5587.70 38.27 3.953 135 5625.97 42.04 3.947 136 5668.01 42.32 3.943 137 5710.33 41.21 3.954 138 5751.54 41.57 3.947 139 5793.11 42.30 nominal 140 5835.41 41.27 3.955 141 5876.68 40.97 3.948 142 59t7.65 4t .34 3.955 143 5958.99 42.48 3.956 144 6001.47 40.49 3.954 145 6041.96 41.57 3.950 146 6083.53 42.77 3.952 147 6126.30 4t .13 3.951 147.1 6167.43 5.58 3.950 Pup 147.2 6173.01 10.98 nominal GLM 2 147.3 6183.99 10.03 3.953 Pup 148 6194.02 42.13 3.946 149 6236.15 41.48 3.951 150 6277.63 41.58 3.954 151 6319.21 41.59 3.962 152 6360.80 41.48 3.945 153 6402.28 42.40 3.953 154 6444.68 39.44 3.950 155 6484.12 42.31 3.948 156 6526.43 40.84 3.936 157 6567.27 41.29 3.946 158 6508.56 42.20 3.954 159 6650.76 41.33 3.952 160 6692.09 40.53 3.944 161 6732.62 41.30 3.948 162 6773.92 41.42 3.954 163 6815.34 42.58 3.949 Joint Tally page 2 .. _. SONDEX CALIPER JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 BUTTRESS Wall thickness. Body: 0.271ins Upset = 0.271ins Nominal ID: 3.958 ins Joint Depth Length Measured Type No. ID feet feet inches 164 6857.92 41.69 3.952 , 165 6899.61 41.93 3.951 166 6941.54 41.70 3.945 167 6983.24 42.14 3.948 168 7025.38 42.24 3.947 169 7067.62 40.21 3.956 170 7107.83 42.41 3.947 171 7150.24 41.96 3.942 172 7192.20 42.54 3.959 173 7234.74 41.66 3.953 174 7276.40 41.53 3.950 175 7317.93 42.72 3.953 176 7360.65 41.64 3.955 177 7402.29 42.06 3.952 178 7444.35 42.14 3.948 179 7486.49 42.38 3.948 180 7528.87 41.59 3.952 , 181 7570.46 41.81 3.952 182 7612.27 42.16 3.946 183 7654.43 41.83 3.946 184 7696.26 38.67 3.944 185 7734.93 42.05 3.953 186 7776.98 41.31 3.954 187 7818.29 42.21 3.948 188 7860.50 42.06 3.945 189 7902.56 41.27 3.946 190 7943.83 40.38 3.944 191 7984.21 42.02 3.952 192 8026.23 41.43 3.952 193 8067.66 42.43 3.948 194 8110.09 41.18 3.961 195 8151.27 42.53 3.940 196 8193.80 41.53 3.943 197 8235.33 42.50 3.941 198 8277.83 40.91 3.946 199 8318.74 42.07 3.955 200 8360.81 41.76 3.947 201 8402.57 41.13 3.939 202 8443.70 41.06 3.943 202.1 8484.76 6.34 3.951 Pul:) 202.2 8491.10 12.92 nominal GLM 1 202.3 8504.02 7.73 3.952 Pup 203 8511.75 42.22 3.948 204 8553.97 41.82 3.952 Well: 02-35A Field: Prudhoe Bay Company: ARCO Alaska Country: USA Date: Sept. 4, 1999 Joint Depth Length Measured rype No. ID feet feet inches 204.1 8595.79 22.66 nominal PACKER 204.2 8618.45 8.89 3.935 Pul:) 204.3 8627.34 19.87 3.946 Pup 204.4 8647.21 1.73 nominal X-NIP 204.5 8648.94 16.18 3.943 Pup 204.6 8665.12 unknown 3.952 WLEG , ,,, , Joint Tally page 3 r-I I=t I I__1__ I IM 13 S Icc F:t U I 1-- cc S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 October 29, 1997 MWD Formation Evaluation Logs D.S. 2-35A, AK-MM-70170 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 D.S. 2-35A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22222-01 2" x 5" TVD Resistivity & CJamma Ray Logs: 50-029-22222-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia OCT $ 0 '!9~'? 5631 Silverado Way, Suite G · Anchorage, A/aska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 Ft I I--I--I IM G SEE Ft ~J I I::: ES S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~'1 / MWD Formation Evaluation Logs - D.S. 2-35A, AK-MM-70170 October 15, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by remming a signed copy of this transmittal letter to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22222-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA -.., ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well J~] Oil F-] Gas J~ Suspended E~J Abandoned J~ Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-96 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22222-01 4. Location of well at surface ' -':.~,-:F:r,~,~,..,~,,~¢_ ,i";:?i~"~,.,~ .~ i'~J:'O¢-~~:: ~ 9. Unit or Lease Name 863'SNL, 905'EWL, SEC. 36, T11N, R14E, UM [~~/~, !B. ~~.~ .' ?' Prudhoe Bay Unit At top of productive interval --- i 10. Well Number At total depth. .... 6. i 11. Field and Pool 3582' SNL, 3622' EWL, SEC. 36, T11N, R14E, UM Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 54.70I ADL 028308 12. Date Spudded I 13. Date T.D. Reached I 14. Date Comp., Susp., or Aband.tl 5. Water depth, if offshore 116. No. of Completions 6/8/97 6/13/97 6/18/97 N/A MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+-I-VD) 19. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 11630 9014 FT 11542 9009 FT J~Yes E~NoI (Nipple) 1997' MDI 1900' (Approx.) 122. Type Electric or Other Logs Run MWD, GR, 4-Phase RES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 11 )/ds Arctic Set 13-3/8" 68# L-80 38' 3476' 16" 2594 cuft CS II, 460 cu ft Class 'G' 9-5/8" 47# L-80 36' 8844' 12-1/4" 2375 cu ft Class 'G' 7" 29# L-80 8435' 8782' 8-1/2" 499 cu ft Class 'G' & 713 cu ft Class 'G' 4-1/2" 12.6# L-80 8677' 11630' 6" 365 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8669' 8605' M D TVD M D TVD 10020' - 11530' 8993' - 9008' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 75 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) June 28, 1997I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE ]GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL iGAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Zone 3 9070' 8678' Zone 2C 9203' 8747' Zone 2A 9536' 8914' Zone 1 9733' 8976' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hesignedre by certify th at ~e fo)/eg,~ /"/~ o~~ co rrect to the best of my kn owled ge~/~/ Dan Stoltz ~__~-d¢~,/~---/ -v -v~,) Title Senior Drilling Engineer Date 02-35A 97-96 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM ,5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. ~ 4: ~-~;~ ~ '?' ~-__i ~? Form 10-407 Rev. 07-01-80 Progress Report Facility PB DS 02 Well 02-35A Page 1 Rig Doyon 16 Date 27 August 97 Date/Time 30 May 97 05:00-06:00 06:00-15:00 15:00-15:30 15:30-18:00 18:00-20:30 20:30-21:30 21:30-23:00 23:00-01:00 31 May 97 01:00-02:30 02:30-06:00 06:00-07:00 07:00-08:30 08:30-10:30 10:30-11:00 11:00-14:00 14:00-15:30 15:30-16:00 16:00-17:00 17:00-22:00 22:00-02:30 01 Jun 97 02:30-04:00 04:00-04:30 04:30-06:00 06:00-08:30 08:30-10:30 10:30-11:30 11:30-12:30 12:30-13:30 13:30-14:00 14:00-15:00 15:00-15:30 15:30-16:00 16:00-16:30 16:30-17:00 17:00-17:30 17:30-20:30 20:30-23:00 23:00-01:00 02 Jun 97 01:00-04:00 04:00-06:00 06:00-07:30 07:30-10:00 10:00-11:00 11:00-12:00 12:00-15:00 15:00-18:30 18:30-21:00 21:00-21:30 21:30-22:00 22:00-22:30 22:30-00:00 03 Jun 97 00:00-02:00 02:00-02:30 02:30-06:00 Duration lhr 9 hr 1/2 hr 2-1/2 hr 2-1/2 hr lhr 1-1/2 hr 2 hr 1-1/2 hr 3-1/2 hr lhr 1-1/2 hr 2hr 1/2 hr 3 hr 1-1/2 hr 1/2 hr lhr 5hr 4-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 2 hr 1 hr 1 hr 1 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 3 hr 2-1/2 hr 2 hr 3hr 2 hr 1-1/2 hr 2-1/2 hr 1 hr 1 hr 3 hr 3-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 2hr 1/2 hr 3-1/2 hr Activity Rig moved 5.00 % Rig moved 85.00 % Held safety meeting Rig moved 95.00 % Rigged up Drillfloor / Derrick Installed Additional services Rig moved 100.00 % Fill pits with Seawater Retrieved Hanger plug Circulated at 9508.00 ft Circulated at 9508.00 ft Rigged up Logging/braided cable equipment Perforated from 8680.00 ft to 8682.00 ft Rigged down Wireline units Circulated at 8680.00 ft Circulated at 8680.00 ft Installed BOP test plug assembly Removed Xmas tree Rigged up BOP stack Tested BOP stack Retrieved BOP test plug assembly Rigged up Tubing handling equipment Pulled Tubing on retrieval string to 9508.00 ft Pulled Tubing on retrieval string to 9508.00 ft Rigged up Wireline units Conducted electric cable operations Rigged down Logging/braided cable equipment Rigged down BOP stack Functioned SCSSSV nipple assembly Rigged up BOP stack Retrieved Hanger plug Circulated at 8680.00 ft Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Prepared & tn:ed cutting charge at 9296.00 ft Pulled Tubing on retrieval string to 9296.00 ft Rigged up sub-surface equipment - Downhole tools Conducted electric cable operations Rigged up sub-surface equipment - Downhole measurement tools Conducted electric cable operations Conducted electric cable operations ~ ~ ~ !