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200-113
STATE OF ALASKA ALASKA~ AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ,~ Abandoned ^ Suspended zoaaczs.~os zoa~c2s.,~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. lass: ~ ~ Developm~~~E~ploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7/4/2009 12. Permit to Drill Number 200-113 ~ 309-200 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 08/21/2000 13. API Number 50-029-22651-01-00~ 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 08/29/2000 14. Well Name and Number: PBU 15-49A ~ 4676 FSL, 5165 FEL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 4972' FSL, 914' FEL, SEC. 22, T11 N, R14E, UM 8• KB (ft above MSL): 67.3' ~ Ground (ft MSL): 32.7' 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4721' FSL, 2199' FEL, SEC. 22, T11N, R14E, UM 9. Plug Back Depth (MD+~/p) 9408' 8256' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 676031 y- 5960879 Zone- ASP4 10. Total Depth (MD+~/D) 11736' ~ 8772'~ 16. Property Designation: ADL 028306 ~ TPI: x- 680274 y_ 5961276 Zone- ASP4 Total Depth: x- 678996 y- 5960995 Zone- ASP4 11. SSSV Depth (MD+~/D) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ~ No S mi el ronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (ND): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD GR & MEM GR / CCL / CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETfING DEPTH ND HOLE AMOUNT; WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 2" 91.5# H-40 urface 110' Surface 110' 30" ~260 sx Arctic Set 9-5/ " 4 rf urf 7' 12-1/ " 1030 sx CS III, 305 sx'G', 345 sx CS II 7" 26# L-80 Surf ce 9355' Surfa 213' 8-1/2" 200 sx Class'G' 4-1/2" 12. L- 9198' 9751' 8088' S44' 6" 325 sx Class' ' 2-7/ " .# -8 447' 117 6' 8' 7' 4-1 /8" 122 x LAR 23. Open to production or inject ion? ^ Yes ~ No 24. Tus~NC RecoRo If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): Size DearH SeT MD PACKER .SET MD 4-1/2", 12.6#, 13Cr80 / L-80 9212' 9069' & 9177' MD TVD MD ND ZrJ. ACID, FRACTURE, CEMENT SQUEEZE, ETC. u i - ~f}~~`~; ° i ~- ~ . , DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 4: .~.. # 9 ,, ~ 4 ~'•' 9408' Set Whipstock ZB. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N!A Date of Test: Hours Tested: PROOUCT~or, FoR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Ca~cu~.areo 24-HouR Rnre• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API ~CORR~: 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ~ No Sidewal l Core s Ac uired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summari2e 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 per 20 AAC 250.071. &+," :s'~~ ~ 3 . , None # ~~1 ~y F ~ ~ s . . ~ ,.~:..... - `f ~~~~~~~~~~~~ ~:~ ~~ iy, 43 4~ 2(~0~ . r~ FOfRI ~0-407 R6VIS@C~ OZIZOO7 CONTINUED ON REVERSE SIDE ~,'• -_~~~ ~ ,~t; R~ ~~~~~ ~% ~~~~}~ ~. _ . _ ~ ~~f~ ~~ ~ ~ ZS. GEOLOGIC MARKERS ~LIST ALL FORMATIONS AND MA S ENCOUNTERED~: Z9. FORMATION TESTS ~ NAME M TVD Well Tested? Yes ~ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Zone 1 B 9980' 8720' None Zone 1 B 9988' 8725' TDF 1 Zone 1A 10064' 8771' TDF / Zone 1A 10066' 8772' TDF / Zone 1A 11277' 8787' TDF / Zone 1A 11322' 8781' 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 foreg 'ng is true and correct to the best of my knowledge. ~~ / ~~ ~ Signed Terrie Hubble ' Title Drilling Technologist Date PBU 15-49A 200-113 309-200 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A roval NO. Drilling Engineer: Ron Phillips, 564-5913 INSTRUCTIONS GeNew-~: 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. IreM 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. IreM 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. Ir~M 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the Iocation of the cementing tool. IreM 23: If this welt 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). Irena 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 AAC 25.071. IreM 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 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • • 15-49A, Well History (Pre Rig Sidetrack) Date Summary 6/15/2009 WELL S/I ON ARRIVAL. RAN 10' x 3.70" DMY WHIPSTOCK TO DEPLOYMENT SLV C~ 9423' SLM. RAN 3.0" LIB TO 9423' SLM, VERIFIED SITTING ON DEPLOYMENT SLV. WELL LEFT S/I, JOB COMPLETE. 6/18/2009 T/I/0=2360/480/300 Temp=Sl MIT IA PASSED to 3000 psi, MITOA FAILED to 2000 psi (Pre CTD). Pressured up IA to 3000 psi with 4 bbls crude. IA lost 160 psi in the 1 st 15 mins and 20 psi in the 2nd 15 mins for a total pressure loss of 180 psi in 30 min test. Bled back 3 bbis crude. ~VIIT OA : OAP never pressured ua to 2000~si. Established LLR-OA of 4 bpm C«~ 1250 psi for 30 bbls without chanae. OAP bled down to 500 psi in 30 min after shut in. Bled back 1 bbl. Final W HP's = 2320/480/220. Operator notified of valve positions as SV, WV, SSV = closed. MV, IA, OA open at departure. 6/19/2009 T/I/O=SSV/500/300, Temp=Sl. PPPOT-T (PASS), pre CTD. PPPOT-T: Stung into test port (500 psi), bled to 0 psi. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS (ET style), all moved freely. 6/26/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O: 2400/450/300 PSI. SET BAKER 45 "KB" WHIPSTOCK AT 9414'. BOTTOM OF WHIPSTOCK AT 9430'. PIP TAGS INSTALLED AT 9423'. THIS IS CORRELATED TO HORIZONTAL LINER SUMMARY DATED 4/3/96 WITH FIRST FULL JOINT OF 4.5" LINER AT 9226.34'. FINAL T/I/O: 2400/450/300 PSI. WELL LEFT SHUT IN. JOB COMPLETE. 6/26/2009 T/I/0=2350/360/280. Temp=Si. Bleed TP to CLP. (Pre-CTD/FB). 81ed TP from 2350 psi to 250 psi in 30 minutes to Prod down flowline. IAP decreased 10 psi to 350 psi during 7P bleed. No change in OAP during TP bleed. Final WHP's = 250/350/280. SV, SSV & WV = CLOSED. MV = OPEN. IA & OA = OTG. NOVP. 6/27/2009 T/I/0=250/420/300, Temp=S/I MIT-T PASSED to 1000 psi, (CTD Prep) Loaded tubing with 138 bbls of 90° crude. Pressured up tubing with 7 bbls of 90° crude to reach 1000 psi. MIT-T lost 0 psi in 1st 15 minutes and 0 psi in 2nd 15 minutes for a total loss of 0 psi in a 30 minute test. Bled tubing psi down flowline. FWHP's = 200/480/300, Swab, Wing = Shut/ Master, SSV, IA, OA = OPEN. 6/28/2009 T/I/O=Vac/410/290. Temp=Sl. Bleed W HP's to 0 psi (pre-CTD). No AL. IA FL near surf. OA FL @ surf. Bled IAP from 410 to 1 psi (all gas). Bled OAP from 290 psi to 190 psi (all fluid, 25.5 bbls) in 5.5 hrs. Monitored 30 mins. IAP increased 7 psi, OAP increased 10 psi. Final T/I/O=Vac/8/200. