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Home My WebLink About198-263XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages:. '~.~_._~ Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA ~ Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Daretha a~Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: ~si 1 a. Well Status: DOil DGas D Plugged 181 Abandoned D Suspended 1 b. Well Class: ZOAAC 25.105 20AAC 25.110 181 Development D Exploratory DGINJ DWINJ D WDSPL DWAG D Other No. of Completions Zero D Service D Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or A~. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 91212007 .n? 198-263 - 307-263 3. Address: 6. Date Spudded (D-'" 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 01/20/1999 50-50-029·20582-01-00 ,- 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Suñace: 01/23/1999 PBU G-09A . 2664' FNL, 2367' FEL, SEC. 12, T11N, R13E, UM 8. KB (ft above MSL): 64.14' r 15. Field 1 Pool(s): Top of Productive Horizon: 690' FNL, 4136' FEL, SEC. 13, T11N, R13E, UM Ground (ft MSL): 35.4' Prudhoe Bay Field 1 Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool .- 2087' FNL, 4492' FEL, SEC. 13, T11N, R13E, UM 11407 8933 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Suñace: x- 657861 y- 5968977 Zone- ASP4 11476 . 8937 , ADL 028285. TPI: x- 656164 y- 5965635 Zone- ASP4 11. SSSV Depth (MD+ TVD) 17. Land Use Permit: Total Depth: x- 655837 5964231 Zone- ASP4 NIA y- 18. Directional Survey DYes 181 No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): (Submit electronic and orinted information oer 20 MC 25.050\ N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 MC 25.071): MWD, GR 22. CASING, LINER AND CEMENTING RECORD ,'?i? n.EE' .. <i' ,<'1'11'; BOtTOM", , vr J30TTOM 20" x 30" Suñace 110' I Suñace 110' 36" 8 cu vds Concrete 13-3Iß" 72# -80 Suñace 2672' Suñace 2672' 17-1/2" 3440 cu ft Arcticset 1/ 9-518" 47# -80 Suñace 9481' I Suñace 8392' 12-1/4" 1300 cu ft Class 'G' 7" 29# -80 8975' 9928' 7964' 8776' 8-1/2" 336 cu ft Class 'G' 2-7/8" 6.16# -80 9580' 11474' 8476' 9002' 3-3/4" 107 cu ft Class 'G' 23. Open to production or injection? DYes 181 No ....~ '" <;......< >.....;"" If Yes, list each interval open S,ZE DEPTH SET (MD) PACKER SET (MD) (MD+TVD ofTop & Bottom; Perforation Size and Number): None None MD TVD MD TVD 25;}.',".:/<;; ; "/h../ «< -- S0k.NNED NOV () 1 2007 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED - 9600' Set CIBP 9569' Set Whipstock 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: PRODUCTION FOR OIL-BBL: GAs-McF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD ... Flow Tubing Casing Press: CALCULATED OIL-BBL: GAs-McF: WATER-BBL: OIL GRAVITY-API (CORR): Press. 24-HoUR RATE+ 27. CORE DATA Conventional Core(s) Acquired? DYes 181 No Sidewall Core(s) ACQuired? [J Yes 181 No If Yes to either question, list formations and intervals cored (MD+ TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results er 20 MC 250.071. ~__~'.'"·.'''''_M_~''' COMPLETION ¡ None ¢!:JtP1- RBDMS 8Ft 00 .2 6 2D07 ¡a ~. RECE\Vl:.U . STATE OF ALASKA .,~þ~ ALASKA~IL AND GAS CONSERVATION COMIr'SSION OCT 2 2 2007 WELL COMPLETION OR RECOMPLETION REPORT AND L2~ka Oil & Gas Cons. Cnmmission Anchorage Form 10-407 Revised 0212007 0 RIG I N A rONTINUED ON REVERSE SIDE G 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN NAME Permafrost Top Permafrost Base ERS ENCOUNTERED): TVD 29. FORMATION TESTS Well Teste DYes 181 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 MC 25.071. None Sad Z2 (Kicked off in) 9919' 8768' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0(Jl.-- Signed( Sondra Stewman Title Drilling Technologist PBU G-09A Well Number 198-263 Date I D/t9/D 7 Prepared By Name/Number: Sondra Stewman, 564-4750 Drilling Engineer: Sean McLaughlin, 564-4387 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground Level elevation in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 MC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 MC 25.071. Form 10-407 Revised 02/2007 Submit Original Only Digital Well File Well: G-09 Well History Well G-09A G-09A G-09A G-09A G-09A G-09A G-09A G-09A G-09A G-09A Date 8/21/2007 8/24/2007 8/25/2007 8/25/2007 8/25/2007 8/26/2007 8/26/2007 8/26/2007 8/26/2007 8/27/2007 e Page I of. e Summary ····WELL SII ON ARRiVAL·..· DRIFT TO 9,800' SLM WITH 2.25 BLIND BOX. ( NOTE- MADE SEVERAL SLOW PASSES INTO LINER TOP @ 8,944' SLM NO TIGHT SPOTS OR PROBLEMS). "'LEFT WELL S/I"'PAD OP NOTIFIED TlI/O= 0+/18010+. Temp= SI. T&IA FL (Pre-CTD). TBG FL @ 432'? (10 bbls). IA FL @ 162' (8 bbls). "'CONTINUED FROM PREVIOUS DAY'" SET 2-7/8" CIBP AT 9600'. PRESSURE TESTED PLUG TO 3000 PSI. JET CUT 2-7/8" LINER AT 9575' (ABOUT 5' ABOVE THE EST. TOC) USING 2-1/8" SLB POWER CUTTER. WELL LEFT SHUT IN, TURNED OVER TO DSO. "'JOB COMPLETE'" T/I/O= 80120010. Assist E-line (CTD Prep) MIT-T to 3000 psi. 'FAILED' Pumped 40.9 bbls of 62' crude to achieve test pressure. lAP increased as the TP decreased. Bled gas off the IA. CMIT- Tx IA to 3000 psi. 'PASSED' Pumped another 8.1 bbls of 62' crude to achieve test pressure. TBG lost 60 psi & IA held I 1st 15 min. TBG lost 20 psi & IA held 12nd 15 min. Bled back to Final WHP= 140/460/60. Annulus casing valves are open and tagged. ····WELL SHUT IN ON ARRiVAL..·· MASTER VALVE CLOSED AND LOCKED UPON ARRIVAl. SET 2-7/8" CIBP AT 9600'. PRESSURE TESTED PLUG TO 3000 PSI. PLUG TESTED GOOD. '***CONTINUED ON 26-AUG-2007**** T/I/O=0+/140/0+. Temp=SI. Bleed WHPs to 0 psi (pre PPPOT, pre-CTD). Bled lAP to bleed tank from 140 psi to 10 psi in 2.75 hr. Final WHps=0+/1 010+. TlIAlOA= 01010 Temp=SI PPPOT-T (PASS) PPPOT-IC (PASS) (Pre CTD) PPPOT-T Alemite check not holding pressure, bled through slotted bleed screw to 0 psi. Replaced 1" Alemite. Cycled LDS "Standard" all moved no bent or broke pins. RU HP bleed tool onto THA flushed void until clean returns achieved. Pressured to 5000 psi for 30 min test, 49501 15 mins, 49501 30 mins. Bleed THA void to 0 psi RD test equipment, re-installed Alemite cap. PPPOT-IC Bleed IC void to 0 psi through slotted bleed screw, removed 1" NPT plug from test port could not remove internal check, installed 1" Alemite. Cycled all LDS "Standard" all moved no bent or broke pins. Pressured to 3500 psi for 30 min test, 34001 15 mins, 33501 30 mins. Bleed void to 0 psi, RD test equipment, removed Alemite re-installed 1" NPT plug "'CONTINUED FROM 25 AUG 07"* SET 2-7/8" BAKER CIBP AT 9600'. PRESSURE TESTED PLUG TO 3000 PSI. JET CUT 2-7/8" LINER AT 9575' (5' ABOVE THE EST. TOC) USING 2-1/8" SLB POWER CUTTER. WELL LEFT SHUT IN, TURNED OVER TO DSO. *** JOB COMPLETE*** T/I/O= 50/300/20 (POST JET CUT LINER) CMIT TxlA to 2000psi. (PASSED) TBG lost 160 psi & IA lost 60 psi in the 1st 15 min. On the 30 min. check TBG lost no pressure & IA lost no pressure. Pumped 7 bbls crude to achieve test pressure. Bleed pressures back. Bled TBG to 0 psi. Bled IA to 240 psi. DHD took control of well. Final WHP = 0/240/20 ANNULUS CASING VALVES TAGGED AND LEFT OPEN,WING SHUT AND TAGGED. T/I/O=5/45/0. SI. Bleed WHP's to 0 psi (pre-PPPOT, pre-RWO). Bled TBG from 5 to 0 psi in 5 minutes. Bled lAP from 45 psi to 0 psi in 6 hours. Fluid to gas at end of bleed. Monitored 30 minutes. lAP increased to 2 psi. Bled back to 0 psi În 30 seconds. Final WHP's=VAC/OIO http://digitalwellfi1e. bpweb. bp.comIWIInfo/Reports/ReportViewer.aspx 10/171200" Digital Well File G-09A G-09A G-09A G-09A 8/27/2007 8/28/2007 8/29/2007 8/30/2007 Print Date: 10/17/2007 e Page 2 of: e T/I/O=0/20/0. 51. Monitor WHP's, Bleed to 0 psi. (post-bleed, pre RWO). lAP increased 20 psi overnight. Bled lAP from 20 psi to 0 psi in 8 min, (all gas). Monitor whp's for 30 min. lAP increased 10 psi during monitor, TBG went on vac (TBG & IA FL out of balance). Rigged up 1/2" bleed hose & U-tube for 1 hr (No fluid @ surface). Monitor for 30 min. lAP increased to 1 psi. Final WHP's=0/01/0 TlI/O=02/34/0. Temp = 51. Monitor WHP's, bleed to 0 psi. (Pre-RWO). TP gained 2 psi, lAP gained 34 psi, OAP unchanged overnight. Bled TBG to 0 psi in 5 min. Bled lAP to 0 psi in 10 min. 51 bleed & monitor for 30 min. lAP gained 4 psi in 30 min. Re-bled lAP to 0 psi in 5 min. ***Note*** well support on location to rig down scaffolding. Final WHP's=O/O+/O T/I/O = ?/25/0+. Temp = 51. Monitor WHP's bleed if not 0 psi (pre- RWO). unable to get TBGP do to no scafold. lAP increased 25 psi overnight, OAP unchanged overnight. Bled lAP from 25 psi to 0 psi in 3 mins. Monitor for 30 mins. FWHP's :: ?/O+/O+ T/I/O = 0/30/2. Temp = SI. Monitor WHP's, bleed if not 0 psi (pre-RWO). lAP increased 30 psi overnight, OAP unchanged overnight. Bled lAP from 30 psi to 0 psi in 5 min. Monitor 15 min, final WHP's = 0/0+/0. Page 1 of 1 http://digitalwellfi1e.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 10/17/200 TREE '" I\!IcEVOY 6" SAfETY NOTES: e e Page 1 ofL þc¿M Maunder, Thomas E (DOA) From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Tuesday, September 04,20072:15 PM To: Maunder, Thomas E (OOA) M qy1{ Subject: RE: Confusing 404-again G \ ,--,ô"" Tom, The 10-40 for G-09A will be submitted by Terrie Hubble. I just talked to her and she pointed out that she submitted the 10-403 for G-09A and will follow up with the 10-407. So please disregard the 10-404 that was submitted. That still does not explain the faulty reporting of the API # and permit #. I am discarding the so called database that I thought was repaired and will complete the sundries manually, from now until I C~. be assured that the database has been repaired. . ~ Gory Preble \..\() L.