~ ~ ! ~'? i~ ~. ,~ Rigged down Wireline units ~_'~, ~ Rigged up Wireline units Conducted electric cable operations ~5:~ i... (-~ Conducted electric cable operations Prepared & fired cutting charge at 8810.00~,~,~.~_~ ~0ii.. ~3~, ~ Rigged down Wireline units Pulled Tubing on retrieval string to 25.00 ft Removed Tubing hanger Circulated at 8810.00 ft Laid down 2163.00 ft of Tubing Rigged down sub-surface equipment - SCSSSV nipple assembly Laid down 4950.00 ft of Tubing Facility Date/Time 04 Jun 97 05 Jun 97 06 Jun 97 07 Jun 97 PB DS 02 Progress Report Well 02-35A Page 2 Rig Doyon 16 Date 27 August 97 06:00-06:30 06:30-10:00 10:00-11:00 11:00-12:00 12:00-13:00 13:00-22:00 22:00-22:30 22:30-23:30 23:30-00:00 00:00-01:30 01:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-10:00 10:00-12:00 12:00-13:00 13:00-13:30 13:30-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-07:30 07:30-08:30 08:30-10:30 10:30-12:00 12:00-16:00 16:00-16:30 16:30-20:30 20:30-21:30 21:30-22:30 22:30-02:30 02:30-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-10:30 10:30-11:00 11:00-11:30 11:30-15:30 15:30-16:30 16:30-18:00 18:00-18:30 18:30-23:30 23:30-00:30 00:30-01:30 O1:30-06:00 06:00-10:30 10:30-12:30 12:30-13:00 13:00-14:00 14:00-16:30 Duration 1/2 hr 3-1/2 hr lhr 1 hr 1 hr 9 hr 1/2 hr lhr 1/2hr 1-1/2 hr 3 hr lhr 1/2 hr 1/2 hr lhr 1/2 hr 2hr 2hr 1 hr 1/2 hr 13-1/2 hr 1 hr lhr 1 hr 1-1/2 hr 1 hr 2 hr 1-1/2 hr 4 hr 1/2 hr 4 hr 1 hr lhr 4hr 2 hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 4 hr 1 hr 1-1/2 hr 1/2 hr 5hr 1 hr lhr 4-1/2 hr 4-1/2 hr 2hr 1/2 hr 1 hr 2-1/2 hr Activity Held safety meeting Laid down 8810.00 ft of Tubing Rigged down Tubing handling equipment Tested Bottom ram Rigged up sub-surface equipment - PBR dress mill Singled in drill pipe to 8368.00 ft Functioned PBR dress mill Circulated at 8417.00 ft Functioned Retrievable packer Rigged down BOP stack Installed Casing spool Rigged up BOP stack Tested BOP stack Rigged up BOP stack Tested BOP stack Functioned Retrievable packer Circulated at 8238.00 ft Pulled Drillpipe in stands to 24.00 ft Rigged up Casing handling equipment Held safety meeting Ran Casing to 8420.00 ft (7in OD) Rigged up High pressure lines Circulated at 8417.00 ft Mixed and pumped slurry - 126.000 bbl Functioned Liner hanger Rigged down Casing handling equipment Rigged down BOP stack Cut Casing at 0.00 ft Installed Casing spool Tested Casing spool Rigged up BOP stack Tested BOP stack Made up BHA no. 2 R.I.H. to 8340.00 ft Drilled cement to 8447.00 ft Washed to 8810.00 ft Held safety meeting Tested Casing Pulled out of hole to 291.00 ft Pulled BHA Rigged up Wireline units Set downhole equipment (wireline) Rigged down Wireline units Made up BHA no. 3 Held safety meeting R.I.H. to 8786.00 ft Functioned M.W.D. tool Circulated at 8782.00 ft Milled Casing at 8782.00 ft Milled Casing at 8811.00 ft Circulated at 8811.00 ft Laid down 672.00 ft of 3-1/2in OD drill pipe Serviced Block line Pulled out of hole to 391.00 ft Facility Date/Time 08 Jun 97 09 Jun 97 10 Jun 97 11 Jun 97 12 Jun 97 13 Jun 97 14 Jun 97 Progress Report PB DS 02 Well 02-35A Rig Doyon 16 Page 3 Date 27 August 97 16:30-17:30 17:30-20:30 20:30-21:00 21:00-00:00 00:00-06:00 06:00-06:00 06:00-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-09:00 09:00-10:30 10:30-11:00 11:00-14:00 14:00-14:30 14:30-17:00 17:00-18:00 18:00-18:30 18:30-21:30 21:30-22:30 22:30-06:00 06:00-06:30 06:30-15:00 15:00-15:15 15:15-18:00 18:00-18:30 18:30-22:00 22:00-23:30 23:30-23:45 23:45-00:30 00:30-00:45 00:45-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-10:00 10:00-10:15 10:15-11:00 11:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-13:30 13:30-15:00 15:00-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-18:45 18:45-03:30 03:30-05:30 05:30-06:00 06:00-06:30 06:30-10:00 Duration 1 hr 3 hr 1/2 hr 3 hr 6 hr 24 hr 21-1/2 hr 1/2 hr 2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 3hr 1/2 hr 2-1/2 hr 1 hr 1/2 hr 3hr 1 hr 7-1/2 hr 1/2hr 8-1/2 hr 1/4 hr 2-3/4 hr 1/2 hr 3-1/2 hr 1-1/2 hr 1/4 hr 3/4 hr 1/4 hr 3-1/4 hr lhr 1 hr 1/2 hr 3-1/2 hr 1/4 hr 3/4 hr 7 hr 1/2 hr 11-1/2 hr 1/2 hr 7 hr 1-1/2 hr lhr 1 hr 1 hr 1/2 hr 1/4 hr 8-3/4 hr 2hr 1/2 hr 1/2 hr 3-1/2 hr Activity Pulled BHA Made up BHA no. 4 Held safety meeting R.I.H. to 8811.00 ft Drilled to 8950.00 ft Drilled to 9540.00 ft Drilled to 10074.00 ft Circulated at 10074.00 ft Pulled out of hole to 7264.00 ft Held safety meeting Pulled out of hole to 192.00 ft Pulled BHA Retrieved B ore protector Tested BOP stack Installed Bore protector Made up BHA no. 5 R.I.H. to 3640.00 ft Held safety meeting R.I.H. to 9994.00 ft Reamed to 10074.00 ft Drilled to 10197.00 ft Held safety meeting Drilled to 10325.00 ft Held drill (H2S) Drilled to 10425.00 ft Held safety meeting Drilled to 10525.00 ft Circulated at 10525.00 ft Flow check Pulled out of hole to 8700.00 ft Held drill (Fire) Pulled out of hole to 0.00 ft Made up BHA no. 6 R.I.H. to 1000.00 ft Held safety meeting R.I.H. to 8780.00 ft Held drill (Kick while tripping) R.I.H. to 10525.00 ft Drilled to 10836.00 ft Held safety meeting Drilled to 11252.00 ft Held safety meeting Drilled to 11630.00 ft Circulated at 11630.00 ft Pulled out of hole to 8713.00 ft Serviced Block line R.I.H. to 8809.00 ft Held safety meeting Held drill (Kick while tripping) R.I.H. to 11630.00 ft Circulated at 11630.00 ft Pulled out of hole to 10500.00 ft Held safety meeting Laid down 2700.00 ft of 3-1/2in OD drill pipe Facility Date/Time 15 Jun 97 16 Jun 97 17 Jun 97 18 Jun 97 Progress Report PB DS 02 Well 02-35A Rig Doyon 16 Page 4 Date 27 August 97 10:00-12:00 12:00-12:15 12:15-18:00 18:00-18:30 18:30-23:00 23:00-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-10:00 10:00-11:30 11:30-12:00 12:00-13:30 13:30-15:00 15:00-16:00 16:00-17:30 17:30-18:00 18:00-18:30 18:30-21:30 21:30-22:00 22:00-00:30 00:30-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-09:00 09:00-09:15 09:15-14:30 14:30-16:00 16:00-18:00 18:00-18:30 18:30-20:30 20:30-06:00 06:00-06:30 06:30-09:00 09:00-10:30 10:30-10:45 10:45-11:30 11:30-13:00 13:00-13:30 13:30-18:00 18:00-18:30 18:30-22:00 22:00-02:00 02:00-04:00 Duration 2 hr 1/4 hr 5-3/4 hr 1/2 hr 4-1/2 hr 5-1/2 hr 1/2 hr 1 hr 1/2 hr 1 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 1-1/2 hr 1/2 hr 1/2 hr 3hr 1/2 hr 2-1/2 hr 5-1/2 hr 1/2 hr 1/2 hr lhr lhr 1/4 hr 5-1/4 hr 1-1/2 hr 2 hr 1/2 hr 2 hr 9-1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 114 hr 3/4 hr 1-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 