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 6/28/2009 T/I/O = 0/400/300 Pressure test down on swab 4500 qsi for 15 min with no loss ( pass ) pressure test tree master and winq 4500 psi for 5 min with no loss ( pass ) and service tree with 601 clare. Page 1 of 1 ~ ~ $P EXPLORATION Page 1 ~ Operations Summary Report Legal Well Name: 15-49 Common Weil Name: 15-49 Spud Date: 3/12/1996 Event Name: REENTER+COMPLETE Start: 7/2/2009 End: 7/17/2009 Contractor Name: NORDIC CALISTA Rig Release: 7/17/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From -To Hours Task Code NPT Phase Description of Operations 7/2/2009 16:00 - 16:15 0.25 RIGU P PRE SAFETY MEETING. PJSM for moving off well 07-28B. 16:15 - 18:00 1.75 RIGU P PRE Conduct final walk arounds and prep rig to jack up. Jack up rig and roll forward to a suitable spot for lowering windwalls. Set rig down, prep for lowering windwalls. Remove Geronimo line, unpin walls, hook up loader. 18:00 - 19:00 1.00 RIGU P PRE Lower windwalls, continue prep to move. 19:00 - 20:00 1.00 RIGU P PRE Move from back of DS7 to Oxbow road. 20:00 - 00:00 4.00 RIGU P PRE Travel Oxbow road to DS15, around backside of pad to spot rig in front of 15-49. 7/3/2009 00:00 - 01:30 1.50 RIGU P PRE Remove windwalls 01:30 - 02:30 1.00 RIGtJ P PRE Move rig over well. 02:30 - 03:30 1.00 RIGU P PRE Secure rig over 15-49 `*'*"'**""'*'Accept Riq at 02:30 03-Ju1y-09'**"'**`*"*" 03:30 - 08:00 4.50 RIGU P PRE Remove tree cap, NU BOPE. Re- attach guy wires and put away slings, clear rig floor. 08:00 - 14:30 6.50 BOPSU P PRE Test BOPE """Witness waived by Bob Noble, AOGCC'"""' Test Annular, Blind / Shears, 2-3/8" Combis, 3-1/2" x 2-3/8" VBR, Lower 2-3/8" Combis, Choke manifold valves and both TIW valves. 14;30 - 15:30 1.00 RIGU N WAIT PRE Wait on 550 bbls 2# biozan, was scheduled to arrive at 12:00. 15:30 - 16:50 1.33 RIGU P PRE Fluid arrives, start filling pits. Cut off CT connector and cable, re-boot cable. 16:50 - 17:30 0.67 RIGU P PRE Fill reel backwards. Pump 4 bbl/min to shift cable. 17:30 - 18:05 0.58 RIGU P PRE Hook up hydraulic CT cutter. Cut off first piece of CT, cable is there. Remove hydraulic cutter, re-boot cable. 18:05 - 18:30 0.42 RIGU P PRE Get on well, pump fresh water backwards 4.6 bpm. 18:30 - 19:30 1.00 RIGU P PRE Rig up coil cutter, Cut 380' of coil, rig down coil cutter. 19:30 - 20:00 0.50 RIGU P PRE Stab onto well. Pump fresh water backward to clean coil for head up. 20:00 - 21:20 1.33 RIGU N SFAL PRE Test continuity in eline. Good continuity, slight bleed through...15 M-ohms at 500V, should be 40 M-ohms at 500V. Check bulkhead junction box for moisture. Moisture found. Dry out junction box. Check current bleed again - low. Good test. 21:20 - 00:00 2.67 RIGU P PRE Connect coil connector, head up e-line to UQC. Pressure test coil and inner ree! valve to 3500 psi. Install Dual Checks in UQC. Open well, very slight vacumn. 7/4/2009 00:00 - 01:00 1.00 STWHIP P WEXIT MU mill, motor, 2 joints PH6, CoilTrak, test tools. 01:00 - 03:15 2.25 STWHIP P WEXIT RIH, 100 fpm, .26 bpm in, 0.8 bpm out, IA= 192 psi, OA= 217 psi, Cir Press = 363 psi 03:15 - 03:45 0.50 STWHIP P WEXIT CCL tie-in to SLB Whipstock setting log 26-Jun-09. (No gamma ray character in the area above whipstock where we need to tie-in). CCL has good correlation to jewelry. Taking pockets of gas while circulating out brine. 03:45 - 05:00 1.25 STWHIP P WEXIT Circulate gas cut brines from tubing to tiger tank. ~L ~ . el displaced to biozan, tag pinch point 9413'. Begin mi ing. ~\ Taking on biozan. 2.4 bpm in, 2.4 bpm out, Cir re~is -- '$ ,'T `5'~9~ IA=269 psi, OA=530 psi. 06:20 9413.30 ft 1.12 Klbs DWOB 2.54 bpm @ 2140 psi ~~ ~~ 07:00 9413.40 ft 1.05 Klbs 2.68 bpm ~ 2245 psi 08:00 9413.70 ft 1.01 Klbs 2.63 bpm ~ 2161 psi Printed: 7/29/2009 3:05:51 PM _ ....._._ NEL.~NEAI]- ... .~ CItiN ~ 1CTUA~'t'~F~•= . _ r 6AkEE~ C _ .B. ELL)J = tt....~n f7.3' 3F. ELEV - ? :Qf''= _ 1141" Aax Angl~ = ~7~ ~ f 26Q a' Yatum MD = f 2654" ?atumN~ ~ "Rd~ ~$7t3~'S~ S~~FETY NOT~5:1111ELL ANt~E ~ 7t}° d~ 't~17~0 ~ ` ~.-{4°112" X NIP, 1Q = 3.Si 3„ GA5 LI~AMN~R~LS s-~~s~~ c~~. aa#, L-sa, ~u = s.a~~° I---I 3ss~. 1!°~~~~ ~~ »~ ~.~°~" ~~`7'T~ ~~r~~~ T~~ ~~~ ~r B~ker ~+-11~°' Lin~r °f~p t~`ac4~er, I[~ _~ 3~ a'" -~ 9Q~~' ........~ 1 f2" ~G, 12.6#, i 3Gr-~3fl, a152 hpf', ID = 3.958`. 913'~` Tf1F f3F 4-1 t2" LNR~- 919~' 4112"' TB~, 12 ~#, t~-80, .~152 bpF, IO = 3.958" +~2~ ~' - 7" CSG, 26#, L-8~, ID = 8.276" ' 935a~" 3.7" ~plQy'rr~rrt sie~ve, IC~ = 3.~" ~--~ ~~,~3• ~~k~r KB Vtlh~ps#DC1c ~-~ ~• ~ ~4 I~R'FORATK7N SUIt+~tRY R~F ~Qt,~; S~:B N1GUL t17-15-2{~d~ A t~fGL~ A T TG3F' ~"~F: 9~° ~# 04tat?` R~te: Refer tca F"roductian D8 for h~stc~r~cal perf data S~ZE ~PF IMiTERtlAL t?pniSqz L7ATE ~" ~ 1 J~t~l - i p~~U (J C17tt 61{l~ ~" 4 1 D~~4~ - 19 3~{3 {3 CJ7t'6 fiJ(T~ 2" 4 ~ 1~7i3 -~ 1755 ~ fl71~ ~t~99 z.. a ~ t~~~ -~~t~~ ca t~~~t s~~ ~'° 4 9 21 ~~ - 1 z34t~ ~1 fl71161~~ 4112" ~NR, 12.6#, L-80, .01S2~Spf, If3=3.~58" 3 I~{~02~7934'I 38 I K~~-1I ~ I BK (~C) 9{?~8' 4-112" HES X Nlf', I[7 = 3.$13~" ~~s~~- ~° x ~-,iz~; ~~.x~ ~-~ ~~ T._,..,. 3'i {33` 4-112'" hlES X N1P, 1[3 = 3.813'~ 9'~33~ 7op ~f 4.5° Tbg Stub 9'~3'~! E1tVIGtUEfVtACHIPl~~1/ERSFK~T 9'[ 77'° 7" X 4'tC~" 6AK~ S-3 F~IfR $2UU" 4-112" HES k I~IP, ID = 3.$13'` ~ I MILLOUT WINDOW (15-49B)) ?????' - ?????' I 9373f 3-4t2", 8,89#, L-8D STL Lt~R ~3$3~ 3-112" X 3-3I16" XQ: Id = 2.9~J5,~ °~ ~~~~" -~3-314~", 6.2#, ~-8t} TCIi cere~nted LNR w; t€~rbc~s 1037T ~op of 10' 3-3116" TCII l~narker Jt 1~}386' 3-3(1 B X 2-7i8„ X~„ ~ PBTC} °t2614" 2-~18", 6,1 ~, L-Bt~ S~'L cert~~ted LN~ ~ f turhns ~~ °~ ~~ , FISH- CtgP []EBRkS ' (~~ [~~~ aa/2~fosj ; 11C!$fl" _ 2-118" 9~€" LNR„ fi.5# L-84, .4tF579 bpf„ IE~ - 2.387" ] 1~.. PRUC~FiC7E 6AY [1NC1` VUELt: 15-498 PEf~Niff' ~lo: 2t79(}G~ APP No: ~d-f}28-22651-0°~ 5EC 22, T11 N, R14E, 397~F.84' FE~ & 772.12` FNL BP E~cp[oration (Alaskaj 4f L ;. f Wis. CO • • f d q ~ ~7 ~ ~ k ~' ~ ~ f' p~y ~ F " ' : ~ , ~ y ~ ~ ; ~-~ ~ ~~ ~ ~ S ~ ~~ SARAH PAUN, GOVERNOR ~~ ~~' ~.~ ALASFA OII. AI1TD GA5 333 W. 7th AVENUE, SUITE 100 1~T5ER~ATIOI~T COMDII55IO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Q O ~'~~.~ Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 15-49A Sundry Number: 309-200 ;~`.