\ ~(;.. S S "QCJ(c Petroleum Data Management Engineer ~ , '5 - <J l~("J ?1/'v? SAIC t:- ( 907-564-4944 preblegb@bp.com \~ <6-- a-ç, ~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] sent: Friday, August 31, 2007 9:35 AM To: Preble, Gary B (SAIe) Subject: RE: Confusing 404--again SCANNED SEP 07 7nn7 I almost forgot, it would also appear that the work you are reporting should have been reported on a 407 since you are abandoning. I did not dig into what was planned and compare it to what was accomplished. When the permit and API numbers didn't match and the other issues were identified, the possibly incorrect form fell way down the priority list. Tom --- -,~---_._~-------- From: Maunder, Thomas E (DOA) sent: Friday, August 31, 2007 9:32 AM To: Preble, Gary B (SAle) Subject: Confusing 404 Gary, I am examining a 404 we just received for G-09A. There are a number of items that need to be examined and a new 404 wi/llikely be needed. The issues on this 404 are beyond the issues discovered with other 404s we have messaged on in the past couple of weeks. In particular for this one, 1. The PTO given (176-048) is not for G-09A. 176-048 is for OS 09-06. 2. Oitto for the API number. Neither the PTO or the API # are close to that for G-09A (198-263). 3. The information in box 11 (casing, perfs, etc) looks to be scrambled. The first 4 lines of the casing detail and the first set of perforations (9207-9514) appear to be that of OS 09-06. Gary, I don't have time to dig through much more on this but it appears there is still a bust in your database. Like I said, in this case it appears to be more serious than the items discussed over the past few weeks. I look forward to hearing from you. Good luck. Tom Maunder, PE 9/4/2007 . ~V1ÆVŒ (ID~ &\~1Æ~æ&\ . AI,J\SIiA OIL AlO) GAS CONSERVATION COMMISSION SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean Mclaughlin CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 \ql{¡ ~ <q1?J Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-09A Sundry Number: 307-263 SCANNED AUG 1 42007 Dear Mr. Mclaughlin: 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. When providing 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 me 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. an DATED this §day of August, 2007 Enc!. . 1. Type of Request: 181 Abandon o Suspend o Operation Shutdown o Perforate o Time Extension v ... 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 Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Developm~nt D Exploratory 198-263 ~ 3. Address: D Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20582-01-00 ,/ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU G-09A ./ Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028285 / 64.14' Prudhoe Bay Field / Prudhoe Bay Pool .... 12';> / ... ....> / ..<; Ifvvt::I...L v\.. '''VIIIUI'II . . if:i ·..·.....·········.·«···.f. .....; ··.>yy·/;e··.····.. ··;·Y«i.iie<i:i>< ........:. Total Depth MD (ft): Total D~D (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11476 ./ ~' __ 11407 8999 10190 10095 Casino Lenoth ß)tf· "'1 šìzé MD TVD Burst CollaDse Structural Conductor 110' 20" x 30" 110' 110' Surface 2672' 13-3/8" 2672' 2672' 4930 2670 Intermediate 9481' 9-5/8" 9481' 8392' 6870 4760 Production Liner 953' 7" 8975' - 9928' 7964' - 8776' 8160 7020 Liner 2498' 2-7/8" 8976' - 11474' 7965' - 9002' 13450 13890 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 10095' - 11405' 8900' - 8998' 5-1/2",17# x 4-1/2",12.6# L-80 9024' Packers and SSSV Type: 9-5/8" Baker packer I Packers and SSSV MD (ft): 8896' 13. Attachments: 14. Well Class after proposed work: / 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: CommencinQ Operations: August 20, 2007 D Oil DGas D Plugged 181 Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer ~Mtl!~ Date S/B/O] Prepared By Name/Number: Signature Phone 564-4387 Terrie Hubble, 564-4628 Commission Use Only I Sundry Number: .'2./Y7... ~/n,~ Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance Other: ")SŒ) '~'"ßO V ~ p~\ ~. Subsequent Form Required: 4~: APPROVED BY Date8-t3 -q- ADDroved By: f7 COMMISSIONER THE COMMISSION Form 10-403 Revised 06/2006 V \....,...-- '-- Submit In Duplicate . rp:;, 8,/3'01 STÁtE OF ALASKA I /_ ALASKA Oil AND GAS CONSERVATION COMM SION f)ft/\O AUG 0 9 2007 APPLICATION FOR SUNDRY APPROVAL Alaskê üil & Gas Cons Comm':: ill , 20 MC 25 280 . ~s.,,¡; RECEIVED OR\G\NAl RBDMS 8Fl AUG 14 2DD7 ~ 9·,,··, ~q'¢? . . To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission Obp From: Sean McLaughlin CTD Engineer Date: August 07, 2007 Re: G-09A Sundry Approval Sundry approval is requested for well G-09A. G-09A was sidetracked with coil in January 1999 drilling an 1100' horizontal Zone 2A well. The GOR rose steadily and climbed above 20,000 in 6 months. The wellhead developed a leak at the Braidenhead in September 2000 and needed a weld repair. Zone 2B perfs (10,119'- 10,124') were added in November 2000 in an attempt to reduce the GOR. There was no change in production. A CIBP was set at 10,190' in November 2001 to shut-off the entire horizontal section, leaving only the Zn 2B perfs to produce. In September 2002 the well began to have IA problems and failed a TIFL. The valves were dummied and it failed another TIFL. An IBP was set at 8935' to secure the well. A leak detection log was run in October 2002 and found an obvious leak at GLM#I. The well remains shut in and classified as a troubled well that is not v/ allowed to produce due to the tubing leak In February 2006 an attempt was made to return to the horizontal section of the wellbore and patch the holes in the GLMs. This required fishing strip gun debris above the CIBP fonn perfs shot in March 2002. Slickline fished three different times in 2006 retrieving parts of the 30' fish. Then in February 2007 coil got on the well to fish and mill with no success. The last attempt was in April 2007 when cement was dump bailed on the fish and coil tried to mill through the debris and CIPB with no progress. In June 2007 a WRP was set above GLM #1 and the tubing was pressure tested to verify that GLM #1 was the well's only source of TxIA communication. The testing confinned this so the liner only needs to be brought up to ~8700' MD. REASON FOR SIDETRACK With TxIA communication this well needs to be repaired. Being unable to return to the horizontal section ofthe wellbore, a sidetrack is the only option at this point. Due a known leak at GLM#1 @ 8766' MD the liner will be brought up past this elf point in the completion. $'~ ~ Pre-Rig Work: (scheduled to begin August 20, 2007) .;r...-, 1. E Set 2-7/8" CIBP at 9600' ~ If} 7 2. E Jet cut 2-7/8" liner at 9575'(this is 5' above the est. TOe) v /y/q¡ f/ / 3. C Pull test liner to verify section is rree í5f ' 4. 0 CMIT-TxIA (known leak across GLV #1) 5. 0 MIT-OA done 5/15/07 6. 0 AC-LDS; AC-PPPOT-IC, T 7. 0 PT MV, SV, WV 8. 0 Bleed gas lift and production flowlines down to zero and blind flange 9. 0 Remove wellhouse, level pad Rig Work: (scheduled to begin on September 15, 2007) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Pull 613' section of2 7/8" liner 3. Run caliper log. 4. Cleanout/underream cement rrom 9450' down to 9575'. 5. Set 4-1/2 x 7" WS 9564' withHS orientation. 6. Mill 3.8" window at 9564' and 10' of rat hole. Swap the well to Flo-Pro. 7. Drill Build: 4.125" OH, 886' (15 deg/100 planned) 8. Drill Lateral: 4.125" OH, 1940' (12 deg/100 planned) with resistivity 9. Run 3-1/2" x 3-3/16" x 2-7/8" solid liner leaving TOL at 8710' 10. Pump primary cement leaving TOC at 8976', 44.7 bbls of 15.8 ppg liner cmt planned 11. Cleanout liner and MCNL/GR/CCL log 12. Test liner lap to 2000 psi. Th\s a \' ~rovo.. \ 1 ~Cë.~ 4C \ . . 13. Perforate liner per asset instructions (-1000') 14. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's 3. Test separator (-1000' ofprefs) Sean McLaughlin CTD Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble TREE = McEVOY 6" ~N01ES' STAI. LATatIS IIROKBIlNO waLHEAD = McEVOY G-09A FN). MODlRED PRONG IS BROKEN AND BENT ACTUATOR = OTIS OVER REMAINING VALVE BODY. KB. 8..EV = 64.14' BF. 8..EV = 35.54' I H5-1/2" SSSV CAMCO LANDING NIP, 10 = 4.662" I KOP= 3000' . 2096' Max Angle = 92 @ 10796' Datum MD = 10039' :~ 2584' -19-5/8" rN PKR I Datum TVD = 8800' SS GAS LFT MANDRELS l~ ~ ST MD TVD DEV TYPE VLV LATCH PORT DATE 113-3/8" CSG, 72#, L-80, [) = 12.347" H 2672' 12 2985 2920 6 CA [)MY RK 0 09/22/02 11 5103 4770 34 CA [)MY RK 0 09/22/02 L 10 6269 5796 41 CA [)MY RK 0 9 6416 5915 43 CA [)MY RK 0 8 7070 6453 39 CA [)MY RK 0 7 7215 6574 38 CA [)MY RK 0 Minimum ID = 2.44" @ 8976' 6 7660 6951 35 CA [)MY RK 0 2-7/8" LNR 5 7801 7072 35 CA [)MY RK 0 4 8217 7440 33 CA [)MY RK 0 3 8364 7572 33 CA [)MY RK 0 2 8627 7807 30 CA [)MY RK 0 1 8766 7931 31 CA [)MY RK 0 I I 8834' 1-15-1/2" CAMCO SLIJING SLV, [) = 4.500" I ] , 8866' I-1TBG SEAL ASSEMBLY (SBR) I ~ ~ , eøs:' 1-19-5/8" BAKER PKR, 10 = 4.00" I 15-112" TBG, 17#, L-80, .0232 bpf, 10 = 4.892" I 8896' - I B8~c., . . , 8959' 1-l4-1I2" x OTIS NIP, ID = 3.813" I TOP OF 7" LNR I I 8975' I . I TOP OF 2-7/8" LNR, W/4" GS PROFlE, 10 = 3.000" 8976' I )_-1 8991' 4-1/2" XN OTIS NIP, 10 = 3.725" I (B&lIND LNR) MILLED OUT 01/19/99 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9023' I 9023' -14-112" TBG TAIL (BBiIND LNR) I I 9025' H8..MDTTLOGGED02/13/91 I 19-5/8" CSG, 47#, N-80, [) = 8.681" I 9481' ~ .. ~ 9925' HTOPOFWHPSTOCK I PERFORATION SUMMARY V ..... 19928'-9935' HMlLLOUT WWOW IN 7" I REF LOG: SPERRY MIND GR ON 01/23/99 ANGLEAT TOP PERF: 55 @ 10095' V 9935' HRA TAG, 8..MDI Note: Refer to Production DB for historical perf data ~ ~ . 00.5 H 16' OF 2.718" ""'" G'" (818,..) I SIZE SPF INTERVAL Opn/Sqz DATE 2-118" 6 10095 - 10120 0 03/02/02 2 6 10105 - 10115 0 01/12/02 2 6 10115 - 10120 0 02/28/01 2 6 10119 - 10124 0 11/14/00 1.69 4 10480 - 10630 C 01/25/99 1.69 4 10810 - 10950 C 01/25/99 1.69 4 11020 - 11220 C 01/25/99 1.69 4 11280 - 11405 C 01/25/99 ~W I PBTD 11407' ......, I PBTD I 10317' .J' 17" CSG, 29#, N-80, 10 = 6.182 I 12-7/8" LNR, 6.16#, L-80, 11474' I 10354' I .0056 bpf, 10= 2.441" DATE REV BY COMMENTS DATE REV BY COMlAENTS PRUDHOE BAY UNIT 06/01/81 ORIGINAL COMPLETION 10/10/06 RCTfTLH IBP PULLED CORRECTION waL: G-09A 01/01199 CTD SIDETRACK 12/12/06 CJNlTLH FISH PULLED (FRAC SLV) PERMIT No: 1982630 03/02/01 TMNIKAK ADD PERFS 01/24/07 MGSfTLH SL FISH PULLED Apt No: 50-029-20582-01 01/16/02 AYfTLH ADD PERFS SEe 12, T11N, R13E, 2664' FNL & 2367' F8.. 