3-1/2 hr 4 hr 2hr Activity Downloaded MWD tool Held drill (H2S) Ran Liner to 2900.00 ft (4-1/2in OD) Held safety meeting Ran Tubing to 2841.00 ft (2-7/8in OD) Ran Liner in stands to 8811.00 ft Circulated at 8811.00 ft Ran Liner in stands to 10000.00 ft Held safety meeting Ran Liner in stands to 11630.00 ft Circulated at 11630.00 ft Mixed and pumped slurry - 65.000 bbl Held 4200.0 psi pressure on 0.000 bbl squeezed cement Circulated at 11530.00 ft Pulled Drillpipe in stands to 8663.00 ft Circulated at 8663.00 ft Pulled Drillpipe in stands to 0.00 ft Removed Drillstring handling equipment Held safety meeting Laid down 1380.00 ft of Tubing Tested Liner - Via annulus Rigged up sub-surface equipment - TCP Ran Drillpipe in stands to 10000.00 ft Held safety meeting Ran Drillpipe in stands to 11530.00 ft Perforated Circulated at 11525.00 ft Held drill (Fire) Laid down 8650.00 ft of 3-1/2in OD drill pipe Laid down 1500.00 ft of Tubing Laid down 600.00 ft of Tubing Held safety meeting Laid down 670.00 ft of Tubing Ran Tubing to 8000.00 ft (4-1/2in OD) Held safety meeting Ran Tubing to 8668.00 ft (4-1/2in OD) Installed SCSSSV control line Held drill (Spill) Circulated at 8668.00 ft Set Production packer at 8604.00 ft with 4000.0 psi Installed Accessories Rigged down BOP stack Held safety meeting Rigged up Surface tree Monitor wellbore pressures Rig moved 0.00 % spenn -sun O I::1 I I__1__ I /~J r~- S I:= F! ~J I C:: EE; August 27, 1997 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data 2-35A Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 2-35A MWD survey tie-in point at 8,695.45', window point at 8,794.00' and a projected survey at 11,630.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments AUG 27 1997 Aimlm Oil & Ga~ Co~s. C. ommi~ 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company S~ RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / 2- 35A 500292222201 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/27/97 DATE OF SURVEY: 061497 MWD SURVEY JOB NUMBER: AK-MM-70170 KELLY BUSHING ELEV. = 54.70 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 8694.45 8441.70 8387.00 8794.00 8510.71 8456.00 8825.87 8532.46 8477.76 8857.80 8553.98 8499.28 8889.87 8575.11 8520.41 COURS INCLN DG MN 45 30 46 43 47 9 48 8 49 25 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST S 36.30 E .00 828.34S 693.96E S 37.47 E 1.50 885.72S 737.03E S 39.10 E 3.96 903.99S 751.45E S 42.30 E 8.03 921.87S 766.84E S 44.50 E 6.52 939.39S 783.41E VERT. SECT. 1070.37 1140.81 1163.76 1187.17 1211.22 8921.59 8595.01 8540.31 8953.58 8613.85 8559.15 8985.54 8631.80 8577.10 9017.61 8649.32 8594.62 9049.23 8666.42 8611.72 52 54 56 57 57 51 57 42 4 28 S 46.00 E 11.45 956.77S 800.96E S 47.50 E 7.55 974.48S 819.78E S 47.70 E 5.50 992.30S 839.31E S 47.90 E 1.29 1010.35S 859.21E S 48.00 E 1.26 1028.16S 878.96E 1235.89 1261.72 1288.16 1315.02 1341.63 9081.33 8683.60 8628.90 9113.25 8700.45 8645.75 9145.29 8717.14 8662.44 9177.30 8733.71 8679.01 9209.55 8750.30 8695.60 57 47 58 29 58 42 58 57 59 5 S 47.06 E 2.67 1046.47S 898.96E S 45.56 E 4.55 1065.20S 918.56E S 44.58 E 2.70 1084.51S 937.92E S 45.15 E 1.71 1103.92S 957.24E S 45.68 E 1.47 1123.33S 976.93E 1368.74 1395.83 1423.15 1450.50 1478.13 9241.58 8766.81 8712.11 9273.75 8783.41 8728.71 9304.71 8799.33 8744.63 9336.88 8816.02 8761.32 9368.91 8832.77 8778.07 58 51 59 0 59 7 58 22 58 33 S 44.64 E 2.88 1142.69S 996.40E S 45.46 E 2.23 1162.15S 1015.90E S 45.09 E 1.11 1180.84S 1034.76E S 43.36 E 5.15 1200.55S 1053.95E S 42.66 E 1.95 1220.51S 1072.57E 1505.55 1533.07 1559.60 1587.04 1614.24 9400.92 8849.38 8794.68 9432.90 8865.79 8811.08 9464.94 8881.55 8826.85 9496.83 8896.35 8841.65 9528.53 8910.60 8855.90 58 55 59 20 61 41 63 1 63 32 S 43.44 E 2.37 1240.50S 1091.25E S 44.18 E 2.38 1260.31S 1110.25E S 42.37 E 8.83 1280.62S 1129.36E S 44.68 E 7.67 1301.10S 1148.82E S 44.32 E 1.90 1321.29S 1168.66E 1641.51 1668.89 1696.69 1724.85 1753.12 9560.50 8924.13 8869.43 9592.45 8936.17 8881.47 9624.58 8946.99 8892.29 9656.19 8956.67 8901.97 9688.20 8965.58 8910.88 66 22 69 19 71 18 73 2 74 37 S 45.66 E 9.66 1341.77S 1189.14E S 44.52 E 9.81 1362.66S 1210.09E S 45.88 E 7.31 1383.97S 1231.56E S 44.96 E 6.16 1405.09S 1252.99E S 46.21 E 6.20 1426.60S 1274.94E 1782.04 1811.60 1841.81 1871.87 1902.59 9720.42 8973.54 8918.84 9751.99 8980.48 8925.78 9783.94 8986.20 8931.50 9815.94 8989.79 8935.09 9847.87 8991.19 8936.49 76 77 81 85 89 47 47 35 31 26 S 46.66 E 6.87 1448.12S 1297.56E S 47.42 E 3.94 1469.10S 1320.10E S 48.07 E 12.06 1490.24S 1343.36E S 48.70 E 12.44 1511.35S 1367.13E S 49.85 E 12.82 1532.16S 1391.30E 1933.79 1964.59 1996.01 2027.80 2059.69 ORIGINAL S~ ~RRY-SUN DRILLING SERVICES A/qCHORAGE ALASKA PAGE SHARED SERVICES DRILLING / 2-3SA 500292222201 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/27/97 DATE OF SURVEY: 061497 MWD SURVEY JOB NUMBER: AK-MM-70170 KELLY BUSHING ELEV. = 54.70 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS DIRECTION DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 9880.01 8991.09 8936.39 9911.86 8990.83 8936.13 9943.94 8990.98 8936.28 9976.12 8991.59 8936.89 10008.08 8992.86 8938.16 90 55 S 50.27 E 4. 90 1 S 49.95 E 2. 89 25 S 48.26 E 5. 88 24 S 48.78 E 3. 87 3 S 49.32 E 4. 76 1552.79S 1415.94E 2091.80 97 1573.21S 1440.38E 2123.62 60 1594.21S 1464.62E 2155.69 56 1615.52S 1488.73E 2187.86 55 1636.45S 1512.84E 2219.79 10040 10072 10104 10136 10168 56 8994.39 8939.69 .84 8995.61 8940.91 41 8996.88 8942.18 .42 8998.67 8943.97 54 9000.76 8946.06 87 34 88 5 87 17 86 18 86 14 S 53.60 E 13. S 53.44 E 1. S 54.10 E 3. S 52.73 E 5. S 53.62 E 2. 26 1656.66S 1538.21E 2252.16 69 1675.84S 1564.15E 2284.26 28 1694.48S 1589.60E 2315.63 26 1713.53S 1615.26E 2347.44 77 1732.74S 1640.91E 2379.35 10200 10232 10264 10296 10328 44 9002.85 .50 9004.71 54 9005.95 .54 9006.58 58 9007.05 8948.15 8950.01 8951.25 8951.88 8952 35 86 13 87 8 88 25 89 17 89 2 S 53.04 E S 52.12 E S 51.32 E S 50.66 E S 50.83 E 1.82 1751.75S 1666.44E 2411.04 4.05 1771.19S 1691.86E 2442.93 4.74 1791.03S 1716.99E 2474.87 3.39 1811.16S 1741.85E 2506.82 .94 1831.44S 1766.66E 2538.81 10361.87 9007.77 10392.83 9008.65 10424.89 9009.64 10456.87 9010.38 10487.98 9010.57 8953 07 8953.95 8954 94 8955.68 8955 87 88 29 88 14 88 14 89 6 90 10 S 50.83 E 1.65 S 50.41 E 1.58 S 50.61 E .63 S 50.22 E 2.98 S 46.80 E 11.52 1852.46S 1792o46E 2572.05 1872.09S 1816.38E 2602.96 1892.47S 1841.11E 2634.97 1912.84S 1865.75E 2666.91 1933.45S 1889.05E 2698.01 10520.71 9010.58 10552.76 9009.89 10584.80 9008.59 10616.85 9007.57 10648.96 9006.73 8955 88 8955.19 8953 89 8952.87 8952.03 89 47 92 40 91 58 91 39 91 20 S 46.88 S 47.51 S 47.80 S 47.88 S 47.80 1.21 1955.84S 1912.92E 2730.73 9.23 1977.61S 1936.43E 2762.77 2.39 1999.17S 1960.09E 2794.78 1.00 2020.67S 1983.84E 2826.82 1.00 2042.22S 2007.63E 2858.92 10680.92 9006.09 10712.98 9005.66 10743.92 9005.18 10775.94 9004.23 10807.99 9003.20 8951.39 8950.96 8950.48 8949.53 8948.50 90 90 91 92 91 56 34 11 12 26 S 47.00 S 47.31 S 47.17 S 48.01 S 49.00 o 1. 2. 4. 3. 