~i~~'~~ .Jill' ,. ~D~~ Dear Mr. McMullen: 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 file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this Z2 day of June, 2009 Encl. Q~ STATE OF ALASKA r ,~~~ ALA OIL AND GAS CONSERVATION COMIV~ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~"~ ~ J li w ~~~ ~ ~ ZOC±±~ COt~~~. ~ ~-`~~"'i~l3SI 1. Type of Request: ®Abandon - ^ Suspend ^ Operation Shutdown ^ Perforate e ~h, ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter SG~EhI~dell ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development~ ^ Exploratory 200-113 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22651-01-00 - 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 15-49A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028306 - 67.3' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11736' - 8772' - 11702' 8773' 11090' 11040' in Len th Siz M TVD B r Coll Structural nd tr 110' 2" 11 11 14 470 Surface 3667' 9-5/8" 3667' 3572' S7 3 Intermediate 9355' 7" 9355' 8213' 724 541 Pr Liner 5 4-1/2" 9198' - 9751' 8088' - 8544' 8430 7500 Liner 2289' 2-7/ " 9447' - 11736' 8288' - 8772' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10130' - 11011' 8792' - 8797' 4-1 /2", 12.6# 13Cr80 / L-80 9212' Packers and SSSV Type: (2) 7" x 4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 9069' & 9177' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: July 1, 2009 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ron Phillips, 564-5913 Printed Name Jo Mc ull / Title Engineering Team Leader -,"r- Prepared By Name/Numbec ~ ~ Terrie Hubble, 564-4628 Signature ~ Phone 564-4711 Dated ~5/ Commission Use Onl ~~ ~l pc~:~~~e~~o~~4 S S`i ~C..~. ~ ~ Z~ Sundry Number: '3 _ ~-p Conditions of approval: Notify Commission so that a representative may witness ~~~ ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~~»JpS'~ V`-pv-~'~S~'~ ~~~w~~ ~I~'~r~~~~ ~ ©.iP~h~~C~C-~ ~~~ Subsequent Form_j~equired: ~° '~ APPROVED BY A roved B : ~~ COMMISSIONER THE COMMISSION Date Form 10-403 Re ' e 06/2006 ~ JUN ~ `; 209 submit In Duplicate ~ ,~~- ~~ 9 .~RIGlI~A~ RECEIVED=%u~ To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Ron Phillips CTD Engineer Date: June 10, 2009 Re: 15-49A Sundry Approval CC: Well File Sondra StewmanlTerrie Hubble Sundry approval is requested to abandon the existing 15-49A completion. • by This well was sidetracked with coil in Sept 2000. The well came on at very high GOR and gas rates. An STP in October 2000 showed that the toe was the problem so an IBP was set over the toe in Nov 2000. This reduced the gas rates from 40 mmscfd to ~ 5 mmscfd. The well became a strong fulltime producer for the next 1-1 /2 years until hitting MGOR in the summer of 2002 and becoming a cycle well. The well developed AnnCOMM problems in the summer of 2003. The LDL found 5 tubing leaks scattered from 4806' - 6836' md. The well remained SI until April 2008 when Doyon 16 completed the RWO that replaced the corroded 4-1/2" L-80 TBG with brand new 4-1/2" 13Cr-80 TBG. 15-49A hit MGOR by October 2008. The most recent cycle attempt showed it hitting MGOR within a couple of weeks of being POP even after being SI for over 3 months. The well currently has an uptime of 50% in the last 12 months. 15-49A has no good wellwork options left. 15-49A is in sound mechanical shape. The GLVs were dummied off on 3/15/09. The March 2009 MITIA passed to 3000 psi. The well will be abandoned with a packer and the primary cement job. REASON FOR SIDETRACK: 15-49A shows very little potential for re-charge and possesses no viable wellwork options. The well has a declining ontime and just recently had a RWO that installed a brand new 4-1/2" 13Cr TBG string completion. All these factors combine to make it an ideal candidate for a coil sidetrack. Pre-Rig Work: (Scheduled to begi~ July 1, 2009) • 1. O MIT-IA, MIT-OA, PPPOT-T 2. S DGLV's 3. S Drift with dummy whipstock to 2-7/8" liner deployment sleeve at 9447'. 4. E Set 4-1/2" monobore packer WS at 9425'. 5. O PT to 1000 psi against monobore packer WS. 6. O PT tree (MV, SV, WV). 7. O Blind and bleed lines, remove well house, level pad. j~~5 ~~ 4~0~~.~ Rig P&A and Sidetrack Operations: (Scheduled to begin on August 5, 2009) 1. MIRU Nordic Rig 2. 2. NU 7-1/16" CT Drilling BOPE and test. 3. Mill 3.8" window through 4-7 - 4. Drill build/turn with 4.125" and land well. 5. Drill lateral section with 4.125" to 12,440'. 6. Run and cement a 3-3/16" x 2-7/8" L-80 liner string to 9,385' (30.1 7. In one run cleanout with mill/motor and log GR-CNL. 8. Perforate well. 9. Run a liner top packer and 305' of 3-1 /2" stinger. 10. FP well to 2000' with diesel. 11. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 12. RDMO Nordic 2. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run gas lift design. 4. POP Well bbls of cement planned). 2 FMC WELLHEAQ = CM/ ACTUATOR ~ BAKER C Kfs. H.EV = 67.3' BF. ELEV = ? KOP = 1141' Max Angle = 98 @ 11300' Datum MD = WA Datum TV D = 8800' SS ~ 15 2194' H4-1/2" X NIP, ID = 3.813" GAS LIFT MANDRELS 9-5/8" CSG, 40#, L-80, ID = 8.835" 3667' - Minimum ID = 2.387" @ 9453' 2-7/8" LINER PIN ~4-1/2" TBG, 12.6#, 13Cr-80, .0152 bpf, ID = 3.958" ITOP OF 4-1/2" LNR ~ 9198' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9212' 7" CSG, 26#, L-80, ID = 6.276" ~--~ 9355' TOP OF 2-7/8" LNR 9453' PERFORATION SUMMARY REF LOG: SPERRY MWD GR ON 04/01/96 ANGLE AT TOP PERF: 80 @ 10130' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10130 - 10320 O 09/01 /00 2" 4 10430 - 10560 O 09/01 /00 2" 4 10640 - 10680 O 09/01 /00 2" 4 10797 - 10830 O 09/01/00 2" 4 10870 - 11011 O 09/01/00 2" 4 11150 - 11203 C 09/01 /00 2" 4 11280 - 11650 C 09/01 /00 ~ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~~ 1 ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3851 3749 16 KBG2-1 DMY BK 0 03/15/09 2 7011 6363 40 KBG2-1 DMY BK 0 03/15/09 3 9002 7934 38 KBG2-1 DMY BK 0 04/04/08 9038' 4-1/2" HES X NIP, ID = 3.813" 9069' 7" X 4-1/2" BAKER S-3 PKR 9103' 4-1/2" HES X NIP, ID = 3.813" 9133' 9139' Top of 4.5" Tbg Stub UNIQUE MACHINE OVERSHOT 9177' -j7" X4-1/2" BAKERS-3 PKR 9200' 4-1/2" HES X NIP, ID = 3.813" 9212' 4-1/2" TBG TAIL WLEG 9447' DEPLOYMENT SLEEVE 945 3-1/2" X 2-7/8" XO MILL WINDOW THROUGH 4-1/2" LINER @ 9751' 11040' FISH - CIBP DEBRIS (MILLED 04/23/08) \ 11090' 2-1/8" IBP ~ 2-7/8" LNR 6.5#, L-80, .00579 bpf, ID = 2.387" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 1996 ORIGINAL COMPLETION 05/04/08 LLVPJC PERF /MILL CIBP (04/23/08) 09102/00 SIS-Isl SIDETRACK (15-49A) 03/15/09 MF/SV GLV CJO (03/15/09) 11/16/00 SIS-Isl SET IBP @ 11090' 04/20/09 MSE PROPOSED CTD SIDETRACK 04/22/06 OFR/PJC SET CIBP @ 9730 04/05/08 D16 RWO 04/19/08 GJF/TLH GLV CJO (04/10/08) & CORR PRUDHOE BAY UNfT WELL: 15-49A PERMIT No: API No: 50-029-22651-01 SEC 22, T11 N, R14E, 3974.84' FEL 8~ 772.12' FNL BP Exploration (Alaska) FMC WELLHEAQ = CNV ACl ATOR = BAKER C Kg. ELEV = 67.3' BF. ELEV = ? KOP = 1141' Max Angle = 98 @ 11300' Datum MD = WA Datum N D = 8800' SS ~ 15 -49 B SAFETY NOTES: Proposed CTD Sidetrack 2194' H 4-1 /2" X NIP, ID = 3.813" GAS LIFT MANDRELS 9-5/8" CSG, 40#, L-80, ID = 8.835" i-~ 3867' Minimum ID = 2.30" @ 9386' TOL 3-1 /2 Baker 4-1/2" liner top packer ID = 2.375" 9080' 4-1/2" TBG, 12.6#, 13G-80, .0152 bpf, ID = 3.958" 9139' TOP OF 4-1 /2" LNR 9198' 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9212' _ 7" CSG, 26#, L-80, ID = 6.276" 9355' - BTT 3.7" deployment sleeve, min ID 2.3" 9385° ~ rronobore packer w hipstock ~ 9425' 30° PERFORATION SUMMARY REF LOG: SPERRY MWD GR ON 04/01/96 ANGLE AT TOP PERF: 80 @ 10130' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10130 - 10320 O 09101 /00 2" 4 10430 - 10560 O 09/01 /00 2" 4 10640 - 10680 O 09/01 /00 2" 4 10797 - 10830 O 09/01 /00 2" 4 10870 - 11011 O 09/01 /00 2" 4 11150 - 11203 C 09/01 /00 2" 4 11280 - 11650 C 09/01 /00 ~ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3851 3749 16 KBG2-1 DMY BK 0 03/15/09 2 7011 6363 40 KBG2-1 DMY BK 0 03/15/09 3 9002 7934 38 KBG2-1 DMY BK 0 04/04/08 9038' 4-1/2" HES X NIP, ID = 3.813" 9069' 7" X 4-1/2" BAKER S-3 PKR 9103' 4-1/2" HES X NIP, ID = 3.813" 9133' J~Top of 4.5" Tbg Stub 9139' UNIQUE MACHINE OVERSHOT 9177' 7" X 4-1/2" BAKER S-3 PKR 9200' 4-1/2" HES X NIP, ID = 3.813" 9386' i-i Milled out bushing ID = 2.30" 10400' i~ 3-3116" X 2-7/8" XO, 10' mkr joint ~3-3/16" x 2-718" cemented 8 Perfd ~ 124 9447' DEPLOYMENT SLEEVE2-7/8" LINER MILL WINDOW THROUGH 4-1/2" LINER @ 9751' \~ 11040' FISH - CIBP DEBRIS I 11090' I 2-7/8" LNR 6.5#, L-80, .00579 bpf, ID = 2.387" ~-~ 11736' DATE REV BY COMMENTS DATE REV BY COMMENTS 1996 ORIGINAL COMPLETION 05/04/08 LLUPJC PERF /MILL CIBP (04/23/08) 09/02/00 SIS-Isl SIDETRACK (15-49A) 03!15/09 MF/SV GLVGO(03/15/09) 11/16/00 SIS-isl SET IBP @ 11090' 05/01/09 MSE PROPOSED CTD SIDETRACK 04/22/06 DFR/PJC SET CIBP @ 9730 04/05/08 D16 RWO 04/19/08 GJFlTLH GLV GO (04/10108) 8~ CORR PRUDHOE BAY UNfr WELL: 15-49B PERMrr No: API No: 50-029-22651-02 SEC 22, T11 N, R14E, 3974.84' FEL & 772.12' FNL BP 6cploration (Alaska) 6/18/2009 Review of Sundry Application 300-200 BP Exploration (Alaska) Inc. Well PBU 15-49A AOGCC Permit 200-113 Requested Action: BP Exploration (Alaska) Inc. (BPXA) proposes to abandon the existing wellbore to prepare the well for sidetracking. Recommendation: I recommend approval of Sundry Application 300-200 to allow BPXA to perform this operation. Discussion: The current well is a sidetracked well from the mother bore (15-49). That mother bore produced a cumulative amount of 1,611 Mbbls over the four years until it was abandoned and sidetracked into 15-49A. The cumulative oil produced in 15-49A is 846 Mbbl, where as the estimated amount of reserves was 498.7 Mbbl using the trend of entire historical data. (See Appendix A) Beginning in late 2000, 15-49A showed large production with 2.0 Mbopd and had a relatively low GOR at 4.0 Mcf/bbl but had a sharp reduction in oil production and increase in GOR until July 2003. In July 2003, 15-49A showed 381bopd while at a much higher GOR of 41.7 Mcf/bbl and was then shut in at that point because of various leaks in the tubing. Production began again in Apri12008 but as production continued until March 2009, the GOR increased rapidly to 88.1 Mcf/bbl while only producing 312 bopd. Appendix B shows the larger increase in the gas production compared to decrease in oil production. Talking to Ron Phillips, he stated that since the original well bore (15-49) aimed East and the first sidetrack (15-49A) aimed South, was near large amounts of gas. BPXA is trying to limit the amount of gas produced by sidetracking the well (15-49B) to the North, away from the gas. 15-49B will still penetrate Zone lA, which is the zone that was penetrated by 15-49 and 15-49A. Conclusion: 15-49A is still a high producer in bbl of oil but has and had a high GOR. By plugging the current well and sidetracking to a location to the North, away from the gas, seems to be a sound choice for this well. I recommend approving BPXA's request. College Intern AGOCC Aaron Kohring C~6~18 f ~1 LJ I concur this statement Reservoir Engineer AOGCC David Roby ~~~.~ • 6/18/2009 6/ 18/2009 Appendix A. 10000 1000 v a a D a 100 d A 0 10 1 ~W ut uz us ua uo ua ui uo w iu ii ~z is is io i DATE Appendix B 6/ 18/2009 029226510100:150 - - - Oil Rate (PD) (bbUd ) Gas Rate (PD) (Mcf/d ) 1p'- - Water Rate (CD) (bbUd ) -- - -Gas /Oil Ratio (NkfPobl ) Water Cut(%) 10z 2000 01 02 03 04 05 06 07 O6 09 DATE STATE OF ALASKA -'~~'si90~ ~~~'~ ~° ~ ~~ ~ V ~' ALAS IL AND GAS CONSERVATION COMMI N MAY 1 6 200$ REPO~OF SUNDRY WELL OPERA ONS {~t~~sn~ Gi€ ~ ~~s ~:ons. Commission 1. Operations Performed: ~~ "~` `~ ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory ~ 200-113 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 ~, 50-029-22651-01-00 7. KB Elevation (ft): ~ 67 3' 9. Well Name and Number: , ~- PBU 15-49A 8. Property Designation: ~ 10. Field /Pool(s): ADL 028306 ~. Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11736' feet true vertical 8772' - feet Plugs (measured) 11090' Effective depth: measured 11702' feet Junk (measured) 11040' true vertical 8773' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3667' 9-5/8" 3667' 3572' 5750 3090 Intermediate 9355' 7" 9355' 8213' 7240 5410 Production Liner 553' 4-1/2" 9198' - 9751' 8088' - 8544' 8430 7500 Liner 2289' 2-7/8" 9447' - 11736' 8288' - 8772' 10570 11160 E~~~4N6~ED M,4Y ~ ~ 200 Perforation Depth MD (ft): 10130' - 11650' Perforation Depth TVD (ft): 8792' - 8773' 4-1/2", 12.6# 13Cr80 / L-80 9212' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): (2) 7" x 4-1/2" Baker'S-3' packer & 9177 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and frnal pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 742 10,209 -0- 150 1,178 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Sean McLaughlin, 564-4387 N/A Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: Si nature Phone 564-4628 Date ~~ Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 O~ZIGiIVNL -~1~~i~~s ~,i~l ~~ Submit Original Only ~~ Digital Well File • • Page 1 of 1 Well: 15-49 Well History Well Date Summary 15-49A 3/8/2008 T/I/0=640/450/275. Temp=Sl. Bleed WHP's to 0 psi pre-PPPOT (RWO prep). Integral installed on OA. IA needs integral. TBG FL @ 438' (7 bbl). IA & OA FL @ surface. Bled TBG from 640 psi to 0 psi in 2 hrs. During TBG bleed, IA bled from 450 psi to vac. wring T~~6Teed, fluid level inflowed 264'. TBG FL @ 174' (3 bbl's). IA FL near surface. Bled OA from 275 psi to 240 psi in 40 min. Post 1 hr monitor. During monitor OA increased 35 psi. Final WHP's=0/vac/275. 