08/05/06 JCIINPJC PULL IBP @ 8934' 08/09/06 CJNlPJC 3 FISH 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 Perfs 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 64 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 2664' FNL, 2367' FEL, Sec. 12, T11 N, R13E, UM (asp's 657861, 5968977) G-09A At top of productive interval 9. Permit number / approval number 4271' FNL, 4398' FEL, Sec. 13, T11 N, R13E, UM (asp's 655977, 5962049) 198-263 At effective depth 10. APl number 766' FNL, 4202' FEL, Sec. 13, T11 N, R13E, UM (asp's 656099, 5965557) 50-029-20582-01 At total depth 11. Field / Pool 2086' FNL, 4492' FEL, Sec. 13, T11 N, R13E, UM (asp's 655837, 5964231) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11476 feet Plugs (measured) CIBP set @ 10190' (11/15/2001) true vertical 8937 feet Effective depth: measured 10080 feet Junk (measured) Fish (26' Gun Strap) @ 10080' (03/02/2002) true vertical 8891 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 72 c.f. concrete 146' 146' Surface 2636' 13-3/8" 3440 cf AcrticSet II 2672' 2672' Intermediate 9445' 9-5/8" 1300 cf Class 'G' 9481' 8392' Liner 1384' 7" 336 cf Class 'G' 8975' - 10359' 7964' - 8993' Sidetrack Liner 2498' 2-7/8" 107 cf Class 'G' 8976' - 11474' 7964' - 9002' Perforation depth: measured Open Perfs 10095'-10124', Open Perfs below CIBP 10480'-10630', 10810'-10950', 11020'-11220', 11280'-11405' true vertical Open Perfs 8900' - 8915', Open Perfs below CIBP 8997' - 9001', 8998' - 8998', 8998' - 8996', 8996' - 8998' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 TBG @ 8896'. 5-1/2" x 4-1/2" XO @ 8896'. 4-1/2", 12.6# L-80 TT @ 9025'. RECEIVt-.' ED Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker Packer @ 8896'. 5-1/2" Camco SSSV Landing Nipple @ 2096'. 13. Stimulation or cement squeeze summary llfl/41'( 4~ ~ ~/UUL Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 03/01/2002 289 7665 5 218 Subsequent to operation 03/15/2002 726 22453 15 515 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 tr.ue and correct to the best of my knowledge. ~-"~-~'~~J~ Title: TechicalAssistant Date March 18, 2002 Dewayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 01/12/2002 O3/O2/2OO2 03/10/2002 01 / 12/O 2 03/02/02 G-09A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERF(ADD-PERF): PERFORATE 10105 - 10115 FT MD PERF(ADD-PERF): PERFORATING PERF(ADD-PERF): FISH EVENT SUMMARY PERFORATED 10105 - 10115 FT MD WITH 2' HSD @ 6 SPF ( 2006 POWER JET CHARGES) PERFED 10095-10120 FT MD WITH 2.125" POWER ENERJETS @ 6 SPF. HAD DIFFICULTY STABBING INTO LINER TOP, THEN S/D IN LINER AT 9690, 9975, 10005, 10063, 10073, AND 10110 FT. DID NOT TAG TD. TOOL STUCK AFTER SHOOTING. PUMPED 290 BBLS CRUDE THEN PULLED OUT OF WEAKPOINT - ***FISH IN HOLE*** TOP @ 10080' ELM ( OAL= 39.6 FEET X 2.125" MAX OD W/ 1.375" FN). NOTIFY PAD OPER OF STATUS - DO NOT FLOW WELL. 03/10/02 FISH E-LINE PERF GUN 39.6' OAL DID NOT RECOVER ALL OF FISH. APPROX 26' PERF STRIP STUCK IN HOLE @ APPROX. 10080' ELM RDMO NO FISHING OPTIONS, DISCUSSED WITH PE'S AND TURNED WELL OVER TO PAD OPERATOR TO POP FLUIDS PUMPED BBLS 2 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (2 TESTS) 7 METHANOL WATER 290 CRUDE 50 DIESEL 349 TOTAL ADD PERFS 01/12/2OO2 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2" PJ 6SPF, RANDOM ORIENTATION. 10105'- 10115' O3/O2/2OO2 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2-1/8" POWER ENERJET 6SPF, RANDOM ORIENTATION. 10095' - 10120' Page 1 STATE OF ALASKA ALASK~01L AND GAS CONSERVATION COT'VlMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Pull Tubing []Alter Casing [] Repair Well 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2615' FSL, 2366' FEL, SEC. 12, T11N, R13E, UM At top of productive interval 1156' FNL, 1868' FWL, SEC. 09, T11N, R13E, UM At effective depth 2021' FNL, 807' FWL, SEC. 13, T11N, R13E, UM At total depth 2087' FNL, 787' FWL, SEC. 13, T11N, R13E, UM [] Perforate [] Other Add Perfs 5. Type ~f well: 174 Development [] Exploratory [] Stratigraphic [] Service (asp's 657861,5968977) (asp's n/a) (asp's 655856, 5964297) (asp's 655837, 5964231) 6. Datum Elevation (DF or KB) KBE = 64.14' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number G-09A 9. Permit Number / Approval No. 198-263 10. APl Number 50- 029-20582-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 11476 feet 9002 feet 111407 feet 8999 feet Length Structural Conductor 110' Surface 2643' Intermediate 9452' Production Liner 953' Sidetrack Liner 2498' Plugs (measured) Junk (measured) Window @ 9928'-9935'. Abandoned 7"from 9928'to 10354. Size Cemented MD TVD 20" x 30" 72 c.f. concrete 139' 13-3/8" 3440 c.f. Arcticset II 2672' 9-5/8" 1300 c.f. Class 'G' 9481' 7" 336 c.f. Class 'G' 8975' - 9928' 2-7/8" 107 c.f. Class 'G' 8976' - 11474' 139' 2672' 8392' 7964'-8776' 7965'-9002' Perforation depth: measured true vertical Open Perfs 10115'-10124', 10480'-10630', 10810'-10950', 11020'-11220', 11280'-11405' Open Perfs 8911'-8916', 8933'-8936', 8933'-8933', 8933'-8932', 8931'-8934' Tubing (size, grade, and measured depth) 5-1/2" 17 #, L-80 tubing to 8896'. 4-1/2" 12.6# L-80 tubing tail @ 9025'. Packers and SSSV (type and measured depth) 9-5/8" Baker PKR (4.000") @ 8896' 5-1/2" Camco SSSVLN (4.662" ID) @ 2096'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water~Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that,the foregoing is trj~e a~nd correct to the best of my knowledge Signed DeW.~a~R S c rr~t.~_~.~~ -..._ Title Technical Assistant Prepared By Name/Number: Form 10-404 Rev. 06/15/88 E lSil\l .;i.,,,, De Wayne Schnorr 564-5174 Submit In Duplicate G-09A ' .... Description of Work Completed NRWO OPERATIONS 02/28/2001 PERF(ADD-PERF): PERFORATING SUMMARY 02/28/01 SHOOT INTERVAL OF 10115 TO 10120 W/2" POWER JET @ 6 SPF. -- PEN 18.6--ENT 0.2-- CCL TO TOP SHOT 7.6 WELL FLOWED PRIOR TO PERFORATING WELL LEFT WITH DSO ON TEST Fluids Pumped BBLS. 0 0 TOTAL Description NO FLUIDS PUMPED ADD PERFS 02/28/2001 SUMMARY The following interval was perforated using 2" HSD Power Jet gun, 6 SPF 60 degree phased, random orientation. 10115' ~ 10120' MD :-,-: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU: TO: Julie Heusser, DATE: Commissioner Tom Maunder, ~~'~~ P. I. Supervisor March 26, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit BPX / G Pad March 26, 2001' I traveled to BPX's Prudhoe Bay Field, G Pad, to WitnesS Surface Safety Valve System tests and perform well house inspections. Merv Liddelow was the BPX representative in charge of testing and he performed the tests in a safe and proficient manner. Fifteen wells were tested with nine failures witnessed. The pilots on wells G-02A, G-1 lA, G-14A and G- 21A failed to operate properly. The SSV's on wells G-01A, G-02A, G-03^, G-09 and G-13 failed to close or failed to hold DIP. Wells G-03 and G-09 were shut in pending repairs. Mr. Liddelow indicated to me that all other failures had been repaired and passed a retest within 24 hours. Fifteen well houses were inspected and slight crude oil leaks were noted on wells G-14 and G-16. Mr. Liddelow and his crew repaired these leaks immediately. The AOGCC test reports are attached for reference. SUMMARY: I witnessed SVS tests on 15 oil producing wells on BPX's G Pad in the Prudhoe Bay Field. 15 wells, 30 components tested. 9 failures: 30% failure rate. 15 well house inspections Attachments: SVS PBU G pad 3-26-01 JJ CC;' NON-CONFIDENTIAL SVS PBU G Pad 3-26-01 JJ Aiasi~ ~ Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unk/Pad: PBF/PBU/G-Pad Separator psi: LPS 152 Date: 3/26/01 HPS 649 i i i . i i ~ i i L. II I . I Well Permit Separ Set L/P Test Test Test Date Oil, WAG, Gl]NJ, Number Number PSI. PSI Trip Co~e Code .Code Passed aAS or CYCL~ a:0 A P G-02A ~'1~50230 1'52 '¥25 145 1' 5 .... 0IL G-03A 1970700 152 125 115 P 5 OIL G-04A 1951630 G-05 1780970 649 ~50 555 P ~ ............. OIL G206 "' 1790120~ ' ' G-07 1790180! 1521 125 115 P P OIL G-08 1810480 G~09A: J':r.)' ::::'i982~301 649 550 560 P '4 ...... OIL G-10A 1950390 G-11A 1931'600 ' 649 550 ' 180 3 P ....... G212A~ 1961050 ......... G-13 1810720! 152: 'i25 120' P 4 .... oIL , , G-14A 1980530 649 550 0! 2 P OIL G-15A 1981340 649 550 530 p P ' ' oIL~ G-16 1811220 649 550 540 P P G-17 1810940 ' G-18A 1990320 649 '' ~50 555 P ~ I, OIL G-19A 19910'30 ..... G-21 '1~5i540 ' 649 550 0 2' P ' OiL G-23A 1960200 , ,, G-24 1861830 G-25 1861620 ..... G-26A 1981510 G-27 1861560 G-29 1861600 G-50/~ 1950760 G-31A 1980540 649 '~50 560 P P ....... OIL G-32A 1970010 152 125 140 P P OIL Wells: 15 Components: 30 Failures: 9 Failure Rate: 30.000/t~ 90 Day Remarks: G-3. G-9 are shut in for repair. Operator reports all other failures r. epaired & .p. as,,sed' n RJF 1/16/01 Page 1 of 2 SVS PBU G Pad 3-26-01 JJ1 Well Permit Separ Set IXP Test Test Test Date WAG, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLe: RJF 1/16/01 Page 2 of 2 SVS PBU G Pad 3-26-01 JJ1 198,2'63'0 PRUDHOE BAY UNIT G-09A" 50_ 029,20582~0i BP E~LORA~i0N (ALASKA) INC Roll #1: Start: Stop Roll #2: Start Stop MD 11476 TVD 08937 Completion Date: 1/25/99 Completed Status: 1-OIL Current: T Name Interval / C" 'RST/GR/cCn 9900-11400 Digital Data CH v" n PROD-SPIN/TEM/ FINAL PRES 9900-10005 ~,g../m~? ~/'~.-OD CH ~"L RST/GR/CCL 9900-11400 BL'~, Sepi;! ~.-5~tCt~ CH J R EOW SRVY CALC BH 9900.-11476. ~q ,k~-~ q.~.~' OH jR SRVY LSTNG BH 9900.-11476. ~.W,~tc-r~'~ OH Sent Received T/C/D 11/16/00 1/3/01 9/12/00 9/15/00 11/16/00 1/3/01 2/11/99 2/16/99 2/11/99 Thursday, Jarltlary 25, 2001 Page 1 of 1 9/12/00 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 505 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date Blueline Sepia Color CD Prints A-01 PRODUCTION PROFILE/DEFT 000907 1 1 G-09A PRODUCTION/INJECTION PROFILE 000904 ! 1 N-24 PRODUCTION PROFILE/GHOST/DEFT 000908 I 1 U-04A ~%~.