80 2063.85S 2031.15E 2890.87 51 2085.65S 2054.65E 2922.92 05 2106.65S 2077.37E 2953.86 10 2128.23S 2101.00E 2985.86 89 2149.46S 2124.99E 3017.89 10840.14 10872.05 10904.05 10936.01 10968.26 9002.52 9002.01 9001.57 9001.42 9002.08 8947.82 8947.31 8946.87 8946.72 8947.38 90 9O 9O 89 87 58 51 42 49 50 S 47.28 S 47.41 S 46.53 S 46.63 S 46.57 5.54 2170.90S 2148.93E 3050.03 .55 2192.52S 2172.39E 3081.93 2.79 2214.35S 2195.78E 3113.93 2.80 2236.32S 2218.99E 3145.88 6.14 2258.47S 2242.42E 3178.11 S' 'RRY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU / 2-35A 500292222201 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/27/97 DATE OF SURVEY: 061497 MWD SURVEY JOB NUMBER: AK-MM-70170 KELLY BUSHING ELEV. = 54.70 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11000.31 9003.59 8948.89 86 46 S 45.80 E 4.11 2280.64S 2265.51E 11032.41 9005.47 8950.77 86 31 S 46.21 E 1.49 2302.89S 2288.57E 11064.40 9007.12 8952.42 87 34 S 45.56 E 3.86 2325.13S 2311.50E 11096.44 9008.23 8953.53 88 27 S 46.27 E 3.55 2347.41S 2334.50E 11128.24 9008.96 8954.26 88 53 S 46.31 E 1.36 2369.38S 2357.48E 3210.11 3242.13 3274.06 3306.06 3337.84 11160.29 9009.46 8954.76 89 19 S 45.91 E 1.83 2391.59S 2380.58E 11192.34 9009.36 8954.66 91 3 S 45.70 E 5.44 2413.93S 2403.55E 11224.07 9008.46 8953.76 92 11 S 46.05 E 3.76 2436.01S 2426.32E 11254.92 9007.36 8952.66 91 54 S 46.39 E 1.43 2457.34S 2448.58E 11286.97 9006.26 8951.56 92 1 S 46.53 E .58 2479.41S 2471.80E 3369.87 3401.90 3433.60 3464.41 3496.43 11319.06 9005.12 8950.42 92 1 S 46.71 E .56 2501.44S 2495.11E 11351.19 9004.38 8949.68 90 37 S 46.91 E 4.40 2523.42S 2518.53E 11383.20 9004.34 8949.64 89 32 S 46.25 E 3.95 2545.42S 2541.77E 11415.21 9004.64 8949.94 89 23 S 45.61 E 2.05 2567.68S 2564.77E 11446.10 9005.23 8950.53 88 24 S 46.35 E 4.00 2589.14S 2586.98E 3528.50 3560.61 3592.61 3624.60 3655.47 11478.10 9006.19 8951.49 88 9 S 45.16 E 3.80 2611.46S 2609.89E 11510.17 9007.37 8952.67 87 39 S 45.06 E 1.59 2634.08S 2632.59E 11542.37 9008.86 8954.16 87 2 S 44.71 E 2.18 2656.87S 2655.29E 11567.15 9010.19 8955.49 86 48 S 45.00 E 1.52 2674.41S 2672.75E 11630.00 9013.70 8959.00 86 48 S 45.00 E .00 2718.78S 2717.12E 3687.43 3719.44 3751.56 3776.27 3838.95 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3843.76 FEET AT SOUTH 44 DEG. 58 MIN. EAST AT MD = 11630 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 132.15 DEG. TIE-IN SURVEY AT 8,694.45' MD BOTTOM OF WHIPSTOCK AT 8,794.00' MD PROJECTED SURVEY AT 11,630.00' MD Sr 'RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU / 2-3SA 500292222201 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/27/97 DATE OF SURVEY: 061497 JOB NUMBER: AK-MM-70170 KELLY BUSHING ELEV. = 54.70 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8694.45 8441.70 8387.00 9694.45 8967.24 8912.54 10694.45 9005.86 8951.16 11630.00 9013.70 8959.00 828.34 S 693.96 E 252.75 1430.78 S 1279.29 E 727.21 474.46 2073.07 S 2041.04 E 1688.59 961.38 2718.78 S 2717.12 E 2616.30 927.71 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING p~u / 2-35A 500292222201 NORTH SLOPE BOROUGH COMPUTATI ON DATE: 8 / 27 / 97 DATE OF SURVEY: 061497 JOB NIIMBER: AK-MM-70170 KELLY BUSHING ELEV. = 54.70 FT. OPER3tTOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTA/qGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8694.45 8441.70 8387.00 828.34 S 693.96 E 252.75 8713.00 8454.70 8400.00 839.00 S 701.79 E 258.30 5.55 8858.89 8554.70 8500.00 922.47 S 767.39 E 304.19 45.89 9027.51 8654.70 8600.00 1015.92 S 865.38 E 372.81 68.63 9218.10 8754.70 8700.00 1128.47 S 982.16 E 463.40 90.58 9411.23 8854.70 8800.00 1246.92 S 1097.32 E 556.53 93.14 9649.58 8954.70 8900.00 1400.64 S 1248.51 E 694.88 138.35 11630.00 9013.70 8959.00 2718.78 S 2717.12 E 2616.30 1921.42 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS MEMORANDUM TO: David John~, Chairmaf¢'~ THRU: Blair Wondzell, P. I. Su pe rv~)r~._~~. FROM: Bobby Foster, ~(¢~ -,~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 10, 1997 FILE NO: AEIIFJEE.doc SUBJECT: BOPE Test - Doyon 16 ARCO - PBU - DS 2-35A PTD # 97-0096 Prudhoe Bay Field Friday, December 6, 1996: I traveled this date to ARCO's PBU well D~-35A to witness the upcoming BOPE test. I arrived at the rig at 7:30 AM and stoodby until 10:30 AM when the test started. As the attached AOGCC BOPE Test Report shows everything tested OK. The rig was clean and all equipment seemed to be in good working order. The location was clean and all equipment stored properly. Summary: I witnessed the BOPE test on Doyon 16 drilling ARCO's PBU well DS 2- 35A. Doyon rig 16 - 6/10/97 - test time 2,5 hours - no failures. Attachment: AEIIFJEE.XLS X Unclassified Confidential (Unclassified if doc. removed ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial X Workover: DO YON Rig No. ARCO DS 2-35A Set @ 8, 782' Weekly X Other 16 PTD # Rep.: Rig Rep.: Location: Sec. DATE: 6/10/97 97-0096 Rig Ph.# 659-4610 M. JACKSON BOBBY INGRAM 36 T. 11N R. 14E Meridian Urn. MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign OK Drl. Rig OK Hazard Sec. YES BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I P 250/3,000 I 250/5,000 P I 250/5,000 P I 250/5000 P I 250/5000 P 2 250/5000 P I 250/5,000 P N/A MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/5,000 P 250/5,000 P 250/5,000 P 250/5,000 P CHOKE MANIFOLD: No. Valves 14 No. Flanges 36 Manual Chokes 1 Hydraulic Chokes Test Pressure P/F 250/5,000 P 250/5000 Funcb'oned Func'b'oned P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2000 3,000 I P 1,750 P minutes 27 sec. minutes 36 sec. YES Remote: YES Psig. Numberof Failures: 0 ,Test Time: 2.5 Hou-"~, N~lve~ 2~"R~eme'~Fa~ IEquipment will be made within' 0 d'~. Notify the Inspector and follow with ~-'~nt~en or Faxed verification to Ithe AOGCC Commission Office ati Fa~. - 276-7542 Inspector North Slope Pager No, 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: GOOD TEST. Distribution: odg-Well File c- Oper./Rig c - Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER F1-021L (Rev. 12/94) AEIIFJEE.XLS TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 21. 1997 Dan Stoltz Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Prudhoe Bav Unit 02-35A ARCO Alaska Inc. Permit No. 97-96 Sur. Loc. 863'SNL, 905'EWL. Sec. 36. T11N, R14E, Btmnhole Loc. 1729'NSL, 1640'WEL. Sec. 36, T11N, R14E, UM Dear Mr. Stoltz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Johnston Chairman BY ORDER OF THE COMMISSION dlffEnclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AL/-L _-,<A OIL AND GAS CONSERVATION-- OMMISSION PERMIT TO DRILL 20 AAC 25.005 'la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RKB = 54.45' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028308 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 863' SNL, 905' EWL, SEC. 36, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 2828' NSL, 2921' WEL, SEC. 36, T11N, R14E, UM 02-35A At total depth 9. Approximate spud date Amount $200,000.00 1729' NSL, 1640' WEL, SEC. 36, T11N, R14E, UM 05/28/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028326, 1640'I No Close Approach 2560 11630' MD / 8960' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9185' MD Maximum Hole Angle 90° Maximum surface 3300 psig, Attotal depth O-VD) 8800' / 3420 psig 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) 6" 4-1/2" 12.6# L-80 IBT-Mod 2595' 9035' 8602' 11630' 8960' 284 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10768 feet Plugs (measured) Fill at 10750' MD (04/05/9~.AY 1 91997 true vertical 9013 feet Effective depth: measured 10750 feet Junk (measured) true vertical 9015 feet .... Casing Length Size Cemented M D TVD Structural Conductor 110' 20" 11 yards AS 110' 110' Surface 3422' 13-3/8" 2594 cuft CS II, 460 cu ft Class 'G' 3490' 3490' Intermediate 8692' 9-5/8" 1742 cuft Class 'G', 633 cuft Class 'G' 8760' 8491' Production Liner 912' 7" 499 cuft Class 'G' 10122' 9030' ORI¢INAL Perforation depth: measured Slotted Interval: 10125' - 10722'; Add Perfs: 9820' - 9840', 9875' - 9895', 9895' - 9935' true vertical Slotted Interval: 9030'-9017'; Add Perfs: 8995' 8999', 9005'-9009', 9009'-9015' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Chris Brown, 564-5582 Prepared By Name/Number: Terrie Hubble, 564-4628 21.1 hereby certify that the"f(~regoing i~ tr~e ay/rd, correct to the best of my knowledge Signed Dan Stoltz 4~ .