15-49A 3/9/2008 T/IA/OA= SSV/0/200 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP bleed tools onto THA 2000 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bleed void to 0 psi, RD test equipment, re installed Alemite cap. Cycle and torque LDS "ET style" all moved with no problems. PPPOT-IC RU 2 HP bleed tools onto IC test void 150 psi to 0 psi. Pressured to 3500 psi for 30 minute test, 3400/ 15 minutes, 3350/ 30 minutes. Bleed IC void to 0 psi, RD test equipment re installed Alemite cap. Cycle and torque LDS "ET style" all moved with no problems. 15-49A 3/9/2008 T/I/0=80/vac/260. (Pre RWO) CMIT TxIA to 3500 psi. Pumped 11.8 bbls crude down IA. Job Continued on 3-10-08 WSR. 15-49A 3/10/2008 **Job Continued From 3-9-08** CMIT TxIA PASSED to 3500 si..Pressured tubing and IA to to 3500 psi with 12.8 bbls crude. T/IA lost 3 50 psi 1st 15 mins, T/IA lost 30/10 2nd 15 mins for a total loss of 60/60 psi in 30 minute test. Bled tbg and IA to 0 psi. FWHP's=0/0/250. Annulus valves tagged and left open to gauges. 15-49A 3/10/2008 `***WELL S/I ON ARRIVAL**** (pre rwo) SET 3.76" JUNK CATCHER (2.992" MIN ID, OAL 144 3/8") @ 9420' SLM. **** WELL LEFT SHUT IN AND TURNED OVER TO DSO *** 15-49A 3/11/2008 *** WELL SHUT-IN ON ARRIVAL **** INITIAL T/I/O = 200/300/250 JET CUT TUBING AT 9146 FT AT MIDDLE OF FIRST FULL JOINT ABOVE BAKER S-3 PACKER. ***JOB CONTINUED ON 12-MAR-2008*** 15-49A 3/12/2008 ***JOB CONTINUED FROM 12 MAR 08*** JETCUT TUBING AT 9146 FT AT MIDDLE OF FIRST FULL JOINT ABOVE PACKER USING 3.65" SLB POWERCUTTER JOB COMPLETE. WELL LEFT SHUT IN. TURNED OVER TO DSO. FINAL T/ I/ O = 500/ 150/ 250 PSI. ***JOB COMPLETE**** 15-49A 3/14/2008 T/I/0= 250/250/250 Temp = SI Circ-Out, CMITTxIA PASSED to 3500 psi, Load OA w/ Inhibited 9.8 ppg NaCI Brine (RWO Prep) Pumped 5 bbls neat and 470 bbls 1 %KCL down tbg taking returns from IA to flowline. Pumped 75 bbls diesel down tbg and U-tube to IA for FP. CMIT T x IA to 3500 psi. T/IA lost 40 psi 1st 15 mins, T/IA lost 0 psi 2nd 15 mins for a total loss of 40 psi in 30 mins.. Bullhead 110 bbls inhibited 9.8# NaCI brine capped w/ 5 bbls warm diesel down OA. Freeze Protected flowline with 5 bbls neat and 10 bbls diesel. Final WHP's= 0/0/350 ---Annulus casing valves were tagged with info and left open to gauges--- 15-49A 3/15/2008 T/I/0=0+/0/0. Temp=Sl. Monitor (RWO prep). TBGP & IAP unchanged, OAP decreased 350 psi overnight. 15-49A 3/18/2008 T=0 I/A=0 O/A=0 Set 4 1/16" CIW H BPV ,Tagged @ 102"..1-2' was used....Job complete.(pre-rig) 15-49A 3/31/2008 set 4"CIW TWCV @ 102" w/2' exten. 15-49A 4/1/2008 T/I/0=0/0/0; Pulled 4-1/16" CIW H BPV thru tree for Doyon 16; 1-2' ext. used, tagged @ 102'; ***Complete*** (Best/Wortham) Print Date: 5/14/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WI Info/Reports/ReportViewer.aspx 5/14/2008 J • BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: 15-49 Common Well Name: 15-49 Spud Date: 3/12/1996 Event Name: WORKOVER Start: 3/26/2008 End: 4/5/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/5/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase ': Description of Operations 3/30/2008 14:00 - 15:00 1.00 MOB P PRE Back Off END 1-21. Move Rig to Other Side of Well Row. 15:00 - 22:00 7.00 MOB P PRE PJSM on upcoming tasks. Remove BOP stack yoke and UD Double Gate BOP Ram Body. P/U Single Gate Ram Body and reinstall BOP yoke. Remove and then replace Driller's side Brake bands. RU bridle lines. Break down mud manifold on Rig Floor. Place BOP stack on moving stand and secure. Pad clean-up around END 1-21. 22:00 - 22:30 0.50 MOB P PRE Hold PJSM and UD Derrick. 22:30 - 23:00 0.50 MOB P PRE Install rear Boosters for Rig move. 23:00 - 00:00 1.00 MOB P PRE Move Rig off of Endicott Main Island. 3/31/2008 00:00 - 01:30 1.50 MOB P PRE Move Rig from END 1-21 to END Ice Road. 01:30 - 02:30 1.00 MOB P PRE Clean up Camp Site on Ice Road off of SDI. 02:30 - 12:00 9.50 MOB P PRE Move Rig from END 1-21 to DS 17. 12:00 - 23:00 11.00 MOB P PRE Continue to Move Rig from DS17 to DS 15-49. Stage Rig on DS 15. 23:00 - 23:30 0.50 MOB P PRE PJSM & Remove Booster Wheels. 23:30 - 00:00 0.50 MOB P PRE Prepare to raise Derrick. 4/1/2008 00:00 - 00:30 0.50 MOB P PRE Raise Derrick. 00:30 - 01:00 0.50 MOB P PRE Position Rig to move over well 15-49. Install BOP stack in cellar. 01:00 - 02:00 1.00 MOB P PRE Spot Rig over well and Shim as needed. 02:00 - 03:00 1.00 MOB P PRE Prepare for Rig Acceptance. RU Slop Tank & Lines. 03:00 - 04:00 1.00 RIGU P PRE Acce t Ri ~ 0300 hrs. Take on 700 bbls of 140 degree 8.4 ppg 2% KCI Brine to pits. MU Mud Manifold. Tie back Bridle Lines. 04:00 - 05:00 00 1 WHSUR P DECOMP RU DSM I~bricator and oressure test to 500 nsi L~ihricata rnit . B 05:00 - 06:30 1.50 WHSUR P DECOMP RU to circulate out 80-bbls Diesel Freeze Protection. Pressure test lines to 3,500-psi. Pump 20-Bbls HiVis sweep and circulate out diesel freeze protect fluid 8-BPM at 1,600-psi to Cuttings Tank. Displace Wellbore to 8.4 ppg 2% KCI Brine. 06:30 - 07:00 0.50 WHSUR P DECOMP Monitor well--well dead. 07:00 - 09:00 2.00 WHSUR P DECOMP Circulate well 5-BPM at 1,260-psi while waiting on DSM to arrive on location to install TWC. 09:00 - 10:30 1.50 WHSUR P DECOMP PJSM. P/U and install DSM lubricator and PT to 500-psi. Install TWC and R/D DSM lubricator. 10:30 - 12:00 1.50 WHSUR P DECOMP PT TWC to 3 500- si from above and 1,000- si from below, each 10-minutes charted for good tests. 12:00 - 15:00 3.00 WHSUR P DECOMP Bleed down lines and N/D Tree and Adaptor Flange. Check Hanger threads, taking 8-1/2 turns for screwing in the XO. Tieback tree inside cellar to make room for N/U the BOPE stack. 15:00 - 20:00 5.00 BOPSU P DECOMP PJSM. N/U BOPE. Install Blind Rams. H/U Choke Line. Lou Grimaldi, AOGCC, called at 1600-hours to waive State's right to witness the initial BOPE test for Doyon 16's RWO) on DS15-49. 20:00 - 21:00 1.00 BOPSU P DECOMP RU for BOP test. Fill BOP stack and work air out of test equipment. 