~ INJECTION SURVEY W/SRT 000905 1 1 U-10 ~ ! ,~ J INJECTION SURVEY W/SRT 000906 1 1 E-24B 20305 MCNL '-~'~ "1 ~c~ 000710 1 1 1 J-10 20300 RST-SIGMA ~[. ,~i'~ "~'~ 000709 1 1 1 J-20A 20298 RST-SIGMA '1~c~'~ ~O 000706 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EAcH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED Date Delivered: SEP 15 000 Oil.& 6as Cons. commiSs Anchorage Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie 8250 - 8400 ~ 8550 8700 8850 9OOO I V 9750 B.P. Exploration (True) Structure : Pod G Field : Prudhoe Boy Well : G-O9A, APl 50-029-20582-01 Location : North Slope, Alaska <- West (feet) 3000 2850 2700 2550 2400 2250 2100 1950 1800 1650 1500 1350 I I I II II II I I II [ I I I I [ [ I 3300 3600 3750 3900 o 4050 4,200 4350 I 4500 4650 4800 ORIGINAL 5100 Created by phlnnrr B~te plotted: 24-Met-99 i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i CoordInotea era in feet reference G-O9, 300 150 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 21 O0 2250 2400 True VerUcal Oepthi are reference rkb - kiSL - 64,1 ft. Vertical Section (feet) -> · Azimuth 198.81 with reference 3298.89 S, 1761.18 W.from G-09 B.P. Exploration (True) Pad G G-OgA G-09 Prudhoe Bay North SLope, Ataska SURVEY LISTING by Baker Hughes INTEQ Your ref : G-O9A Our ref : svy94 License : AP[ 50-029-20582-01 Date printed : 24-Mar-99 Date created : 24-Mar-99 Last revised : 24-Mar-99 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 654892.610,5971579.300,999.00000,N Slot Location is nTO 19 18.975,w148 43 12.200 Slot Grid coordinates are N 5968977.000, E 657860.999 Slot Local coordinates are 2663.22 S 2914.24 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North B.P. Exploration (True) Pad G,G-OgA Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : G-O9A Last revised : 24-Mar-99 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 9900.00 29.02 225.79 8687.53 3298.895 1761.18W 1.64 0.00 656168.43 5965642.69 9925.00 28.89 225.43 8709.40 3307.36S 1769.83W 0.87 10.80 656159.95 5965634.05 9950.00 30.51 223.56 8731.12 3316.195 1;r78.51~ 7.46 21.97 656151.46 5965625.04 9955.26 30.85 223.19 8735.64 3318~14S 1780.35~ 7.39 24.41 656149.66 596562].05 9980.00 38.39 221.70 8755.99 3328.525 1789.82~ 30.67 37.28 656140.41 5965612.48 9985.44 40.05 221.44 8760.20 3331.09S 1792.10~ 30.66 40.45 656138.18 5965609.86 10018.46 42.28 219.89 8785.06 3347.58S 1806.25W 7.43 60.62 656124.37 5965593.09 10047.84 45.41 218.74 8806.24 3363.33S 1819.14~ 10.99 79.69 656111.81 5965577.08 10078.69 52.06 217.69 8826.58 3381.545 1833.4714 21.71 101.55 656097.86 5965558.57 10109.61 58.11 215.11 8844.27 3401.955 1848.4914 20.73 125.71 656083.27 5965537.86 10143.39 62.84 210.74 8860.92 3426.62S 1864.43W 17.96 154.20 656067.84 5965512.87 10181.49 60.47 205.64 8879.02 3456.155 1880.28W 13.32 187.27 656052.61 5965485.02 10214.71 64.34 203.36 8894.40 3482.94S 1892.48W 13.14 216.55 656040.97 5965455.99 10255.94 69.96 199.14 8910.41 3518.345 1906.21W 16.57 254.49 656027.97 5965420.32 10288.71 76.20 195.45 8919.95 3548.265 1915.51~ 21.87 285.81 656019.29 5965390.21 10320.79 81.91 194.74 8926.04 3578.65S 1923.71W 17.93 317.22 656011.72 5965359.66 10351.00 88.27 193.45 8928.62 3607.835 1931.03~ 21.48 347.21 656005.00 5965330.34 10357.96 89.74 193.16 8928.74 3614.60S 1932.63W 21.53 354.13 656003.54 5965323.53 10391.29 88.86 189.47 8929.15 3647.28S 1939.1714 11.38 387.17 655997.68 5965290.73 10423.61 87.54 186.84 8930.16 3679.255 1943.75W 9.10 418.91 655993.76 5965258.67 10455.18 85.69 179.98 8932.03 3710.695 1945.63~ 22.47 449.28 655992.53 5965227.21 10497.26 88.26 175.58 8934.25 3752.665 1944.00W 12.10 488.49 655995.03 5965185.27 10541.51 88.94 167.85 8935.34 3796.415 1937.63W 17.53 527.84 656002.30 5965141.68 10574.51 89.47 172.59 8935.79 3828.91S 1932.02~ 14.45 556.80 656008.57 5965109.29 10618.08 88.51 175.25 8936.56 3872.235 1927.41W 6.49 596.32 656014.08 5965006.09 10662.58 90.97 180.33 8936.76 3916.68S 1925.70~ 12.68 637.84 656016.71 5965021.69 10706.18 91.57 185.12 8935.80 3960.205 1927.77~4 11.07 679.71 656015.54 5964978.13 10750.00 91.06 189.89 8934.79 4003.625 1933.4914 10.94 722.65 656010.72 5964934.60 10750.99 91.05 190.00 8934.77 4004.605 1933.66~ 11.16 723.63 656010.57 5964933.63 10796.26 91.60 195.00 8933.72 4048.77S 1943.45W 11.11 768.60 656001.69 5964889.27 10846.16 89.56 193.34 8933.22 4097.145 1955.66W 5.27 818.33 655990.48 5964840.65 10890.68 90.44 198.26 8933.22 4139.975 1967.78W 11.23 862.77 655979.25 5964797.59 10928.01 89.56 200.54 8933.22 4175.185 1980.18W 6.55 900.10 655967.58 5964762.14 10955.68 89.12 200.72 8933.54 4201.075 1989.93~ 1.72 927.75 655958.37 5964736.05 11013.41 90.40 196.84 8933.78 4255.725 2008.51~ 7.08 985.47 655940.92 5964681.04 11047.46 90.35 194.74 8933.56 4288.48S 2017.78~ 6.17 1019.47 655932.34 5964648.09 11102.58 90.09 189.82 8933.35 4342.325 2029.50~ 8.94 1074.22 655921.73 5964594.02 11133.41 90.09 188.24 8933.30 4372.775 2034.33W 5.12 1104.60 655917.52 5964563.49 11167.42 90.88 191.05 8933.01 4406.29S 2040.03~ 8.58 1138.17 655912.52 5964529.85 11210.92 90.61 192.98 8932.44 4448.835 2049.09t4 4.48 1181.36 655904.34 5964487.14 11244.04 90.97 194.04 8931.99 4481.035 2056.82~ 3.38 1214.33 655897.28 5964454.79 11275.29 90.26 195.27 8931.65 4511.26S 2064.73W 4.54 1245.50 655890.00 5964424.40 11305.40 90.09 197.03 8931.56 4540.185 2073.10~ 5.87 1275.57 655882.22 5964395.32 11337.87 88.77 197.55 8931.88 4571.185 2082.75W 4.37 1308.03 655873.21 5964364.12 11349.00 88.40 198.12 8932.16 4581.785 2086.16W 6.10 1319.15 655870.03 5964353.47 11372.09 87.63 199.31 8932.96 4603.635 2093.56W 6.14 1342.23 655863.08 5964331.46 11411.09 87.45 194.57 8934.63 4640.89S 2104.91~ 12.15 1381.16 655852.50 5964293.98 11413.00 87.43 194.72 8934.72 4642.745 2105.40W 7.92 1383.07 655852.05 5964292.12 11449.25 87.10 197.55 8936.45 4677.52S 2115.46~ 7.85 1419.23 65584.2.71 5964257.14 11476.00 87.10 197.55 8937.80 4702.995 2123.51~ 0.00 1445.94 655835.19 5964231.51 All data in feet unless otherwise stated. Calculation uses minimum curvature methed. Coordinates from G-09 and TVD from rkb - MSL = 64.1ft. Bottom hole distance is 5160.18 on azimuth 204.30 degrees from wellhead. Vertical section is from tie at S 3298.89 ~ 1761.18 on azimuth 198.81 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and co~uted using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ~ALASKA~ leare.d Ivices rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: March 31, 1999 From: Terrie Hubble Technical Assistant Subject: Revised Surveys Enclosed, in duplicate, are updated directional surveys for the following wells: G-14A, Permit #98-53 S-31A, Permit #98-220 G-09A, Permit #98-263 R-06A, Permit #98-127 Baker Hughes INTEQ has submitted these revised surveys to us correcting the grid coordinates. These surveys do not require changes to the Completion Reports which were previously submitted by Theresa Mills, and are being provided to you simply for your records. However, I have also attached a revised Completion Report for R-06A as I have found a few errors in the previously submitted form and have chosen to revise it at this time. These changes are primarily minor (corrected TD was 12308', open hole completion was from 12038' to 12308'), but felt that it was important to make the corrections. The well histories and logs have previously been filed with the Commission and there are no changes. Thank you. /tlh STATE OF ALASKA ALASKA ". AND GAS CONSERVATION COMMIS 3N WELL COMI'.~TION OR RECOMPLETION REPORT/,:~-~_D LOG CT Sidetrack well 1. Status of Well []Oil E~Gas [] Suspended [] Abandoned [] Service Classification of Service Well 2. Name of Operator ....BP E~.plorat.i..o.n (Alaska) Inc. 3. Address P.O. Box196612, Anchorage, Alaska 99519-6612 Location of well at surface 2367' WEL, 2664' SNL, SEC. 12, T11 N, R13E, UPM At top of productive interval 881' EWL, 4271 'SNL, SEC.13, T11N, R13E, UPM At total depth 7. Permit Number 98-263 8. APl Number 50-029-20582-01 9. Unit or Lease Name Prudhoe Unit Bay ~!~-~ 0. Well Number !';-~~ 1. Field and Pool 4490 WEL, 2086 SNL, SEC. 13, T11 N, R13E, UPM Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE=64.14 J ADL 028285 12. Date Spudded1/20/99 I 13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'll 5' Water depth' if °fish°re t 16' N°' °f C°mPleti°nsl/23/99 1/25/99 N/A MSL One 7. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I 19. Directional SurveyI 20. Depth where SSSV set121. Thickness of Permafrost 11476 8937 FTI 1 1407 8933 FTI [] Yes [] No ! 2096 MD I 1900' (Approx.) 22. Type Electric or Other Logs Run MWD Gamma RAy 123. CASING S~ZE WT. PER FT. GRADE 20x30 Sudace 13-3/8" 72# L-80 Sudace 9-5/8" 47# L-80 Sudace 7" 29 L-80 8975 2-7/8" 6.16# L-80 8976 CASING~ LINER AND CEMENTING RECORD SETTIN(i DEPTH I HOLE ToP BOTTOMI S,~ 110 I 36 2672 17 1/2" 9481 I12-1/4" 10359 /8-1/2" , i 11474 ]3-3/4" i 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) CEMENTING RECORD AMOUNT PULLED 8 c.y. concrete 3440 c.f. Arcticset II 300 c.f. Class G 336 c.f. Class G 07 c.f. Class G 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 5 1/2" 9024' 8816 MD TVD 10480-10630 8933-8936 10810-10950 8933-8933 11020-11220 8933-8932 11280-11405 8931-8934 1 11/16", 4spf 26. ACID FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. Date First Production 1/30/99 Date of Test Hours Tested Flow Tubing Casing Pressure Press. 28. I Method of Operation (Flowing, gas lift, etc.) Flowing tPRODUCTION lOlL-DEL GAS-MCF OR TEST LCULATED · lOlL-DEL GAS-MCF -HOUR RATE I CORE DATA PRODUCTION TEST 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 2~. Geologic Markers 30. 