- ~.,,~ ~] ~-'~/'~ Title Senior Drilling Engineer Date ,.~//~/~ 7 Commission Use Only Permit Number APl Number Approval Date I See cover letter ¢,/~- ~'~' 50- O.2__ ? - ~ 2.~ :~ 2~ 2.__ -- O / ,.~-~-' c~/-' ~' ~I for other requirements Conditions of Approval: Samples Required []Yes I~ No Mud Log Required []Yes .~ No Hydrogen Sulfide Measures ~Yes [] No Directional Survey Required ~Yes[-'] No Required Working Pressure for BOPE []2M; 1--13M; .[]5M; [--I10M; I--I15M Other: Original Signed By by order of - Approved By 1~2vid W .Inhne~n Commissioner the commission Date 7//' Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: IDS 2-35A Sidetrack Plan Summary IType of Redrill (producer or injector): [ Shut in Producer Surface Location: 863' FNL, 905' FWL, S36, T1 IN, R14E, UM Target Location: 2828' FSL, 2921' FEL, S36, T1 iN, R14E, UM Bottom Hole Location: 1729' FSL, 1640' FEL, S36, T11N, R14E, UM I AFE Number: 14J0344 I Estimated StartDate: 15/28/97 ling: I Doyon 16 I MD: [11,630' I I TVD: Well Design (conventional, slimhole, etc.): Operating days to complete: 119 18,960ss I lm~ 154.45' Conventional horizontal sidetrack I Objective: I Access expected 1,089MSTB of reserves west of the existing wellbore Mud Pro~ram Drilling Fluid~ 18.8 ppg QUIKDRILn (solids free) Density LSRV PV Chlor. pH Lubetex Biocide K:N SOLIDS ppg C.P.G. (CP) mg/L Concen. Ratio (%) 8.6 45,000 6 27,000 8.5 1.0% +100 ppm 2.4 <1.0% to to to to to to to to to 8.8+ 55,000 10 27,000 9.0 3.0% +100 ppm 1 <1.0% Directional KOP: +_9,185'MD (estimated) Maximum Hole Angle: Close Approach Well: +_90° None Formation Markers Formation Tops MD TVD (SS) 9,185' 8,696' Window kick off point Top Zone 2B 9,269' 8,743' Top Zone 2A 9,516' 8,855' Top Zone lB 9,652' 8,905' BOT 9,942' 8,950' Beginning of target polygon TD 11,630' 8,960' End of target polygon - 4-1/2" liner point DS 2-35A ST Drining Permit Page 2/4 Casing/Tubing Program Hole size Csg WtfFt Grade Conn Length Top Btm MD/TVDss MD/TVDss 6" 4.5" 12.6 L-80 IBT-MOD 2,595' 9,035'/8,602' 11,630'/8,960' Cement Lead Cement Tail Cement Casing/Liner Sx / Wt / Yield Sx / Wt / Yield Comments 4-1/2" None 284/15.7/1.19 Class G: 30% excess; TOC at 200' above liner top; Pump time = 4+ hfs; Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as listed. Logging Program ILogs: 6" Hole Cased Hole: MWD GR/4 phase RES to TD None planned Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Hazards Sadlerochit pressure is +3,420 psi at 8,800' TVDss or +7.43 ppg EMW. The leak in the 9-5/8" will be repair_ed prior, to sidetracking to avoid encountering Cretaceous overpressure when drilling this well. Pore pressure in the target interval is 7.43ppg EMW. The target polygon is bounded by faults to the south and east. Apparent dip should be close to 20 since the wellpath is planned diagonally along the estimated dip. A 20' upthrown fault is possible near the end of the wellpath. DS 2 is not a designated H2S pad; the last sample taken was <10ppm (9/96) DS 2-35A ST Dririing Permit Page 3/4 Operational Summary Pre-Rig Work: 1. R/U slickline and drift tubing down to production packer. Note: Production packer is at 9,817' MD at 79.4° inclination, and deepest wireline depth attained recently was 9,690'. Notify eps brig Engineer of deepest depth attained by wireline drift. 2. Test tubing/annulus to 3,500psi if not recently tested. 3. P+A existing open perforations (desired TOC at +9,700' MD, minimum for AOGCC compliance is 9,720' MD). 4. R/U electric line and chemical cut 3-1/2" tubing as deep as possible above packer. Notify eps brig Engineer if chemical cut is unsuccessful, or a jet cut becomes necessary. 5. Circulate well to clean seawater if circulation can be established. If circulation is not possible, top fill the well with seawater. Freeze protect to _+2,200' MD. 6. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar Rig Work: 1. Test 9-5/8" packoff to 3,500psi (emergency slips), and function lock down screws. 2.MIRU. Circulate well with 8.5 ppg seawater. Set and test BPV. ND tree. Set BOP blanking plug and NU BOP's. Test same. Pull BOP blanking plug and BPV. 3. Pull 4-1/2" x 3-1/2" tubing from chemical cut made in pre-rig. Replace 9-5/8" packoff if necessary while pulling tubing. 4.M/U and RIH with RTTS packer. Test casing from tubing stump upwards, and locate position of 9-5/8" leak (suspected at 5,717' MD). 5.RIH and dress existing 7" liner top. M/U and run 7" tieback liner from existing 7" liner top at 8,425' MD to 150' above identified ca.s, ing leak. Cement liner in place. 6. M/U and RIH with whipstock electric line. M/U 6" drilling assembly and kick off sidetrack at whipstock. Directionally drill as per plan to TD of section at _+11,630' MD. 7. Run DPC open hole logs to TD (contingency if MWD passes unacceptable). 8.M/U and run 4-1/2" liner to TD'and hang off in 7" casing. Cement liner in place and cleanout if necessary. DS 2-35A ST Dri'hmg Permit ..... Page 4/4 9. RIH and perforate liner. M/U and run 4-1/2" L80 completion with 3 (3LM's to _+9,100' MD (RP shear in top GLM). Shear RP valve in uppermost GLM. 10. Set BPV and test from below. N/D BOP's. N/U tree. Set tree test plug and test tree. Pull test plug and BPV. Circulate and freeze protect well. 11. Set BPV and RDMO. Shared Services Drillingt Structure: PB DS 02 Well: 02-35A Field ' Prudhoe Bay Location: Alaska Easf -> 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 5400 -800 , -- -1000- -1200~ -- -1400- -- A -16oo- -1800- (- _ k_ -2000- O - Z -2200- -- -2400- © o -2600- 0 - '' -2800- 0 ~ - o ~ -3000, I I I I I I I I I .1 I I I I I I TARGET DAITA MD Inc Dir TVD North I~ozt -- Nome .... P~il. lon -- 11630 89.66 130.59 9014 -2688 2736 02-3~ ~erg2690456,5947722 99~2 89.66 130.59 900¢ -1588 145~ 02-3~BTor9 689147,5948788 PRELIMINARY r02-$5A Wp4 ] , -800 -- --1000 -- --1200 -- --1400 --1600 A --1800 --2000 O -- --2200 -- --2400 -- --2600 --2800 '' o - -3000 o 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 ~400 Scole 1 ' 200.00 East -> I02-35A Wp4I 7800 - -- 8000 - -- 8200 - 8400 - 8600 8800 9000 - 9200 - 9400 - -- 9600 1000 1200 1400 1600 Scale1 ;200.00 Shared Services Drilling Structure ' PB DS 02 Field ' Prudhoe Bay Well' 02-35A Location ' Alaska WELL PROFILE DATA .... Point .... MD Inc Dir 'R/D North EastDLS (deg/lOOft) Tieon 918555.40 141.23 8751 -1130 924 0.00 KOP 9203 55.00 140.00 8761 -114-2 934 6.00 End of Build 9456 66.15 128.10 8885 -1294 1092 6.00 End of Hold 9548 66.15 128.10 8922 -1345 1158 0.00 Target 9942 89.66 130.59 9004 -1588 14-54 6.00 Target 116,30 89.66 1,50.59 9014 -2686 2736 0.00 PRELIMINARY TD/4 1/2" Liner 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 Vertical Section on 130.69 azimuth with reference 0.00 S, 0.00 E from 35A 02-35A Wp4 Vertical Section RKB 130.69 54.45' MD Inc. Azi. TVDss TVDrkb Rect. Coordinates Northing 9185.00 55.40 141.23 8696.10 8750.55 1130.31s 9200.00 55.07 140.21 8704.65 8759.10 1139.84s 9203.07 55.00 140.00 8706.41 8760.86 1141.77s 9269.18 57.80 136.63 8743.00 8797.45 1182.86s 9300.00 59.14 135.13 8759.12 8813.57 1201.72s 9400.00 63.58 130.53 8807.06 8861.51 1261.29s 9456.34 66.15 128.10 8830.99 8885.44 1293.59s 9500.00 66.15 128.10 8848.65 8903.10 1318.23s 9515.71 66.15 128.10 8855.00 8909.45 1327.10s 9547.89 66.15 128.10 8868.01 8922.46 1345.25s 9600.00 69.26 128.46 8887.78 8942.23 1375.12s 9652.41 72.38 128.81 8905.00 8959.45 1406.02s 9700.00 75.22 129.12 8918.27 8972.72 1434.76s 9800.00 81.19 129.74 8938.70 8993.15' 1496.90s 9900.00 87.16 130.34 8948.84 9003.29 1560.87s 9941.83 89.66 130.59 8950.00 9004.45 1588.00s 10000.00 89.66 130.59 8950.35 9004.80 1625.85s 10100.00 89.66 130.59 8950.94 9005.39 1690.90s 10200.00 89.66 130.59 8951.53 9005.98 1755.96s 10300.00 89.66 130.59 8952.12 9006.57 1821.02s 10400.00 89.66 130.59 8952.72 9007.17 1886.07s 10500.00 89.66 130.59 8953.31 9007.76 1951.13s 10600.00 89.66 130.59 8953.90 9008.35 2016.19s 10700.00 89.66 130.59 8954.50 9008.95 2081.25s 10800.00 89.66 130.59 8955.09 9009.54 2146.30s 10900.00 89.66 130.59 8955.68 9010.13 2211.36s 11000.00 89.66 130.59 8956.27 9010.72 2276.42s 11100.00 89.66 130.59 8956.86 9011.31 2341.48s 11200.00 , 89.66 130.59 8957.46 9011.91 2406.54s 11300.00 89.66 130.59 8958.05 9012.50 24:71.60s 11400.00 89.66 130.59 8958.64 9013.09 2536.66s 11500.00 89.66 130.59 8959.23 9013.68 2601.72s 11600.00 89.66 130.59 8959.82 9014.27 2666.77s 11630.11 89.66 130.59 8960.00 9014.45 2686.36s Easting 924.29e 932.09e 933~71 e 970.33e 988.62e 1053.00e 1092.46e 1123.87e 1135.18e 1158.34e 1196.18e 1234.84e 1270.37e 1345.94e 1422.08e 1453.89e 1498.06e 1574.01 e 1649.95e 1725.89e 1801.83e 1877.77e 1953.72e 2029.66e 2105.60e 2181.54e 2257.48e 2333.42e 2409.36e 2485.30e 2561.24e 2637.18e 2713.12e 2735.99e Grid Coordinates Easting Northing 688606.19. 5949232.33 688614.23 5949222.99 688615.89 5949221.10 688653.53 5949180.94 688672.28 5949162.54 688738.12 5949104.60 688778.37 5949073.29 688810.39 5949049.45 688821.91 5949040.87 688845.51 5949023.30 688884.08 5948994.38 688923.50 5948964.45 688959.73 5948936.62 689036.83 5948876.38 689114.52 5948814.33 689147.00 5948788.00 '689'192.~0 "5948751.27 689269.64 5948688.13 689347.17 5948624.99 689424.71 5948561.85 689502.24 5948498.71 689579.78 5948435.57 689657.31 5948372.43 689734.85 5948309.29 689812.38 5948246.15 689889.92 5948183.01 689967.45 5948119.87 690044.99 5948056.73 690122.52 5947993.58 690200.05 5947930.44 690277.59 5947867.30 690355.12 5947804.16 690432.65 5947741.01 690456.00 5947722.00 DLS deg/100ft 0.00 6.00 6.00 6.00 6.00 6.00 6.00 0.00 0.00 0.00 '6.00 6.00 6.00 6.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Ve~ical Section 1437.76 1449.89 1452.38 1506.94 1533.10 1620.75 1671.73 1711.62 1725.97 1755.36 1803.53 1852.99 1898.67 1996.49 2095.92 2137.73 2195.90 2295.90 2395.89 2495.89 2595.89 2695.89 2795.89 2895.89 2995.88 3095.88 3195.88 3295.88 3395.88 3495.87 3595.87 3695.87 3795.87 3825.98 Tie in point Comment Zone 2B Zone 2A Zone lB 02-35A BTarg TD / 4 1/2" Liner 5/9/97 11:08 AM Page 1 of I Well: 02-35 Spud Date: 10-25-91 Original RKBE: 68' top of Formation: 8780' ARCO Alaska, Inc. - Prudt~oe Bay API ~: 50-029-22222-00 Completion: 08-27-92 Hanger Type: FMC Gen IV Max Hole Angle: 94° @ MD: 10711' Annular Fluid: Inhib Crude/8.5 SW Reference Log: DGWD Date: 11-20-91 Tie In: Ann. Comm: LDL 05/24/96 Indicates leak in 9-5/8" @ 5717' ALL DEPTHS ARE RK]3 DRILLING MD TO TOP OF EQUIPMENT EXCEPT WHERE NOTED. Jewelry {J) Depth Description d-1 1 2163' 4-1/2" AVA SCSSV .Nipple ID=3.812" 2 2950' Crossover 4-1/2" x 3-1/2" 3 9285' 3-1/2" Parker S~N No-Go Nipple ID=2.75" 4 9817' 7" x 3-1/2" TIW Horizontal Packer 5 9860' 3-1/2" TIW Overshot Seal Ass_~_bly 6 9868' 4-1/2" Ported Joint (41.61'} J-2 bC-1 ID: 3-1/2" Parker SWN No-~o Nipple ID=2.75" Type: PRODUCER Status: Workover Hanger: 34' Angle @ TS:47° Angle @ TD:95° Date: 00-00-00 G-1 Casing and Tubing (C) Size Weight Grade 1 13-3/8" 68% L-BO 2 9-5/8" 47# L-80 3 7" 29~ L-80 4 4-1/2" 12.6% RD 4-1/2" 12.6# L-80 3-1/2" 9.2% L-80 Top Bottom Description 0' 3490' Casing 0' 8760' Casing 8425' 10122' Liner 9849' 10761' Liner-Slotted 0' 2950' BTC Tubing 2950' 9872' Tubing-IPC Gas Lift Information MD TVD Stn Mandrel Valve T1~e 3182' (3182') 1 CA-MMG ' CA RD 5482' (5481'} 2 CA-MMG' CA RD 7338' (7284') 3 CA-M~ CA RD 8280' (8136') 4 CA-MMG CA RD Latch Port TRO Date RK 05-21-96 RK 05-21-96 RK 08-27=92 RK 05-21-96 C-2 Perforation Data (EL~ DEPTHS} (P) Cret Gel SQZ (08123196) Interval Zone PT SPF Date Comments 3-3 J-4 J-5,6 C-3 9820- 9840 1 20 6 9849- 9875 lB 26 0 9875- 9895 lB 20 6 9895- 9915 lB 20 0 9915- 9935 lB 20 6' 9935-10761 lB 826 0 Not Arctic Packed Datum 8700' SS= 9205' MD 88.0.0' SS= 9397' MD PBTD=10716' TD=10769' 02-21-97' APERF 11-29-91 SLOTTED~ 02-21-97 RPERF 11-29-91 SLOTTED LINER 02-20-97 RPERF 11-29-91 SIXYITED I/NER Revision Date: 03-01-97 by CEE Reason: Adperfs Previous Reason: 09-21-96 Well 02-35 · k c-4 Well: 02-35 Spud Date: 10-25-91 Original RKBE: 68' Pop of Formation: 8780' ~%E_ - g,l~ ~TATL~ ARCO Alaska, Inc. - Prudhoe Bay API ~: 50-029-22222-00 Completion: 08-27-92 Hanger Type: FMC Gen IV Max Hole Angle: 94° @ MD: 10711' Annular Fluid: Inhib Crude/8.5 SW Reference Log:DGWD Date: 11-20-91 Tie In: Ann. Comm: LDL 05/24/96 Indicates leak in 9-5/8" @ 5717' ALL DEPTHS A/{E RKB DRILLING MD TO TOP OF EQUIPMENT EXCEPT WHERE NOTED. Jewelry (J) Depth Description J-1 1 2163' 4-1/2" AVA SCSSV Nipple ID:3.812" 2 2950' Crossover 4-1/2" x 3-1/2" 3 9285' 3-1/2" Parker SWN No-Go Nipple ID=-2.75" 4 9817' 7" x 3-1/2" TIW Horizontal Packer 5 9860' 3-1/2' TIW Overshot Seal Assembly 6 9868' 4-1/2' Ported Joint (41.61') J-2 ~C-1 ID: 3-1/2" Parker SWN No-~o NiDDle ID=2.75" Type: PRODUCER Status: Workover Hanger: 34' Angle @ TS:47° Angle @ TD:95° Date: 00-00-00 G-1 Casing and Tubing (C) Size Weight Grade 1 13-3/8" 68# L-80 2 9-5/8' 47# L-80 3 7" 29# L-80 4 4-1/2' 12.6~ RD 4-1/2" 12.6# L-80 3-1/2' 9.2~ L-80 ToD Bottom Description 0' 3490' Casing 0' 8760' Casing 8425' 10122' Liner 9849' 10761' Liner-Slotted 0' 2950' BTCTubing 2950' 9872' Tubing-IFC Gas Lift Information (G) MD TVD Stn Mandrel Valve TyDe 3182' (3182') 1 CA-MMG' CA RD 5482' (5481') 2 CA-~' CA RD 7338' (7284') 3 CA-M~ CA RD 8280' (8136') 4 CA-MMG CA RD C-2 Perforation Data (ELM DEPT~S) (P) Cret Gel SQZ (08/23/96) %~D' J-4 J-5,6 C-3 Interval Zone FT SPF 9820- 9840 1 20 6 9849- 9875 lB 26 0 9875- 9895 lB 20 6 9895- 9915 lB 20 0 9915- 9935 lB 20 6' 9935-10761 lB 826 0 Not Arctic Packed Datum 8700' SS= 9205' MD 8800' SS: 9397' MD PBTD=10716 ' TD--10769' Latch Port TRO Date RK 05-21-96 RK 05-2!-96 RK 08-27=92. RK 05-21-96 Date 02-21-97 APERF 11-29-91 SLOITEDLINER 02-21-97 RPERF 11-29-91 ~LINER 02-20-97 RPERF 11-29-91 SLUITEDLINER Re~on~ - 09-21296. ~?