21:00 - 00:00 3.00 BOPSU P DECOMP Test BOP a ui ment per AOGCC procedures to250-psi & 3500-psi. Hold each test for 5 minutes and chart all tests. All tests witnessed by BP WSL and Doyon TP. Test Annular Preventer, Upper and Lower IBOP, Choke Manifold, Dart and TIW valves, HCR Kill and Choke, Manual Kill and Choke, and Printed: 4/11/2008 12:31:09 PM • • BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: 15-49 Common Well Name: 15-49 Spud Date: 3/12/1996 Event Name: WORKOVER Start: 3/26/2008 End: 4/5/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/5/2008 Rig Name: DOYON 16 Rig Number: Date. L From - To ~~ Hours Task Code NPT I Phase Description of Operations 4/1/2008 21:00 - 00:00 3.00 BOPSU P DECOMP Accumulator. 4/2/2008 00:00 - 01:00 1.00 BOPSU P DECOMP BOP Test per AOGCC procedures. Test to 250-psi low and 3500-psi high. Hold all tests for 5 minutes and chart. Test witnessed by BP WSL and Doyon Toolpusher. Good Test. 01:00 - 01:30 0.50 BOPSU P DECOMP R/D BOP test equipment and hoses. 01:30 - 02:00 0.50 PULL P DECOMP R/U 4-1/2" Tubing handling equipment while waiting on DSM lubricator. 02:00 - 03:00 1.00 PULL P DECOMP RU DSM Lubricator. Pressure test to 500-psi -good test. Pull TWC and RD DSM Lubricator. 03:00 - 03:30 0.50 PULL P DECOMP MU 4-1/2" NSCT XO to Landing jt and engage Hgr w/ expected 8 1/2 turns. BOLDS and pull Hanger to Rig Floor. Break Over Wt = 140K, PU Wt = 145K. 03:30 - 04:00 0.50 DECOMP SLB Control Line Spooler terminate Control Lines. LD Tubing Hanger and RU to Circulate. 04:00 - 04:30 0.50 PULL P DECOMP Circulate bottoms up at 10-BPM and 2,700-psi. 04:30 - 13:00 8.50 PULL P DECOMP POH and UD 4-1/2", 29-Ib BTC Modified Tubing. R/U Tugger to pull tension on the Control Lines. 30-joints POH at 0630-hours. 52-jts POH at 0730-hours. Immediately below the 52-nd joint the Control Lines were balled up around the SSSV and loose SS-bands were in the tangle. Hold PJSM to discuss how to safely remove the control line nest. Recovered 34 SS-bands versus what possibly could have been as many as 55-56 SS-bands originally RIH. 90-joints POH at 0900-hrs. #135 at 1025-hrs. #170 at 1145-hrs. Most of the joints below the SSSV had extensive corrosion at the immediate end of the pins, with some thread wickers appearing. 13:00 - 13:30 0.50 PULL P DECOMP VD cut-off joint, length 21.17' and the OD of the Power Jet Cut is 4-3/4" with a very clean, smooth appearance. 13:30 - 14:30 1.00 PULL P DECOMP Clear and clean Rig Floor. Drain BOP Stack to check for missing SS-bands, found none. P/U Wear Ring Run/Pull tool and M/U to landing joint. Install 7" Wear Ring. Bring Baker Fishing BHA equipment to Rig Floor. 14:30 - 15:30 1.00 CLEAN P DECOMP PJSM to handle BHA. P/U and M/U Dress-off BHA: 6" x 4-9/16" ID Dress-off Shoe, 15.47' of 5-3/4" Extensions, 4-3/4" x 3-7/8" Tubing Dress-off Mill, 5-3/4" Boot Basket, 7" Casing Scraper, Bumper Jars, and 9-ea 4-3/4" Drill Collars. 15:30 - 18:30 3.00 CLEAN P DECOMP RIH w/ Dress-off BHA on 4" Drill Pipe from Pipe Shed from 311' to 3,800' md. 18:30 - 19:30 1.00 CLEAN P DECOMP GPB Safety Stand Down with Herb Williams and James Willingham. 19:30 - 00:00 4.50 CLEAN P DECOMP RIH w/ Dress-off BHA on 4" DP from Pipe Shed from 3,800' to 8,400' md. 4/3/2008 00:00 - 01:30 1.50 CLEAN P DECOMP RIH w/ Dress off assembly from 8,400' and to 9,110' md. PU= 175K, SO Wt=145K, Rot Wt= 160K. Rotate @ 60 rpm with 5K free torque. Pump 4-bpm Q 470-psi. Wash down and tag 01:30 - 02:30 1.00 CLEAN P DECOMP Rotate down over Tubing stump until no-go ~ 9,147' md. Dress off Tubing stump with above parameters and 5-7K weight on bit. 02:30 - 03:00 0.50 CLEAN P DECOMP Pump 20-bbl Hi-Vis sweep C~3 10-bpm / 3100-psi. Saw clumps of black "Schmoo" at bottoms up. Reduced amount seen when sweep back to surface. 03:00 - 03:30 0.50 CLEAN P DECOMP Monitor well -Static. Pump 15-bbl dry job and blow down Top Printed: 4/11/2008 12:31:09 PM • BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: 15-49 Common Well Name: 15-49 Spud Date: 3/12/1996 Event Name: WORKOVER Start: 3/26/2008 End: 4/5/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/5/2008 Rig Name: DOYON 16 Rig Number: Date From - To .Hours Task Code I NPT ~; Phase Description of Operations __ I 4/3/2008 03:00 - 03:30 0.50 CLEAN P DECOMP Drive. 03:30 - 10:30 7.00 CLEAN P DECOMP POH and LD 4" DP from 9 147' md. 10:30 - 11:30 1.00 CLEAN P DECOMP Break out and VD Bumper Sub, Boot Basket, and Scraper. Find 3 SS-Bands and 1-quart of cuttings debris in Boot Basket. Scraper blades were filled with hard paraffin and also had an SS-band wrapped in them. Total SS-band recovery is 38 SS-bands. Remove steam wand and Herculite from wellhead. 11:30 - 12:15 0.75 WHSUR P DECOMP P/U Landing Joint and M/U to Wear Ring Run/Pull tool, RIH and pull Wear Ring. Check OA for pressure--none and no fluid dripping out bleed valve. P/U and M/U FMC packoff Run/Pull tool to Landing Joint. RIH and engage Run/Pull Tool into 7" packoff. BOLDSs. Pull 20,000-Ibs over Top-Drive weight and ackoff ulls free. 12:15 - 13:00 0.75 WHSUR P DECOMP M/U FMC packoff Run/Pull tool to new FMC 7" packoff and RIH and set in 7" Bowl. RILDSs. Pressure test packoffs to 4,300-psi for 30-minutes and get 200-psi gain due to thermal expansion of the sealing fluid inside the warm wellhead. 13:00 - 22:00 9.00 BUNCO RUNCMP Off-load first truckload of new 4-1/2", 12.6-Ib, 13Cr80, Vam Top tubing which had arrived at 1245-hours. Driver reported 200-miles of glare-ice road on the Haul Road. Second truckload arrived at 1400-hrs. Stores will send out 30 additional joints to make up the completion string. Load, clean threads, and tally 220-joints into the Pipe Shed. While waiting, service and inspect Top Drive and Pipe Skate. Bring 4-1/2" Tubing handling equipment to Rig Floor. 22:00 - 00:00 2.00 BUNCO RUNCMP RU Torque Turn equipment -power tongs, computer, compensator. 4/4/2008 00:00 - 10:30 10.50 BUNCO RUNCMP RIH w/ 4-1/2" 13cr80 Vam To Com letion. 3-X Nipples, 3-GLMs, 1-Baker S-3 Packer. Bakerlok all connections below the packer. Utilize Torque Turn services w/ Optimum torque of 4,440-Ibs-ff (Max Torque=4,880-Ibs-ft, Min Torque= 4,000-Ibs-ft). Use Jet Lube Seal Guard thread compound for all connections not Bakerlok'd. 122-joints RIH at 0700-hours. 10:30 - 12:30 2.00 BUNCO RUNCMP P/U joint #213 and slowly RIH (5-footing in), see stump at ' continue RIH (1-footing in) and see first set of pins shear at 9,137' with 10-15,000-Ibs. P/U joint #214, and continue RIH (1-footing in) to see 2nd set of pins shear at 9,142' with 10-15,000-Ibs. Continue to No-Go at 9,144'. Calculate Space-out. POH and L/D joints #214 and #213. M/U two pup joints, 4.07' and 10.09' and RIH under joint #213. P/U and M/U to Hanger, plug two ports in Hanger and land Hanger. RILDS. Bottom of Unique Machine Overshot at 9,139' and top of 4-1/2" tubing stub at 9,133' fora 6' swallow. 