'mation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. I~1. List of Attachments Summary of Daily Drilling ~eports, Surveys 32. I hereby c~e~fy that the foregoing is true and correct to the best of my knowledge - Signed ~"~re~'~~'~'~ ;) Title Coiled Tubing Dri !ling TA Date ~-~/~[/~ ~ Prepared By Name/Number: Theresa Mills 564-5894 ~NSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 !TREE: McEVOY 6" WELLHEAD: McEVOY !ACTUATOR: OTIS 9-5/8 D.V. PACKERJ 2584 13-3/8", 72#/ft 12672 I~ L-80, BTRS IKOP: 2700 I MAX ANGLE: 42° 5-1/2", 17#/ft, L-80 IJ4S TUBING IBING ID: 4.892" 0.0232 BBL/FT 2 7/8" Liner Top @ 8976' 2 7/8" 6.16 #/FT, L-80, ST-L ID-2.441" (Min. ID-2.377" at Tool Jr.) Capacity: 0.0058 Bbl/Ft 4" GS Profile in Top of Liner 4-1/2", 12.6#/ft, L-80 TAILPIPE TOP OF 7" LINER 18975 9-5,8", 47#,ft, N-80, BTRS I9481 Whipstock Top @ 9925' RA Tag @ 9935' ELMD G-09a KB. ELEV = 64.14 BF. ELEV = 35.54 SSSV LANDING NIPPLE (CAMCO BAL-O)(4.562" ID) I 2096 GAS LIFT MANDREL I (CAMCO W/ RK LATCH', I 12 11 10 9 8 7 6 5 4 3 2 1 2985 5103 6269 6416 7070 7215 7660 7801 8217 8364 8627 8766 2919 4822 5796 5915 6453 6574 6951 7072 7440 7572 7807 7931 (,SIIII ~ne RKEE 1/94 ~ SLIDING SLEEVE (CAMCO)(4.500" ID) I 8834 SEAL ASSY (SBR) I 8896 9-5/8" BAKER PKR (4.00" ID) 881 6 4-1/2 .... X" NIPPLE (OTIS) (3.813" ID) I 8959 :(0TIS)'i (3:~25"'1D):' I!: 1/2"i: :ii: : TBG TALE(ELMD) II 902590238991 ii PERFORATION SUMMARY: REF: LOG: Sperry MWD GR 1/23/99 SIZE ISPFI INTERVAL 1.691411o48o-lo63o 1.6914110810-10950 I:~99 ~11020'11220 11280-11405 OPEN/SQZ'D Open Open Open Open Original Prod. Permanently Abandoned IPBTD - 11,407' 11,474' HORIZONTAL COMPLETION Well exceeds 60 degrees at 10,140' Horizontal at 10,350' DATE 6/1/81 REV. BY COMMENTS INITIAL COMPLETION 8/14/93 J. Eckstein Post Sqz Perfs 8/16/96 EBK Reperf 2/27/98 CHH SET BAKER IBP 1/99 CT Sidetrack PRUDHOE BAY UNIT WELL: G-09 (13-11-13) APl NO: 50-029-20582-01 SEC 12; TN 11N; RG'E 13E BP Exploration (Alaska) Well: G-09A Accept: 1/7/99 Field: Prudhoe Bay Spud: 1/20/99 APl: 50-029-20582-01 Release: 1/25/99 Permit: 98-263 CTD Unit: Nordic #1 Date Day Depth 1/8/99 1 Move DS/N #1 from R-06ai to G-Pad. Accept rig at Standby rate at 1530 hrs. WO well house removal. Install heater on tree. WO grease crew to service leaking tree valves. SIWHP-2260 psi. MIRU HB&R. Fluid pack well with 600 bbls SW. RD HB&R. MIRU DS/N#1. NU BOPE. Install 2-7/8" slip rams. Spot slop tank, RU hardline. Fill pits with KCI water. WO grease crew to service leaking swab and master valves. Install test jt. Prep to test BOPE. 1/9/99 2 Attempt to test BOPE and swab and master leaked. Set TWC in tubing hanger using ARCO DSM lubricator assy. Had trouble seating due to cold soaked tree (-32 deg). Test BOPE. Attempt to pull TWC w/o success. Install Baker CTC, PT @ 3500 psi, 35K. Fill CT w/KCI water. Install jet nozzle and checks. RIH to TWC and jet clean. POOH. RU DSM and work to retrieve TWC. Can latch ok, but won't move. RD DSM. Grease tree. Circ to keep CT warm (-40 deg). Discuss 1/10/99 3 Held meeting with CIW, DSM and BP personnel to determine procedure to fish 2 way check valve from well head. Kill well by pumping 300 bbl NaCL brine [9.9 PPG] down inner annulus thru upper 2 GLV's. Pump 300 bbl seawater down inner ann while bleeding WHP. WHP fell from 1500 psi to 250 psi. DSM work two way check valve with running and pulling tools while pumping 1 BPM down IA to keep well dead. RD DSM. RIH with jet nozzle and wash grease out of tree with 40 bbls SW and 40 bbls hot diesel. RU Halliburton camera. Displace tree/BOP/lub with bottled N2. Drove fluid level to master valve. WO N2. 1/11/99 4 Wait on N2 unit to pump N2. R/U N2 unit and pressure test lines. Pump N2 into stack to displace water thru 'I'WC. Increase N2 WHP to 3000 psi. Unable to pump water down thru -15NC. 'rwc is sealed with pack-off grease from Halco lubricator. Wash tree with clean sea water. Tried to pump water thru 'TWC at 3000 psi. No luck. Unable to view top of TWC with camera. P, JD Halco E-Line unit. PJU "Big Bertha" DSM Lubricator. Press test with 2500 psi. RIH to top of 'I'WC and make-up threaded pulling tool. Work pulling tool up and down with max. Hydraulic press of 4800 psi. Work up and down for 2 hours. RDMO pulling tool and lubricator. RU milling assy. RIH with BHA #1 (3.5" tapered mill, 3.5" motorwith two centralizers). Mill on mandrel of TVVC for 1.5 hrs and made 0.5". POOH to check mill-sli wear. RU DSM with overshot pulling tool and screw on okay. 'I-WC still won't budge. RD DSM. RIH with same milling assy. Have cut approx 1.1" of 12" total. '1/'12/99 5 Mill on TWC mandrel to release locking dogs. Mill with Baker 3.5" taper mill. POOH and check mill. RIH and mill on mandrel. POOH. Total of 4" milled on mandrel from mill #1 wear. RIH with Baker mill #2, 1.70" X 3.5" Core mill, designed to swallow 1.55" OD dart in center of 'I-WC valve body. Mill with core mill. Flag CT above injector head to monitor progress. Mill additional 4.5" by flag. Check mill-shows 1.5" left. Rerun same mill. Cut additional 1.5" which should leave mill bottomed on prong. POOH, check mill- was bottomed out. Purge riser with N2 to see mandrel top. Core looks good. Discuss pulling procedure. 1/13/99 6 Discuss TWC pulling procedure with personnel. R/U DSM lubricator and overshot. RIH with overshot and M/U to threads on TWC valve. Pull up easy, plug still stuck, increase pull, work pulling tool up and down about 40 times. Mandrel of TWC parted with 2800 psi Hyd. Press. POOH. Recovered upper 3" of TWC mandrel. Locking dogs of TWC still extended by part of milled mandrel. Baker made a 4" mill to mill out rest of mandrel. M/U Mill #3 and RIH on 3.5" Drilex motor with two 6 ¼" clamp-on centralizers. Mill 4" hole in TWC valve [3.5" pilot hole]. Mill +/-4", began losing 40 bph. Pull out, check mill--slight wear, couple of chipped buttons. Resume milling, making very little progress. Pull out, check mill, very little additional wear. Recovered 3/8" W X 1/8" X 6" long strip of metal from top nut of Madrel. 1/14/99 7 Fish in riser with magnet and vacuum. RIH with 4" Taper tap. Unable to get a good set. Pull free easy. RIH with 4" core mill and mill for 3 hours with no progress. POOH. RIH with 6" magnet, no recovery. Run LIB. Half moon mrk from milled 3.5" mandrel. RIH with 4" short catch taper mill, set firm and pulled free with 10K. Re-set with more torque, pulled free with 10K. RIH with 4" core mill again, no progress in one hour. POOH. RIH with 3.80" Christensen Diamond mill. Milled 1" in first hour, milled 1" in second hour. Milled total 4" and mill stopped. Check mill, cored out in throat. Dis-lodge dart and other junk from alongside top of plug. Recovered part of dart and other metal pieces. Run 4" OD mill to ensure that milled section will receive 4" center spear grapple. 1/15/99 8 M/U Baker fishing BHA. Seat 4" grapple/spear in TWO body. Pull free from fish with 10K. POOH. Grapple broke and pulled free from spear. Vacuum out tree and fish out grapple. Recovered 100% of grapple in one piece. M/U 3.8" Christensen concave diamond mill and RIH on 3.5" motor. Mill 3.25" of'l'WC valve in 7.5 hours. Milling at locking dog depth in TWC. POOH. Vacuum out tree, Run magnet, Check depth of fish and bore. -I-WC was set 15" above correct setting depth. M/U 4.0" Pin Tap on 2 7/8" tbg and screw into TWC body with 3000 fi-lbs of torque. Pull 'I-VVC free with 30-40K up wt. POOH and recover upper 2/3 of'I'VVC valve. Four ¼" bolts sheared leaving bottom section body in hole. Vacuum out tree, run magnet, run LIB. LIB indicated 1.55" X 1.0 plunger looking up. Run 1.0" spear on CSH tubing. Stab in and work pipe to attempt to pull plug. Stem on spear parted, leaving spear grapple in hole. Order milling shoe to mill valve body in order to attempt catch w/overshot. Wait on tools. PU milling shoe, begin milling on Lower Valve Body. 1/16/99 9 Mill on TWC valve lower body section with 5 1/8" X 3 3/8" shoe. Mill down 3.75". RUN Baker fishing BHA with 3 3/8" overshot, jars, bumper sub and accelerator. Latch onto fish and pull up with 20-50K. Fish still stuck. Pull 50K and jar fish free on first jar lick. Recover 100% of fish. No marks on body of TWC. Well bore is clean. R/D Baker fishing tools. Well was dead. Bullhead 100 bbls of seawater to flush tailpipe. R/U SWS E-Line unit and run Baker 7" retrievable whipstock. Set top of whipstock at 9925', oriented 5 deg Right of high side, RA tag at 9935'. TIH w/squeeze nozzle. RU Dowell cementers, pump 25 Bbl cement (8 Bbl w/aggregate). Close choke and bullhead 15 Bbl cement to formation, pressure increased to 1500 psi. Close choke, shut down pump. Pressure held steady at 1500 psi. 1/17/99 10 Pull uphole to safety at 40 fpm. Circulate w/choke open at 1:1 returns. Begin closing choke to attain squeeze pressure. Pressure increased to 1500 psi. Close choke, shut down pump. Pressure held steady at 1500 psi. Circulate thru choke holding 1250 psi backpressure. Shut down and stage pressure to 2000 psi. Good test. Drop jetting ball and pump 50 bbl Biozan. Jet down to middle of whipstock with Biozan contaminant. Circulate out cement and POOH while jetting GLV's. Clean rig pits. Press test cement plug after 8 hours. Good 30 minute pressure test at 2300 psi. Freeze protect tree and CT. R/U slickline and set a plug in the SSSV nipple. R/D slickline. N/D BOP stack and move rig off of well. Pull off X-mas Tree, inspect BPV profile-- OK. Set 2 Way Ck. Valve. Install new tree, re-install S Riser, pressure test tree to 5000 psi. Move rig over well. NU BOP, change out Pipe/Slip rams 1/18/99 11 Perform weekly BOPE test. Pipe/Slip rams leaking. Replace seals and rams, still leaking. Unable to get Pipe/Slip Rams to test. Get OK from AOGCC to continue test and order pads to repair Pipe/Slip Rams. Pull 2 Way Ck. Valve, Pull plug from SSSV. Cut off 200' CT. Install CT Connector. Pull and pressure test connector. PU Window Milling BHA. TIH 1/19/99 12 9924 TIH with window Milling BHA. Mill out XN Nipple at 8991 ft. No depth correction. RIH. Circulate out bottoms-up gas. RIH and ream cement stringers from cement squeeze. Tag top of Baker whipstock at 9924' and correct to 9925 ft. Stad milling window. Many stalls to stad. Order FIoPro to sweep cement from liner. Attempt to mill, unable to make headway. POOH, change out motor. TIH, mill window. 