~n~ 19 ~997 Gas ~::s~ C-4 Original KB. ELEV = 68' DS 2-35A Proposed CompletionPad ELEV= 28.95' . SSSV @ +/-2,100' . 9-5/8", 47#/ft, ~ / I k L-80, BTRS@8,760' ' ~ i~~~ ' 7" x 4-1/2" packer at +/- 9000' 7" x 4-1/2" liner hanger -- - ~ ~ ~ +/- 9,035' i ~ ~ ~ 4-1/2", 12.6~, L80 IBT ~ MOD liner ~hi~;t;;k8;et for kickoff __ ~~ }TD ~ 11,360 Original 4-1/2" x 3-1/2" -- ~~~ ~o/~9~l~i~n tubing cut ~ ~~~ P+A cement to +/-9,450'~ ~ Cemented pedorations ~ 9,820'-9,840', DATE REV. BY COMME~S 5-13-97 ~B Sidetrack PRUDHOE BAy UNIT WELL:DS 2-35A APl NO: 50-029-222222r00 SEC 36; TN 11N; RGE 14E I STATE OF ALASKA ALASKA OIL ANB GAS CONSERVATION (, ...... MISSION APPLICATION FOR SUNDRY APPROVALS · -',~e Ol request: .. Alter casing _ Change approved program _ Abandon _X Sust:~e¢,o _ Operation ShutdOwn _ Repair well _ Pluggrx:.:J _X Time extension __ Pull tubing _ Va r~,rce _ Perforate _ Reenter susDencled wel _ ,.Slim ulate _ Other _ Name e! Operator: ARCO Alaska. Inc. ,,.~clres~: P.O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Devetoc,ment _X Exp~ory _ S~am~-a. p~ _ Service _ 4. ,,.:cati~ of well at suflace: 836' SNL, 905' EWL, Sec 36, T11N, R14E. UM .~ too pt productive interval: 1643' SNL. 1630' EWL, Sec 36, T11N, R14E, UM N. effe~,e depth: 2208' NSL, 1766' WEL, Sec 36, T11N, R14E, UM ..V. Iotal depth: 2173' NSL, 2457' WEL, Sec 36, T11N, R14E, UM 12_ .=rese~t well condition summa,'7 Total Depth: Effective Depth: Casing measured 10768 feet Plu~ (measured) true vertical 9013 feet measured 10750 feet Jur~ (measured) true vertical 9015 feet Length Size Cemented 6. Datum pt elavation (DF or KB feet): 68' RKB 7. Unit or Property: Prudhoe Bay Unit 8. Well number:. 2-35 9. Permit number: 91-127 !10. APl numar:. 50-029-222~ 11. Field/Pool: Prudhoe Bay Oil Pool Measured depth True vertical deCh 3onauc'tor Surface :roducruon '~ner P~"rOraticn Depth 110' 3422' 8692' 912' measurea flue vertical TuL-"ing (s~ze, grade, and measured dep~) 20" 11 Yds AS 110' 110' 13-3/8" 2594 cf CS II, 3490' 3490' & 460 cf Class G 9-5/8" 1742 cf Class G, 8760' 8491' & 633 cf Class G 7" 4,99 cf Class G 11122' 9030' 4-1/2" Slotted Liner: 9849 - 10761' 4-1/2" Slotted Liner: 9001 - 9014' ORI A 4-1/2", 12.6#, L-80, BTC Tbg @ 2950' MB; 3-1/2", 9.2#, L-80, IPCT @ 9872' MD. Pa::xers z,"~ SSSV (type and measure~ depth) 7" TIW Horz Packer @ 9817' MD: 4-1/2" AVA SCSSV @ 2163' MD. 13. Atta~ents Bes~iption summary of proposal _ X DC',a,ited operations program _ BOP sketch _ X Est~m~e~ date for commencing operation 115. Status of well classification as: Oil _X Gas _ Service April 30, 1997 16. If prc~a~ was verbally approved Name ~f a~prover Date approved 17. I herec, y certify that the forgoing is true and correct to the best of my knowledge. Suspende~ _ S~e~ ~ % _ ~ Title: EnCneering Supervisor FOR COMMISSION USE ONLY Ccnditior~ of approval: Notify Comiss~c~ so representitive may witness Plug integrety ~u.--"~' 8DP tes _t~-~ Location cearance _ Mechanical integrety test Subsequent form required 10- ,a:~,row~worderoftheCommis~iL~O~.O,..~... Oavid VV. JohrlStOrlcommissioner 10-403 Rev 06/15/88 Date SUBMIT IN TRIPLICATE H ! 08809 DATE I I INVOICE/C~EDITMEMO 1TYPE] 'HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. VENDOR S615201 ©0 ?i I :SC WELL PERMIT CHECKLISTco ,,NY FIELD FOO', INI CLASS GEOL AREA PROGRAM: expo dev~redrl~,;servO wellbore segO ann disp para reqO ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............ N 5. Well located proper distance from drlg unit boundary. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ............. N 10. Operator has appropriate bond in force ........ N 11. Permit can be issued without conservation order. . . ~ N 12. Permit can be issued without administrative approval N 13. Can permit be approved before 15-day wait ...... N ENGINEERING REMARKS 14. Conductor string provided ................ Y N~ , 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg. . Y N 17. CMT vol adequate to tie-in long string to surf csg. .~-%Y N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ....... , ..... ~Y~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ N 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... -'~~ 24. Drilling fluid program schematic & equip list adequate . Y~ N 25. BOPEs adequate ............... ~ ' ' 'i~ N 26. BOPE press rating adequate; test to ~ psig N 27. Choke manifold complies w/API RP-53 (May 84) ...... '~Y~ N /~g- ' / ~ ~" ' 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y // ~ 32. Seismic analysis of shallow gas zones .......... y N /~/~ ~ 33. Seabed condition survey (if off-shore) ........ ./ N / ~' 34. Contact name/phone for weekly progress reports . . . .//. Y N [exploratory onlyi ~ GEOLOGY: ENGINEERING: COMMI SS ION: BEW -- ~ . _ ~ Comments/Instructions: HOWIdlf- A:\FORMS\cheklist rev 01/97 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. Sperry-Sun Drilling Services LIS Scan Utility Hon Oct 13 09:17:14 1997 Reel Header Service name ............. LISTPE Date ..................... 97/10/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services MIC OF LMEg Tape Header Service name ............. LISTPE Date ..................... 97/10/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: OCT '1 5 a~-~s~,~. Oil & Gas C:o~m, DS 2-35~ 50029222220Z ~CO ~S~ ZNC. SPD~Y-SUN D~ZS~ZNG SD~VZCDS Z3-OCT-97 MWD RUN 2 MWD RUN 3 MWD RUN 4 AK-MM-70170 AK-MM-70170 AK-MM-70170 T. FLYNN T. FLYNN T. FLYNN M. JACKSON M. JACKSON D. HIEM JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: MWD RUN 4 AK-MM-70170 T. FLYNN D. HIEM 36 liN 14E 863 FWL: 905 ELEVATION (FT FROM MSL 0) KELLY BUSHING: 54.70 DERRICK FLOOR: 53.20 GROUND LEVEL: 29.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 7.000 8782.0 PRODUCTION STRING 6.000 11630.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL DEPTHS ARE MEASURED FROM TOP OF KELLY BUSHING UNLESS OTHERWISE NOTED. 3. ANNULAR AND CRITICAL VELOCITIES CALCULATED USING THE POWER LAW HYDRAULICS MODEL. 4. MWD RUN 1 IS DIRECTIONAL ONLY TO ORIENT THE WHIPSTOCK AND IS NOT PRESENTED. 5. MWD RUN 2 THROUGH 4 ARE DIRECTIONAL WITH DUAL GAM/~A RAY (DGR) UTILIZING GEIGER MUELLER TUBES DETECTOR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. A MEASURED AFTER DRILLING (MAD) PASS WAS PERFORMED FROM 8751'MD TO l1600.50'MD. THIS PASS CONSISTED OF DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 7. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN J. YOUNG OF ARCO ALASKA, INC. AND A. TURKER OF SPERRY-SUN ON 09/30/97. 8. MWD RUNS 1 THROUGH 4 REPRESENT WELL 2-35A WITH API#: 50-029-22222-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF ll,630'MD, 9014'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH THE EXTENSION "M" ARE MEASURED AFTER DRILLING (MAD) PASS. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/13 Maximum Physical Record..65535 Fil~e Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP $ START DEPTH STOP DEPTH 8765.0 11586.0 8772.0 11593.0 8772.0 11593.0 8772.0 11593.0 8772.0 11593.0 8811.0 11593.0 8813.0 11635.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 8811.0 10074.0 3 10074.0 10529.0 4 10529.0 11630.