12:30 - 13:30 1.00 BUNCO RUNCMP R/U lines to reverse circulate 140-Bbls of hot 2% KCI brine and 170-Bbls of hot 2% KCI brine mixed with EC 1124A Corrosion Inhibitor. Wait on Vac Trucks, which both show up at 1300-hours. R/U Vac truck to start pumping hot brine. PJSM for reverse circulating and Packer setting and testing. PT lines to 3,000-psi. 13:30 - 16:30 3.00 BUNCO RUNCMP Reverse circulate 140-Bbls of hot brine followed by 170-Bbls corrosion inhibited hot brine, 3-BPM at 630-psi. 16:30 - 18:00 1.50 BUNCO RUNCMP Break off circulating line from tubing and drop the ball/rod. M/U circulating line to tubing. Let ball/rod fall for 20-minutes then Printed: 4/11/2008 12:31:09 PM BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: 15-49 Common Well Name: 15-49 Spud Date: 3/12/1996 Event Name: WORKOVER Start: 3/26/2008 End: 4/5/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 4/5/2008 Rig Name: DOYON 16 Rig Number: Date '~ From - To Hours Task Code NPT 'Phase Description of Operations 4/4/2008 16:30 - 18:00 1.50 RUNCO RUNCMP pressure u p on tubing to 3,500-psi. Pressure sensor 18:30 - 19:30 10.00 BOPSUGH P 19:30 - 20:30 ~ 1.00 ~ BOPSUFj P 20:30 - 23:00 I 2.501 WHSUR I P 23:00 - 00:00 ~ 1.00 ~ WHSUR ~ P 4/5/2008 100:00 - 01:00 ~ 1.00 WHSUR ~ P 01:00-01:30 I 0.501 WHSURIP 01:30 - 03:00 I 1.501 WHSUR I P 03:00 - 04:00 1.00 ~ WHSUR ~ P 04:00 - 05:00 1.001 WHSUR P 05:00 - 05:30 I 0.501 WHSUR I P 05:30 - 06:00 I 0.501 WHSUR I P malfunctioned• bleed off tubing and replace pressure sensor. Pressure u on tubin to 3,500- si and record fora 30-minute, rock-solid test. Bleed off tubing to 1,500-psi, then pressure up nn the IA to 3 500- si and record fora 30-minute, rock-solid test. Quickly bleed off the tubing pressure, but do not see chart indication of the DCK valve shearing although both sides equalized instantly. Pump at 3-BPM down tubing and get good returns. Pump down IA and get same, good returns. RUNCMP Blowdown lines and backout and UD the landing joint. RUNCMP FMC technician install TWC. Test TWC to 3,500-psi from above and 1,000-psi from below. Both tests charted for 10-minutes each as rock-solid. RUNCMP PJSM on N/D BOPs. Blowdown Choke and Kill lines. Drain and N/D BOP stack. Move BOP with bridge cranes to cellar pedestal and secure in place. RUNCMP N/U adapter flange and tree per FMC rep. Pad operator witnessed installation and okay'd it. Install flange on Wing valve. Test neck seal void on adapter flange to 5,000-psi. Good test. RUNCMP Fill Tree with diesel and R/U to test. Test tree to 5,000-psi, holding for 30 minutes and charting test -Good Test. RUNCMP R/D Tree testing equipment. P/U and R/U DSM Lubricator. Pressure test Lubricator to 500 psi -Good Test. Pull TWC and R/D DSM Lubricator. RUNCMP R/U all rig lines and manifold for Diesel Freeze Protection. Test lines to 3500 psi -Good Test. RUNCMP PJSM on Freeze Protecting and U-tubing with Diesel. R/U and test Little Red's lines to 3500 psi -Good Test. Reverse circulate 85-bbls of 85-degree Diesel at 2-bpm / 1400-psi. RUNCMP Shut down LRS pumps. R/U jumper line and allow Diesel Freeze Protection to U-tube. RUNCMP FMC rep dry rod in BPV. Test BPV to 1000-psi using LRS. Hold and chart test for 10-min. "`* Release Rig Cagy 0600-hrs on 4/5/2008 "' RUNCMP LRS suck back lines and R/D. R/D cellar manifold and all Rig Lines. RUNCMP Remove secondary annulus valves from wellhead. "` Release Rig (~ 0600-hrs on 4/5/2008 "` Printed: 4/11/2008 12:31:09 PM TREE = FMC WELLHEAD= CM/ ACTUATOR = BAKER C KB. ELEV = 67.3' BF. ELEV = _ ? KOP = 1141' Max Angle = 98 @ 11300' Datum MD = WA Datum TV D = 8800' SS DRLG DRAFT 9-5/8" CSG, 40#, L-80, ID = 8.835" 3667' Minimum ID = 2.387" @ 9453' 2-7/8" LINER PIN 14-1/2" TBG, 12.6#, 13Cr-80, .0152 bpf, ID = 3.958" I~ 9123' ITOPOF4-1/2"LNR 9198' 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9212' 7" CSG, 26#, L-80, ID = 6.276" 9355' TOP OF 2-7/8" LNR I~ 9453' TOP OF WHIPSTOCK I~ 9744' PERFORATION SUMMARY REF LOG: SPERRY MWD GR ON 04/01/96 A NGLE AT TOP PERF: 80 @ 10130' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10130 - 10320 O 09/01 /00 2" 4 10430 - 10560 O 09/01/00 2" 4 10640 - 10680 O 09/01 /00 2" 4 10797 - 10830 O 09/01/00 2" 4 10870 - 11011 O 09!01/00 2" 4 11150 - 11203 C 09/01 /00 2" 4 11280 - 11650 C 09/01 /00 ~ 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I 2194' H 4-1 /2" X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3851 3749 16 KBG2-1 DOME BK 16 04/10/08 2 7011 6363 40 KBG2-1 SO BK 20 04/10/08 3 9002 7934 38 KBG2-1 DMY BK 0 04/04/08 9038' ~ 4-1 /2" HES X NIP, ID = 3.813" 9069' 7" X 4-1/2" BAKER S-3 PKR 9103' 4-1/2" HES X NIP, ID = 3.813" 9133' Top of 4.5" Tbg Stub 9139' UNIQUE MA CHINEOVERSHOT 9177' 7" X 4-1/2" BAKER S-3 PKR 9200' 4-1/2" HES X NIP, ID = 3.813" 9212' 4-1/2" TBG TAIL WLEG 9447' ~DEPLOYMENTSLEEVE 9453' 3-1/2" X 2-7/8" XO MILL WINDOW THROUGH 4-1/2" LINER @ 9751' 11040' FISH -CIBP DEBRIS (MILLED 04/23/08) 11090' 2-1/8" IBP 12~ 1/2 OF SPLfT RING OFF4-1/2" SSSV 5-3/4" X 1/4" PBTD 11702' 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.387" I 11736' I DATE REV BY COMMENTS DATE REV BY COMMENTS 1996 ORIGINAL COMPLETION 05/04/08 LLUPJC PERF /MILL CIBP (04/23108) 09/02/00 SIS-Isl SIDETRACK(15-49A) 11/16/00 SIS-Isl SET IBP @ 11090' 04/22/06 DFR/PJC SET CIBP @ 9730 04/05108 D16 RWO 04/19/08 GJF/TLH GLV C/O (04/10/08) & CORRECTIONS PRUDHOE BAY UNIT WELL: 15-49A PERMIT No: 2001130 API No: 50-029-22651-00 SEC 22, T11 N, R14E, 23 3974.84' FEL & 772.12' FNL BP Exploration (Alaska) 15-49A F:\LaserFiche\CvrPgs _ Inserts\M icrofilm _Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ') 01/22/04 Schlumberger NO. 3095 Alaska Data & Consulting Services Company: State of Alaska 3940 Arctic Blvd, Suite 300 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color ( Well Job # Log Description Date Blueline Prints CD D.S.06-02 \.-( l' -(Yt~ 10874399 PROD PROFILE 11/22/03 1 E-35A :::In' ... \ '-1 10715373 MEM PROD PROFILE 12/27/03 1 P1-06 \ q ,,0 '- \ ~~ '"-:::¡" 1 0703984 PPROFILE/DEFT/GHOST 12/24/03 1 D.S. 15-49A I~ 00" I.~' 10679043 LDL 12/23/03 1 M-38A .~() I -. ~~ 10709678 LDL 12/25/03 1 D.S.09-15 ri-=J "C 3( 0 10709680 STATIC SURVEY 12/27/03 1 X-27 ~ 9) Y --c:) _oc-{ 10679046 LDL 01/08/04 1 . i ' ( \ ;,,,,,, ,,',.'.'" ::J;::, ,',1;$:.~~./:;:~, ~,:,¡¡:',t""'''':'!