1/20/99 13 9935 Mill 3.80" window with dimple mill to 9935 ft. POOH. Replace pipe/slip rams in BOP stack and pressure test OK. M/U string reamer and formation mill and RIH. Correct depth to 9928 ft at top of window. Ream window and mill to 9941 ft. Swap well over to used FIoPro from last well. Ream up/down across window area. Dry tag window at 9941 ft. Window is clean. POOH with reaming BHA. L/D Baker BHA. PU Drilling BHA. TIH, orient to go thru window. Drill ahead. Correct depth at RA tag (-23'). Drill 1/21/99 14 10959 Drilled build section from 10190 - 10350 ft. POOH for Horizontal drilling BHA. C/O motor, bit and Sperry MWD. RIH with drilling BHA #2. Tag TD and correct CTD to 10350 ft. Orient TF and drill horizontal hole from 10350-10959 1/22/99 15 11425 Shod trip to window. Orient TF. Drill horizontal hole from 10959 - 11168 ft. Shod trip to window. MAD pass with MWD / GR. GR not working properly. POOH for Sperry MWD/GR and orientor. C/O MWD/GR, orientor, Motor and bit. TIH, shallow test Sperry tools-OK. GR log for correlation at RA tag, correct depth (-8.5'). TIH to 10730'. Make MAD Pass to TD. Drill ahead to 11425'. TD well. 1/23/99 16 11474 Shod trip to window. Hole is clean. Orient TF. Drill with TF down. Slow ROP. Drill to a final TD of 11,474 ft BKB. POOH. Flag CT at 8500 ft EOP. L/D drilling BHA. R/U to run 2 7/8', 6.16#, STL liner. RIH with Liner. Tag bottom, correct depth (-13'), reciprocate liner. Drop CTLRT release ball, displace w/FIo-Pro. Ball on seat and sheared at 3400 psi. Check CTLRT release-- OK. Displace hole to 2% KCI. 1/24/99 17 11407 Displace hole to 2% KCL. Circulate and stop operations due to gas leak in Module 54 on G pad. Shut down operations for 5 ¼ hours. R/U DS Cementing van. Held Safety meeting. Pumped 19 BBL, 15.8 PPG, G Cement slurry as per program. Sheared liner wiper plug and bumped landing collar on schedule. Full returns during displacement. Sting out of landing collar and jet while POOH. No cement seen at surface. L/O Baker CTLRT. M/U 2.25" jetting nozzle and RIH on CSH workstring. Cement sample in DS UCA at lab. Wash into liner, no obstructions. Tag up, spot 150K LSRV FIo-Pro in liner, POOH. Hold Safety Meeting. PU Schlumberger 1 11/16" perf guns on 1 ¼" CS Hydril work string. TIH. 1/25/99 18 RIH with 1 11/16" perforating guns on CSH workstring on CT. Tag PBTD at 11407 ft BKB. Drop 5/8" steel ball. Locate bottom shot at 11,405 ft BKB. Ball on seat at 56 bbls. Firing head sheared at 3400 psi. Good indication guns fired. POOH. Held Safety Meeting. Recover perf guns, all shots fired. PERFORATED INTERVALS: 10,480-10,630, 10,810-10,950, 11,020-11,220, 11,280- 11,405 FT BKB Lay out perf guns. RIH with CT and freeze protect 5 %" tubing from 0 - 2,000 ft. POOH. Blow down CT with Nitrogen for rig move. Empty and clean rig pits. ND BOP. Release Rig 20:00 1/24/99 Rig on Stand-by Waiting on Weather to move ~~EJEBJBBJ ~~JJJBBJB! ]~~WJJJJJlJ ~~JJJJJJJJJJ ~~jjJJJJJJ i~~JJJJJlll '~-~J~J~JJlJJJJ BP Exploration Well: G-09A Prudhoe Bay North Slope, Alaska Rig: Nordic I/CTU #7 End of Well Survey & Run Report Job Number: AFE Number: 103322 4P-1245 Reviewed by: ~ ~.~~ Date: ~?~ BAKER HUGHES INTEQ EOW Survey Calculations BAKER HUGHES Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLAN Company: B.P. Exploration Rig: Nordic 1/CTU#7 Job No: 103322 Well: G-09A Field: Prudhoe Bay, Alaska AFE No: 4P-1245 Calculation Method: Minimum Curvature Mag. Declination: 27.780 BHI Rep: H. Wagoner Vertical Sect. Plane: 199.990 TRUE Grid Correction: 1.180 Job Start Date: 18-Jan-99 Vertical Sect. Plane: 198.810 GRID Total Correction: 26.600 Job End Date: 22-Jan-99 Measured l)epth from: RKB RKB Height: 64.100 True Vertical Depth: Sea level Meas. Incl. TRUE Subsea Vertical Dogleg Coords. - TRUE GRID Coords. - GRID Coords. - ASP Depth Angle Azi. TVD SectiOn Severity N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) (deg) (deg) (ft) (TIP) °/lOOft. Lat. (Y) Dep. (X) (deg) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) 9900.00 29.02 225.79 8687.53 0.00 0.00 -3298.53 - 1761.18 224.61 -3334.46 - 1692.87 5965642.54 656168.13 9925.00 28.89 225.43 8709.41 10.91 0.87 -3307.00 - 1769.83 224.25 -3343.10 - 1701.34 5965633.90 656159.66 9950.00 30.51 223.56 8731.12, 22. i 8 7.46 -3315.83 - 1778.50 222.38 -3352.12 - 1709.83 5965624.88 65615 I. 17 9955.26 30.85 223.19 8735.64 24.65 7.39 -3317.78 -1780.35 222.01 -3354.11 -1711.64 5965622.89 656149.36 9980.00 38.39 221.70 8755.99 37.63 30.67 -3328.16 -1789.81 220.52 -3364.67 -1720.89 5965612.33 656140.11 9985.44 40.05 22 i .44 8760.20 40.83 30.66 -3330.73 - 1792. I 0 220.26 -3367.29 - 1723.12 5965609.71 656137.88 10018.46 42.28 219.89 8785.06 61.17 7.43 -3347.22 -1806.25 218.71 -3384.07 -1736.93 5965592.93 656124.07 10047.84 45.41 218.74 8806.25 80.37 10.99 -3362.97 -1819.14 217.56 -3400.08 -1749.49 5965576.92 656111.51 10078.69 52.06 217.69 8826.58 102.39 21.71 -3381.18 -1833.47 216.51 -3418.59 -1763.44 5965558.41 656097.56 10109.61 58.11 215.11 8844.27 126.70 20.73 -3401.59 -1848.49 213.93 -3439.30 -1778.04 5965537.70 656082.96 I 0143.39 62.84 210.74 8860.92 155.34 17.96 -3426.26 - 1864.43 209.56 -3464.29 -I 793.47 5965512.71 656067.53 10181.49 60.47 205.64 8879.02 188.50 13.32 -3455.79 - 1880.28 204.46 -3494.14 - 1808.70 5965482.86 656052. 10214.71 64,34 203.36 8894.41 217.85 13.14 -3482.58 - 1892.47 202.18 -3521.18 - 1820.35 5965455.82 65604~{ 10255.94 69.96 199.14 8910.42 255.8 16.57 -3517.98 -1906.21 197.96 -3556.85 -1833.35 596542{).15 656027}05 10288.71 76.20 195.45' 8919.95 287.10 21.87' -3547.90 -1915.51 194.27 -3586.95 -1842.03 5965390.05 656018.97 10320.79 81.91 194.74 8926.04 318.47 17.93 -3578.29 - 1923.70 193.56 -3617.51 - 1849.60 5965359.49 656011.40 1035 ! .00 88.27 193.45 8928.63 348.39 21.48 -3607.47 - 1931.03 192.27 -3646.83 - i 856.32 5965330.17 656004.68 10357.96 89.74 193.16 8928.75 355.30 21.53 -3614.24 -1932.63 191.98 -3653.64 -1857.78 5965323.36 656003.22 ! 0391.29 88.86 189.47 8929.15 388.24 11.38 -3646.92 - 1939.17 188.29 -3686.44 - 1863.65 5965290.56 655997.35 10423.6 87.54 186.84 8930.17 419.86 9.10 -3678.89 -1943.75 185.66 -3718.50 -1867.57 5965258.50 655993.43 10455.18 85.69 179.98 8932.04 450.04 22.47 -3710.33 - 1945.63 178.80 -3749.97 - 1868.80 5965227.03 655992.20 10497.26 88.26 175.58 8934.26 488.93 12.10 -3752.31 - 1944.00 174.40 -3791.90 - 1866.30 5965185.10 655994.70 10541.5 88.94 167.85 8935.34 527.86 17.53 -3796.05 -1937.63 166.67 -3835.50 -1859.03 5965141.50 656001.97 i 0574.51 89.47 172.59 8935.80 556.50 14.45 -3828.55 - 1932.02 171.41 -3867.89 - 1852.76 59651 {)9.1 I 656008.24 10618.08 88.5 175.25 8936.57 595.62 6.49 -3871.87 -1927.41 174.07 -3911.10 -1847.26 5965065.90 656013.74 10662.58 9{).97 18{).33 8936.77 636.81 12.68 -3916.32 -1925.69 179.15 -3955.50 -1844.63 5965021.50 656016.37 10706.18 91.57: 185.12 8935.80 678.42 11.07 -3959.84 - 1927.77 183.94 -3999.06 - 1845.80 5964977 94 656015.20 Meas. Incl. TRUE Subsea Vertical Dogleg Coords. - TRUE GRID Coords. - GRID Coords. - ASP Depth Angle Azi. TVD Section Severity N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/WI-) (de~) (de~) (ft) (TIP) °/lOOft. Lat. (Y) Dep. (X) (del~) Lat. (Y) Dep. (X) l~at. IY) i)ep. (X) 10750.00 91.06 189.89 8934.80 721.18 10.94 -4003.26 -1933.49 188.71 -4042.59 -1850.63 5964934.41 656010.37 10750.99 91.05 i 90.00 8934.78 722.15 11.16 -4004.24 - 1933.66 188.82 -4043.57 - 1850.78 5964933.43 656010.22 11.1796.26 91.60 195.00 8933.73 767.01 11.11 -4048.41 -1943.45 193.82 -4087.93 -1859.66 5964~89.07 656001.34 10846. ! 6, 89.56, 193.34 8933.22 816.65 5.27 -4096.79 - 1955.66 192.16 -4136.55 -1870.87 596484().45 65599(). 13 10890.68 90.44 198.26 8933.22 861.03 11.23 -4139.61 - 1967.78 197.08 -4179.62 -1882.11 5964797.3~ 65597S.89 10928.01 89.56 200.54 8933.22 898.36 6.55 -4174.82 - 1980.18 199.36 -4215.07 -1893.78 5964761.93 655967.22 10955.68 89.12 200.72 8933.54 926.03 1.72 -4200.71 - 1989.93 ! 99.54 -4241.16 - 1902.99 5964735.84 655958 .I) 1 I 1013.41 90.40 196.84 8933.78 983.73 7.08 -4255.36 -2008.51 195.66 -4296.18 - 1920.44 596468().82 655940.56 i 1047.46 90.35 194.74 8933.56 IOi 7.69 6.17 -4288.12 -2017.77 193.56 -4329.12 -1929.03 5964647.88 655931.97 11102.58 90.09 189.82 8933.35 1072.29 8.94 -4341.96 -2029.49 188.64 -4383.19 -1939.64 5964593.81 655921.36 Il 133.41 90.09 188.24 8933.30 1102.56 5.12 -4372.41 -2034.33 187.06 -4413.73 -1943.85 5964563.27 6559174~' I I 167.42 90.88 191.05 8933.01 ! 136.01 8.58 -4405.93 -2040.03 189.87 -4447.37 -1948.85 5964529.63 655912'I','1., I 1210.92 90.61 192.98 8932.45 1179.08 4.48 -4448.47 -2049.08 191.80 -4490.09 - 1957.03 5964486.91 655903.97 I 1244.04 90.97 194.04 8931.99 1211.99 3.38 -4480.67 -2{)56.82 192.86 -4522.44 - 1964.10 5964454.56 655896.90 11275.29 90.26 195.27 8931.66 1243.10 4.54 -4511.).90 -21.164.73 194.09 -4552.83 -1971.38 5964424.17 655889.62 11305.40 90.09 197.03 8931.56 1273.14 5.87 -4539.82 -2073.10 195.85 -4581.91 -1979.16 5964395.09 655881.84 I 1337.87 88.77 197.55 8931.89 1305.57 4.37 -4570.82 -2082.75 196.37 -4613.1 I - 1988.17 5964363.89 655872.81:; 11349.00 88.40 198.12 8932.16 1316.69 6.10 -4581.42 -21.186.16 196.94 -4623.77 -1991.36 5964353.23 655869.64 I 1372.09 87.63 199.31 8932.96 1339.76 6.14 -4603.27 -2093.56 198.13 -4645.77 - 1998.31 5964331.23 655862.69 11411.09 87.45 194.57 8934.64 1378.66 12.15 -4640.53 -2104.91 193.39 -4683.26 -2008.89 5964293.74 655852.1 I I 1413.00 87.43 194.72 8934.72 1380.56 7.92 -4642.38 -2105.39 193.54 -4685.1 I -2009.34 5964291.89 655851.66 11449.25 87.10 197.55 8936.45 1416.68 7.85 -4677.16 -2115.46 196.37 -4720.09 -2018.68 5964256.91 655842.32 I 1476.00 87.10 197.55 8937.81 1443.37 0.00 -4702.63 -2123.51 196.37 -4745.73 -2026.21 5964231.27 655834.79 MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson~ DATE' January 17, 1999 Chairman THRU: Blair Wondzell, .J'~,.¢.