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 RPS MWD OHMM 4 1 68 8 3 RPD MWD OHN~4 4 1 68 12 4 RPX MWD OHM- 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 FET MWD HOUR 4 1 68 ROP MWD FT/H 4 1 68 24 28 Name Min Max Mean DEPT 8765 11635 10200 GR 14.2521 198.306 42.3963 RPS 0.1357 2000 26.178 RPD 0.4488 2000 58.3815 RPX 0.1271 2000 17.8713 RPM 0.2043 2000 37.9773 FET 0.5506 22.7682 1.94457 ROP 4.6936 2265.82 76.0802 Nsam 5741 5643 5643 5643 5643 5643 5565 5645 First Reading 8765 8765 8772 8772 8772 8772 8811 8813 Last Reading 11635 11586 11593 11593 11593 11593 11593 11635 First Reading For Entire File .......... 8765 Last Reading For Entire File ........... 11635 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 8750.0 11587.5 RPM 8750.0 11587.5 RPS 8750.0 11587.5 RPX 8750.0 11587.5 GR 8750.0 11581.0 RAT 8750.0 11600.5 FET 8811.5 11585.5 $ MERGED DATA SOURCE PBU TOOL CODE lV~D. REMARKS: MAD RUN NO. MAD PASS NO. 4 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD AAPI 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHM~ 4 1 68 FET MAD HOUR 4 1 68 MERGE TOP 8750.0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 MERGE BASE 1160O.5 Name DEPT RAT GR RPX RPS RPM RPD FET Min 8750 56 5445 12 0639 0 1436 0 0936 0 5281 0 1136 15.074 Max Mean Nsam 11600.5 10175.2 5702 1393.07 319.193 5702 197.602 44.3288 5663 2000 10.9491 5676 2000 15.3776 5676 2000 27.1515 5676 2000 40.1161 5676 137.339 71.561 5549 First Reading 8750 8750 8750 8750 8750 8750 8750 8811.5 Last Reading 11600.5 11600.5 11581 11587.5 11587.5 11587.5 11587.5 11585..5 First Reading For Entire File .......... 8750 Last Reading For Entire File ........... 11600.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Semvice name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8765.0 10027.0 RPD 8772.0 10034.0 RPM 8772.0 10034.0 RPS 8772.0 10034.0 RPX 8772.0 10034.0 FET 8811.0 10034.0 ROP 8813.0 10073.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03/DEP 2.042 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : 10-JUN-97 IGC 5.06 / IGC 4.88 DEPII 2.17f/SP4 MEMORY 10074.0 8811.0 10074.0 47.2 90.9 TOOL NUMBER P0743SP4 P0743SP4 6.000 6.0 QUIKDRIL-N 8.70 47.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.8 24500 8.4 .160 .091 · 150 .180 .6 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMS4 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 58.3 Name Min Max Mean Nsam DEPT 8765 10073 9419 2617 GR 16.5088 185.909 37.4326 2525 RPX 0.1271 2000 20.9698 2525 RPS 0.1357 2000 34.5523 2525 RPM 0.2043 2000 59.9232 2525 RPD 0.4488 2000 104.136 2525 ROP 4.6936 1126.76 58.8776 2521 FET 0.6002 3.4118 1.55357 2447 First Reading 8765 8765 8772 8772 8772 8772 8813 8811 Last Reading 10073 10027 10034 10034 10034 10034 10073 10034 First Reading For Entire File .......... 8765 Last Reading For Entire File ........... 10073 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/13 Maximum Physical Record..65535 File Type ................. LO Previous File Name ....... STSLIB.003 Cormment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10010.0 10480.5 FET 10016.5 10487.5 RPM 10016.5 10487.5 RPS 10016.5 10487.5 RPX 10016.5 10487.5 RPD 10017.5 10487.5 ROP 10059.0 10529.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03/DEP 2.042 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 Il-JUN-97 ISC 5.06 / ISC 4.88 DEPII 2.17f/SP4 MEMORY 10529.0 10074.0 10529.0 86.2 89.3 TOOL NUMBER P0675SP4 P0675SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.000 6.0 QUIKDRIL-N 8.80 54.0 9.0 24500 4.8 .150 .080 .140 .200 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAP I 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHlV~ 4 1 68 12 4 RPM MWD 3 OHM~ 4 1 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 ROP MWD 3 FT/H 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 60.9 First Name Min Max Mean Nsam Reading DEPT 10010 10529 10269.5 1039 10010 GR 28.5855 126.273 49.9922 942 10010 R?X 5.672 28.1821 13.6409 943 10016.5 RPS 6.8456 32.8728 17.9098 943 10016.5 Last Reading 10529 10480.5 10487.5 10487.5 R?M 8.413 32.2169 19.5156 RPD 10.9615 31.6437 21.0977 RO? 7.3563 2228.91 71.1308 FET 0.889 22.7682 4.64351 943 10016.5 10487.5 941 10017.5 10487.5 941 10059 10529 943 10016.5 10487.5 First Reading For Entire File .......... 10010 Last Reading For Entire File ........... 10529 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical.EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10457.0 11586.0 FET 10464.0 11593.0 RPD 10464.0 11593.0 RPM 10464.0 11593.0 RPS 10464.0 11593.0 RPX 10464.0 11593.0 ROP 10507.0 11635.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03/DE? 2.042 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): 13-JUN-97 ISC 5.06 / ISC 4.88 DEPII 2.17f/S?4 MEMORY 11630.0 10529.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINII~UM ANGLE: ~AXIMUM ~GLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): I~UD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 11630.0 86.5 92.7 TOOL NUMBER P0675SP4 P0675SP4 6.000 6.0 QU I KDRI L-N 8.80 48.0 8.9 22500 5.2 .160 .080 .140 .220 67.8 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAP I 4 1 68 4 2 RPX MWD 4 OHM}4 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMM 4 1 68 16 5 RPD MWD 4 OHMM 4 1 68 20 6 ROP MWD 4 FT/H 4 1 68 24 7 FET MWD 4 HOUR 4 1' 68 28 Name Min Max Mean DEPT 10457 11635 11046 GR 14.2521 198.306 45.2758 RPX 6.5697 42.8807 16.0442 RPS 8.9103 36.263 19.9953 RPM 9.939 33.9303 20.5139 RPD 12.1931 35.0628 21.4845 ROP 17.4682 2265.82 102.761 FET 0.5506 16.1093 1.82534 Nsam 2357 2259 2259 2259 2259 2259 2257 2259 First Reading 10457 10457 10464 10464 10464 10464 10507 10464 Last Reading 11635 11586 11593 11593 11593 11593 11635 11593 First Reading For Entire File .......... 10457 Last Reading For Entire File ........... 11635 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: FILE SUMYuARY VENDOR TOOL CODE START DEPTH RPD 8750.0 RPM 8750.0 RPS 8750.0 RPX 8750.0 GR 8750.0 RAT 8750.0 STOP DEPTH 11587.5 11587.5 11587.5 11587.5 11581.0 11600.5 FET $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03/DEP 2.042 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 881'1.5 11585.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 13-JUN-97 ISC 5.06 / ISC 4.88 DEPII 2.17f/SP4 MEMORY 11630.0 10529.0 11630.0 86.5 92.7 TOOL NUMBER P0675SP4 P0675SP4 6.000 6.0 QUIKDRIL-N 8.80 48.0 8.9 22500 5.2 .160 .080 .140 .220 67.8 .6 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT RAT GR RPX RPS RPM RPD FET Name Service Order Units Size Nsam Rep FT 4 1 68 IZ~AD 4 FT/H 4 1 68 MAD 4 AAPI 4 1 68 MAD 4 OHM- 4 1 68 MAD 4 OHM- 4 1 68 MAD 4 OHM- 4 1 68 MAD 4 OHM- 4 1 68 MAD 4 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 8750 11600.5 10175.2 5702 RAT 56.5445 . 1393.07 319.193 5702 GR 12.0639 197.602 44.3288 5663 RPX 0.1436 2000 10.9491 5676 RPS 0.0936 2000 15.3776 5676 RPM 0.5281 2000 27.1515 5676 RPD 0.1136 2000 40.1161 5676 FET 15.074 137.339 71.561 5549 First Reading 8750 8750 8750 8750 8750 8750 8750 8811.5 Last Reading 11600.5 11600.5 11581 11587.5 11587.5 11587.5 11587.5 11585.5 First Reading For Entire File .......... 8750 Last Reading For Entire File ........... 11600.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/10/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/10/13 Origin ................... STS Reel Name ................ UNKNOWN Scientific Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Technical Services Writing Library. Scientific Physical EOF Physical EOF End Of LIS File