~ FILE NO: .DOC P. I. Supervisor FROM: Lawrence M Wade~~ SUBJECT: Petroleum Inspectdr BOP Test Nordic 1 PBU G-09a PTD 98-263 January 17,1996: I waived a BOP test on Nordic I CTU drilling rig. They couldn't get the top pipe/slip rams to hold pressure. After exhausting their options, they called and asked if they could continue with their well program. They discussed the option with their supervisors and after visiting them I could not envision a potential safety problem as they had a set of pipe/slips in the lower BOP stack. I allowed them to continue. SUMMARY: Allowed Nordic I to start drilling after top pipe/slip failure. Parts on order and installation to be done as soon as parts arrive. Attachments: cc; NON-CONFIDENTIAL TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 7, 1999 Ted Stagg Coiled Tubing Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit G-09A BP Exploration (Alaska) Inc. Permit No: 98-263 Sur Loc: 2367'WEL, 2664'SNL, Sec. 12, T11N, R13E, UM Btmhole Loc. 542'EWL, 2350'SNL, Sec. 13, T1 IN, R13E, UM Dear Mr. Stagg: 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 laxv 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. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK,t IL AND GAS CONSERVATION Cf 'MISSION PERMIT TO DRILL 2O AAC 25.OO5 CT Sidetrack well la. Typeofwork ___Drill [~Redrill I1b Typeofwell [--I Exploratory I--IStratigraphicTest [~ Development Oil [] Re-Entry [~ DeepenI ' E~]Service [] Development Gas E]Single Zone E~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska)Inc. KBE=64.14 Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box196612, Anchorage, Alaska 99519-6612 ADL 028285 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2367' WEL, 2664' SNL, SEC. 12, T11 N, R13E, UPM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 881' EWL, 4271'SNL, SEC.13, T11N, R13E, UPM G-09A At total depth 9. Approximate spud date Amount $200,000.00 542' EWL, 2350' SNL, Sec. 13, T11N, R13E, UPM 1/12/9~ 12. Distance to nearest property line 113. Distance to nearest well ~ 4. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028280 @ 2350'I No Close Approach 2560 11,862', 8965'TVD 16. To be completed for deviated wells i17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9950' Maximum Hole Anqle 9o° Maximum surface 3350 psig, At total depth (-I-VD) 8800', 3936 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) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2888 8974 7898 11862 8965 il 13 c.f. ~ . 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~ ~ ~:~' ~ ~ ~ t- ._:: ~ Present well condition summary ...~- ;~-; '~ iq® Total depth: measured 10364 feet Plugs (measured) ~;.:L...--~..-'. true vertical 9160 feet / Effective depth: measured 10317 feet Junk (measured)~,!~S'~(¢ ~il k, ¢,~.~ ¢:~¥?S- true vertical 9118 feet "~,*,*' .... Casing Length Size Cemented MD TVD Structural Conductor 20x30 8 c.y. concrete 110' 110' Surface 2642 13-3/8" 3440 c.f. Arcticset II 2672 2672 Intermediate 9452 9-5/8" 1300 c.f. Class G 9481 8356 Production Liner 1383 7" 336 c.f. Class G 8976-10359 7929-9120 Perforation depth: measured {10015'-10049',10053'-10084',10101'-10125',}sqzed 10130'-10133',10143'-10149' true vertical subsea {8788'-8818', 8821 '-8863'} 8889'-8892',8901 '-8906 20. Attachments [] Filing Fee [] Drilling Fluid Program [] Property Plat [] Time vs Depth Plot [] BOP Sketch [] Refraction Analysis [] Diverter Sketch [] Seabed Rep Contact Engineer Name~Number? Ted Stagg 564-4694 Prepared By Name/Number: Theresa Mills 564-5894 21. I hereby certify t%~s trUesigned and correct to the best of my knowledge . Ted $~aa~ ~-~.,¢.-~_-~ Title Coiled Tubing Drilling Engineer Date /'/ ~'~' Commission Use Only Permit Number I APl Number I A?~°v¢' Dat~ I See cover letter /,~'~... ~_~ ~.~ 50- (D ~ ¢ --- .2. d:~ ,.¢"' ~'.2, "' 0 / ¢' for other requirements Conditions of Approval: Samples Required [] Yes '~ No Mud Log Required[] Yes~ No Hydrogen Sulfide Measures [] Yes ~ No Directional Survey Required ~ Yes [] No Required Working Pressure for DOPE [] 2k; [] 3k; [] 4k; ~j~ 5k; [] 10k; [] 15k Other: ORIGINAL SIGNED BY by order of / ~) ~,~? Approved By o,,~rt N Christensofl Commissioner the commission Date Form 10~401 Rev. 12-01-85 Submit In Triplicate BPX G-09a Sidetrack Summary of Operations: G-09 is a poor cycle producer with no gas shut off remedial options. The sidetrack, G-09a, will target remaining Zone 1 and Zone 2 LOC.. This sidetrack will be conducted in two phases. Phase 1: set whipstock and downsqueeze abandonment cement: Planned for 1/4199. · G-09 will be tested for tubing integrity and drifted for the whipstock. · A Kinley caliper has been run and the tubing/liner found to be in good condition. · A permanent whipstock will be set on ELine at approximately 9,940' MD. · Existing perforations will be abandoned with approx. 25 bbls cement. Abandonment cement will be downsqueezed past the whipstock and squeezed to 1500 psi with AOGCC witness. This procedure is described in more detail in the Form 10-403. Phase 2: Mill Window and Drill Directional Hole: Planned for 1/12/99. Directional drilling coil tubing equipment will be rigged up and utilized to mill the window (if not done by service coil) and drill the directional hole as per attached plan. The completion will be a fully cemented 2 7/8" liner. Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Liner Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 8,974' MD and cemented with approx. 22 bbls. cement. The well will then be perforated with coil tubing conveyed guns. Well Control: BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional: - See attachments. - Kick Off: 9,950' MD (8,731' -I-VD ss) - TD: 11,862' MD (8,965' -I-VD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging: · A Gamma Ray log will be run over all of the open hole section. · Phase resistivity log will be run in open hole prior to running the liner. Mud and Cuttings disposal: All waste mud and cuttings will be injected at the CC2 facility. Drilling Hazards: No faults are lost circulation zones are expected on this sidetrack. TREE: McEVOY 6" WELLHEAD: McEVOY ACTUATOR: OTIS 9-5/8 D.V. PACKER I 2584 13-3/8", 72#/ft 1267,2 L-80, BTRS KOP: 2700 MAX ANGLE= 42° @ 6643' 5-1/2", 17#/ft, L-80 IJ4S TUBING TUBING ID: 4.892" CAPACITY: 0.0232 BBL/FT 4-1/2", 12.6#/ft, L-80 TAILPIPE TOP OF 897'5 7" LINER 9-5/8", 47#/ft, [ 9481 N-80, BTRS PERFORATION SUMMARY: REF: LOG: BHCS(DA) 5/26/81 INTERVA OPEN/SQZ'D SIZE ISPFI i 10002-10007 - 10015-10049 -7/8 I I10053-10084 3-3/8 14 I 10143-10173 3-3/8 I~ ] 10177-10184 3-3/8 I~ ] 10189-10199 3-3/8 I~ 110205-10213 3-3/8 16 I 10125-10133 I PBTD 7", 2§#/ft, N-80, BTRS G-09a Proposed Completion 0317 )PEN 7/24/98 Sqzd 8/93 Sqzd 8/93 Open 8/96 Sqzd 8/93 Open 8/14/93 Open 8/14/93 Open 8/14/93 Open 8/14/93 Reperf 11/94 Reperf 11/94 0354 J KB. ELEV = 64.14 BF. ELEV = 35.54 SSSV LANDING NIPPLE I (CAMCO BAL-O)( 4.562" ID) 2096 GAS LIFT MANDREL (CAMCO W/ RK LATCH/ Mo ~n~v~ ,-P/Doc ~k "'~' 2919 11 5103 4822 10 6269 5796 9 6416 5915 8 7O70 6453 7 7215 6574 6 7660 6951 5 7801 7O72 4 8217 7440 3 8364 7572 2 8627 7807 1 8766 7931 {KED SLIDING SLEEVE [ (CAMCO)(4.500" ID) 8834 TBG SEAL ASSY (SBR) 9-5/8" BAKER PKR I 8816 (4.00" ID) 1 4-1/2 .... X" NIPPLE 8959 (OTIS) (3.813" ID) 4-1/2 .... ×N" NIPPLE 8991 (OTIS) (3.725" ID) 4-1/2" TBG TAIL (ELMD) .2 7/8" Cemented Liner Whipstock approx. 9940' MD (still there 1/94) 8896 9023 9025 9990 -~-09a CT Drilling & Completion BOP LU O 22.5" 2 3/8" CT ~-~ 110,000 psil 7 1/16" Annular 1/16" 5000 psi Blind/Shear 7 1/16" Pipe/Slip 7 1/16" x 5,000 psi 7 1/16" x 5,000 psi Slips 7 1/16" Pipe 7 1/16" x 5,000 psi 2 3/8" 2 7/8" 2 3/8" SWAB OR MASTER VALVE -3,000 -2,500 G-09 -2,000 X distance from Sfc Loc -1,50 -3,000 , -1 ,~)00 -3,500 -4,000 -4,500 -5,000 -5,500 Well Name G-09 I CLOSURE Distance 5,502 ft I Az 204 deg I NEW HOLE E/W (X) N/S (Y) Kick Off -1,708 -3,352 TD -2,263 -5,015 State Plane 655,598 5,963,962 Surface Loc 657,861 5,968,977 DLS deg/100 Tool Face Length Curve 1 6 0 30 Curve 2 17 -20 371 Curve 3 8 -90 399 Curve 4 6 90 599 Curve 5 6 180 64 Curve 6 6 90 449 1,912 Drawn: 12/17/98 13:45 Plan Name: Case 201 G-09 Vertical Section 8300 8350 ~TSHU: 8400 8450 8500 8550 8600 TZ 8650 870O 8750 8800 885O 890O 8950 9000 9O5O 8,935 5OO Path Distance (Feet) 1,000 1,500 2,000 2,500 Room is available above this sidetrack for a future sidetrack below TSHU Angle @ K.O.= 29 deg MD:9950 3,000 11862 TD Marker Depths @Orig Wellbore TSHU TZ2C TZ3 8,9651 8,9651ft 1-VD I 8,3901, TVD [ 8,7041~TVD I 8,6381f~TVD Kick Off 8,731 If"[ -I'VD 9,950Jft MD Deprtr @KO 3,778 ft MD KO Pt 9,950I MD New Hole 1912I I Total MD 11,862I TVD TD 8,9651 DLS deg/100 Tool Face Length Curve 1 6 0 30 Curve 2 17 -20 371 Curve 3 8 -90 399 Curve 4 6 90 599 Curve 5 6 180 64 Curve 6 6 90 449 1,912 Drawn: 12/17/98 13:45 Plan Name: Case 201 BP EXPLORATION, (ALASKA)INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 PAY To The Order 0¢ NATIONAL CITY BANK 56-389 Ashland, Ohio ~ No. P 006500 CONSOLIDATED COMMERCIAL ACCOUNT ONE HUNDRED'-&:. OO/i.liO0~*~~*~--~H~~"~~*~~'~ US DOLL~ "::: ~.'~ -:~ - :~::: ':~: ~:' DA~ :~'~::::~:~: ¥:~::~::~: AMOUNT ALASKA STATE DEPT OF REVENUE ' 3OO~ PORCUPINE DR ANCHORAGE AK 9~501-3120 10/98 :i-. :: NOT VALID:AF'rER 1'20 DAYS $100. O01 ~1'00~50011m m.'Oh 1. ~03~]Sm-' 0 J- ~?R~,ll' 3AM 06 '99 10:46~M BP E×PLON~IION ~,l FAX MESSAGE Jan 6, 1999 To: Blair Wondzell AOGCC From: CTD Drlg. Eng. Subject: Change in CTD schedule BP's coil drilling rig was scheduled to move onto S-08a this week and all permits are in place. However, it appears that an exploration well will be spudded in the vicinity of S Pad. Air quality issues associated with the exploration well make it impossible for coil drilling to work on S Pad while this exploration well is in progress. For this reason I am requesting approval of the Sundry notice and Permit to Drill for well G-09a. These applications were submitted on 12/18/98. I expect the rig to be ready to move onto G-09a on 1/8/99. I apologize for the short notice on this change in plans. Please call if further information would help in your review of these permit applications. I. I~ernlit tee attached ............ 2. I ease ilumber appropriate .......... 3 LJ~fique well name and numbe~. 4 Well I(~(:aled iii ~1 defined pool.. 5 Wull Io(:aled p~ol)e~ distance f~olll d~illi~lg u~lit I)otHl(hlfy 6 Well Iocaled proper distance flOra other wells .... 7 Sulficienl acreage available in drilling tufil . . 8 If deviated, is wellbore plat included .......... g. Ope~alor only affected pady ............... 10. Operator has appropriale bond in force ............. 11. Permil can be issued wilhoul conse~ation order ........ 12 Pei~lil can be issued wilhout administralive apploval ...... 13. Can I)errnit be approved before 15-day wait ........... GEOL. AREA Y N Y N ....................... Y N Y N Y N Y N Y N Y N' - Y N t' N ........................................................ Y N ADMINISTRATION ENGINEERING 14 C(),ld,,clor string provide, d .......... 15. Sulfate casing protects all known USDWs ......... N 16 CMl' vol adequate to circulate on conductor & surf csg ..... N 1'7 CMI vol adequate to tie-in long string to sulf csg ........ Y N 18. CMI will cover all known productive horizons ......... f~ N l g. Casing designs adequate for C, T, B & permafl'ost ....... ~ N 20. AdeqHale lankage or reserve pit ................ (~) N 21 If a re-drill, has a 10-403 for abandonmenl been approved.. 22. Adequate wellbore separation proposed ............. (~) N 23. If diveder required, does it meet regulations .......... '~::::!~'"~ ................................... 24. Drilling fluid program schematic & equip Iisi adequale. .... g¢~ NN .__ .............................................. 25. BOPEs, do lhey meet regulation ................ APPI;~ DAtE 26. BOPE press rating appropriate; test to ,,~'d)(3~::~ psig. <:~ N ............................................................. I'2[~Sf~5iB 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~ N 28 Work will occur without operation shutdown ........... N ................................................... 29. Is plesence of I--12S gas probable ................ N ~-~LOGY ............................ 31. 32 33 APl )1~ I )A l [.:: 34 ANNULAR DISPOSAL AI'I't~ I)AII Y N Y N t)e~nfit can be issued w/o hydrogen sulfide measures ..... Y N/.._ . Dala presenled on potential overpressure zones ....... Y,~-~ "--~ ......... Seisinic analysis of shallow gas zones ..... ' ........ Seabed condition survey (if off-shore) ............ / Y N ............... Contact name/phone for weekly progress I'el0orts ..... Y N l'exploratory only] ........................................................ Wilh pr'oper cemenling records, this pla~ (A) will con~sle in a suitable re__zone; .... Y N (il) will ~ot c~~t~.';('; (hillin!l wash?. Y N to stu'face; / ~ (C) will Ilol impa'~ical integrily oRl'm-~l used for disposal; (I)) w~~nor impair lecovery flora a po(fi; and Y N .................................... _(,E.') will not circumvent 20 AAC 25.252 or 20 AAC 25.412. .G...E_'.OI. QG Y: F_NGLN__E_.EBLNg: Ul~r COMMISSJO_~ ,ID~ RNC ............... , ~...:..::.-=..:::;.-.::::-.:. :.. . ....................................................................................... Itll (' \flp,Ilihl ,l\W(ItlJl;Ifl\tJI, Ht, l',, lu' ltl I Cornmentsllnstructions: 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 SRevision: 3 $ LisLib SRevision: 4 $ Mon Feb 19 15:36:11 2001 Reel Header Service name ............. LISTPE Date ..................... 01/02/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/02/19 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 MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD G-09A 500292058201 BP Exploration (Alaska), Inc. Sperry Sun 19-FEB-01 1ST STRING MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MW-90064 AK-MW-90064 AK-MW-90064 BUD JAHN B. JAHN B. JAHN C PARKER C PARKER C PARKER 12 lin 13E 2664 2367 64.14 64.14 35.34 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 13.375 2672.0 2ND STRING 3.750 9.625 9481.0 3R~ STRING 3.750 7.000 9925.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-3 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. DIGITAL DATA ONLY IS DEPTH SHIFTED/CORRECTED TO THE PDC GAMMA RAY LOG (SCHLUMBERGER CPNL OF 09/06/00) WITH KBE=64.14'. LOG AND LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 4. MWD RUNS 1-3 REPRESENT WELL G-09A WITH API#: 50-029-20582-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11476~MD, 8938'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/19 Maximum Physical Record..65535 File 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. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9911.5 11436.5 ROP 9917.0 11468.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9911 5 9931 9933 9936 9952 9955 9958 9986 10013 10016 10018 GR 9911.5 9931 5 9934 0 9936 5 9952 5 9956 0 9959 0 9987 5 10013 5 10017 0 10019 5 EQUIVALENT UNSHIFTED DEPTH 10021 10024 10027 10031 10065 10104 10107 10129 10131 10135 10146 10178 10188 10214 10218 10221 10224 10226 10228 10232 10301 10302 10358 10411 10423 10436 10459 10462 10464 10469 10475 10479 10618 10624 10629 10632 10639 10642 10646 10651 10654 10659 10662 10665 10678 10690 10697 10709 10714 10778 10780 10782 10785 10787 10795 10797 10805 10809 10814 10815 10818 10820 10828 10954 10022 10025 10028 10031 10067 10105 10108 10130 10132 10137 10148 10180 10191 10216 10220 10223 10225 10228 10230 10234 10304 10305 10363 10413 10426 10438 10461 10464 10466 10471 10477 10481 10622 10628 10634 10637 10643 10646 10651 10655 10658 10663 10667 10669 10682 10694 10703 10715 10720 10786 10787 10789 10793 10794 10802 10804 10812 10816 10821 10822 10826 10828 10835 10961 10959 0 10989 10994 10997 11007 11009 11011 11013 11027 11038 11043 11065 11154 11212 11240 11242 11256 11268 11272 11290 11293 11296 11303 11318 11326 11468 $ 5 0 5 5 5 5 5 5 0 0 5 5 0 0 0 0 5 5 0 5 0 0 5 0 5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 10967 0 10997 0 11002 0 11005 5 11014 5 11016 5 11019 5 11021 5 11035 5 11045 5 11051 5 11074 0 11162 0 11219 5 11247 5 11251 0 11265 5 11279 0 11283 0 11300 0 11302 5 11305 5 11312 5 11327 0 11334 0 11476 5 BIT RUN NO MERGE TOP MERGE BASE 1 9912.0 10350.0 2 10350.0 11168.0 3 11168.0 11476.0 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 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 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9911.5 11468.5 10690 3115 ROP MWD FT/H 4.82 2574.8 97.6353 3104 GR MWD API 9.61 299.96 36.7197 3051 First Reading 9911.5 9917 9911.5 Last Reading 11468.5 11468.5 11436.5 First Reading For Entire File .......... 9911.5 Last Reading For Entire File ........... 11468.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/19 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 ....... 01/02/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9911.5 10322.0 ROP 9917.0 10349.5 $ LOG HEADER DATA DATE LOGGED: 20-JAN-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 10350.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL {FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 28.9 MAXIMUM ANGLE: 81.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS TOOL NUMBER PCG 072 3.750 9925.0 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 Depth Units ....................... Datum Specification Block sub-type...0 Flo-Pro 8.90 .0 9.3 45000 5.2 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 58.6 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 9911.5 10349.5 10130.5 877 ROP MWD010 FT/H 31.62 2574.8 153.912 866 GR MWD010 API 17.56 299.96 33.8074 822 First Reading 9911.5 9917 9911.5 Last Reading 10349.5 10349.5 10322 First Reading For Entire File .......... 9911.5 Last Reading For Entire File ........... 10349.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/19 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 GR 10323.0 ROP 10350.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 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: STOP DEPTH 11140.0 11168.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BlT 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: 21-JAN-99 Insite 0 Memory 11164.0 85.7 91.6 TOOL NUMBER PCG 055 3.750 9925.0 Flo-Pro 8.80 .0 9.3 44000 5.4 .000 .000 .000 .000 .0 65.6 .0 .0 Dat HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: a 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 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 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10323 11168 10745.5 1691 ROP MWD020 FT/H 4.82 126.97 75.9436 1637 GR MWD020 API 9.61 113.43 40.3679 1635 First Reading 10323 10350 10323 Last Reading 11168 11168 11140 First Reading For Entire File .......... 10323 Last Reading For Entire File ........... 11168 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/19 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 ....... 01/02/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 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 GR 11140.5 ROP 11168.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 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: STOP DEPTH 11444.5 11476.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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 22-JAN-99 Insite 0 Memory 11476.0 87.1 90.9 TOOL NUMBER PCG 072 3.750 9925.0 Flo-Pro 8.90 .0 8.9 50000 5.8 .000 .000 .000 .000 .0 70.3 .0 .0 Max frames per record ............. Undefined Absent value ...................... -999 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 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 11140.5 11476.5 11308.5 673 ROP MWD030 FT/H 34.28 1033.33 78.71 617 GR MWD030 API 21.7 55.63 30.9908 609 First Last Reading Reading 11140.5 11476.5 11168.5 11476.5 11140.5 11444.5 First Reading For Entire File .......... 11140.5 Last Reading For Entire File ........... 11476.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Versio,n Number ........... 1.0.0 Date of Generation ....... 01/02/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/02/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/02/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File