¡I'': :IV, .':, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc," Schlumberger GeoQuest Petrotechnical Data Center LR2-1 RECEIV 3940 Arctic Blvd, Suite 300 900 E. Benson Blvd, 'ED Anchorage, AK 99503-5711 Anchorage, Alaska 99508 ' ATTN: Beth ! ^ r! -. C "004 -, ',-"" , , \oJ i\;~ \.) ,; L , "-"""':::" \"" "' Date Delivered: Received by: "'~t~:ì \...( 1\/" \ \ t (.L'~..':'''--.l~..\l-''\ AJaskaOU &: Gas Cons. Commlian II Jindøage SÇ¡j~N~\\EC FED ij ¿~ 2DDtll- --'~"""<:':':',,, ,'", \ \. TREE = FMC WELLHEAD = CIW SAFETY NOTES: LAI~ING COLLAR OPEN @ 11702' 15 49A WILL HANG UP ALL TOOLS RII-L CAUTION SHOULD 'R~;'-t~['~'"~ .................................................... BE USED. 70' @ 10100' AND 90' @ 10190' 67 BF. ELEV = ~ KC)P= 1141' MaX Angle = 98 @ 11300' i Dat~mUD= I '' 1 ~TM ~ I2223.1-1 ~-"~''~H~°SV'"Sssv"~,°=~-~" I DatUm~D = 8800, SS I~'~'~''cs~'®#'~-°°'~=°'~'' I-I 3667' ]~ ' GAS LIFT MANDRB_S ST IVD TVD DEV TYFE VLV LATCH PORT DATE L 1 3791 3691 16 KBG2LSMOD INT 2 6931 6301 41 KBG2LSMOD: INT Minimum ID =2-7/8" @ 9453' I 3 91o8 8o17 39 KBGZLSMOD~ ~NT I CROSSOVER TO 2-7~8" LINER X X I 9177' I--t ?'X4-1/2"BAKERS-3PKR I i ,' 9200' I-t ~-l/2'"~SXN~.~D--3-813"l I TOP Of 4.1/Z, LNRH 9198, t~ ~ 9212'Id4"/Z'TBgTAILWlEgl ~-~",~, ~.~, ~-oo, .o~ ~p~, ,~= ~.o~.. Id ,2~2' I '!~ ,4~ MILL WNDOW THROUGH ~ 4-1/2" [_1~1~ @ 9751' ' , TOPOFWHtPSTOCK ,d 9744'I ~~ PEP, FOP, AT]ON SUMMA RY REF LOG: BAKER HUGHES/GR ANGLE AT TOP PEP, F: 80 @ 10130' 11090' ,I--I 2-1/8" IBP Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE o _ _ ' oo°° o o ,oo 2" 4 11150 - 11203 C 09/01/00 . ' ~ OFF 4-1/2" SSSV 5-3/4" X 1/4" DATE REv' BY COMMENTS DATE REV BY COMMENTS PRUDHOEBAY UNIT 1996 ORIGINAL COMPLETION WELL: 15-49A 09/02/00 SIS-Isl SIDETRACK COIVPLEFION PERMIT No: 2001130 11/16/00 SIS-Isl SETIBP@ 11090' APINo: 60-029-22651-00 03/05/01 SIS-MD FINAL SEC22, T11N, R14E, 23 3974.84' FEL &772.1Z FNL 02/10/02 RN/TP CORRECTIONS 02/28/03 CNJ/TP CLOSED PERFCORRECT]ON BP Exploration (Alaska) PERFORATION SUMMA RY REF LOG: BAKER HUGHES/GR ANGLE AT TOPPERF: 80 @ 10130' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10130 - 10320 O 09/01/00 2" 4 10430 - 10560 O 09/01/00 2" 4 10640 - 10680 O 09/01/00 2" 4 10797 - 10830 O 09/01/00 2" 4 10870 - 11011 O 09/01/00 2" 4 11150 - 11203 C 09/01/00 2" 4 11280 - 11650 C 09/01/00 DATE REt/ BY COMMENTS DATE REV BY COMMENTS 1996 ORIGINAL COMPLETION 09/02/00 SIS-Isl SIDETRACK COIVPLEFION 11/16/00 SIS-Isl SETIBP@ 11090' 03/05/01 SIS-MD FINAL 02/10/02 RN/TP CORRECTIONS 02/28/03 CNJ/TP CLOSED PERFCORRECT]ON Permit to Drill 2001130 MD 11736 ~ -I-VD DATA SUBMITTAL COMPLIANCE REPORT 9/912002 Well Name/No. PRUDHOE BAY UNIT 15-49A Operator BP EXPLORATION (ALASKA) INC 8772 ~'~ Completion Dat 9/2/2000 f Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22651-01-00 UIC N REQUIRED INFORMATION Mud Log N_go Sample N_.Qo Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments ED O''~j Ver LIS Verification R R R R JWL GAS ENTRY TVD GR MD GR LIS Verification 10159 MWD Survey Report MWD Survey Report MWD Survey Report 9817 5 2/5 2/5 FINAL FINAL FINAL FINAL FINAL 1 FINAL FINAL FINAL 1 9144 9810 9810 9760 9771 9767 9200 9144 9771 9890 9770 11698 11736 11736 11735 11735 9913 11660 11698 11735 11736 9912 CH 10/25/2000 PDS CH 10/25/2000 9144-11698 OH 6/21/2001 9810-11736 BL, Sepia OH 6/21/2001 9810-11736 BL, Sepia CH 6/22/2001 9760-11735, Digital Data OH 6/22/2001 10159~'~71-11735, Digital Data Open 2/1 ~2002 10587-~- Case 10/13/2000 09760 z~'200-11660 Case 10/25/2000 09817~ 44-11698 · Open 6/22/2001 10159.~J~ 1 -i 1735 2/2/2001 Digital Data 2/2/2001 9890-11736 Paper Copy 2/2/2001 9770-9912 Paper Copy CH 10/25/2000 9817':-'PDS GAS ENTRY Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2001130 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. PRUDHOE BAY UNIT 15-49A Operator BP EXPLORATION (ALASKA) INC MD 11736 'I'VD 8772 Well Cored? Y/~ Chips Received? ~ Analysis ~ Re.c~iv~.d ? Completion Dat 9/2/2000 Completion Statu 1-OIL Current Status Daily History Received? Formation Tops ~/N APl No. 50-029-22651-01-00 1-OIL UIC N Comments: Compliance Reviewed By: Date: Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: 15-49APB 1 Prudhoe Bay Unit Contains the following: LDWG format disk listing · set films (2 films: 1GR MD and 1TVD) set prints (2 prints: 1GR MD and 1TVD) LAC:16513 Sent By: Iuliana Craiciu Received By: ~~s~ ~ Date: Date: ,-r-m n~ 2002 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RE~G OR FAXING YOUR COPY FAX: (403) 537-3767 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 Transmittal Form Kill BAK~ HUGH~ Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission ...,.. 333 West 7th Avenue, SUite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: BP AMOCO Pmdhoe Bay North Slope, Alaska 15-49A Contains the following: LAS Format disk Film Measured Depth GR print ,4 TVD-GR print Sent B~erg Date: June 20, 2001 Receive B~~~(_ ~~)~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537~3767 RECEIVED JUN 2 i 2001 Oil & Gas Cees. ~ ObP BP Amoco Baker Hughes INTEQ Survey Report FieM: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetle Model: BGGM2000 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft Latitude: 70 17 35.236 N 676296.98 ff Longitude: 148 34 21.213 W North Reference: True GrM Convergence: 1.34 deg WeD: 15-49 Slot Name: 49 15-49 WeliPosition: +N/-S 2048.00 ft Northing: 5960879.57 ft Latitude: 70 17 55.378 N +E/-W -217.64 ff Easting: 676031.39 ff Longitude: 148 34 27.558 W Position Uncertainty: 0.00 ff Wellpath: 15-49APB1 Drilled From: 15-49 500292265171 Tie-on Depth: 9770.00 ft Current Datum: 67: 49 5/30/1996 17:16 Height 67.30 ft Above System Datum: Mean Sea Level Magnetic Data: 9/11/2000 Declination: 26.98 deg FieM Strength: 57481 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +K/-W Direction ff ff ff deg 0.00 0.00 0.00 266.00 Survey: MWD Start Date: 8123/2000 Measured While Drilling Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation 9770.00 8559.67 Kick-off Point 9912.99 8670.43 Projected to TD Survey 9770.00 36.46 88.30 8559.67 8492.37 431.19 4153.82 5981407.91 680173.70 0.00 9800.00 34.80 103.00 8584.10 8516.80 429.52 4171.11 5961406.65 680191.02 29.02 9830.00 36.50 118.60 8608.53 8541.23 423.31 4187.32 5981400.82 680207.37 30.76 9860.00 39.30 128.70 8632.22 8564.92 413.09 4202.58 5981390.96 680222.87 22.66 9890.00 45.60 128.80 8654.34 8587.04 400.42 4218.37 5981378.66 680238.95 21.00 -4173.78 -4190.91 -4206.65 -4221.16 -4236.02 9913.00 45.60 128.80 8670.44 8603.14 390.13 4231.17 5981368.67 680251.99 0.00 -4248.08 BP Amoco WELLPA TH DETAILS 500292265101 Parent Wellpath: fS. dgAPBf Tie on MD: VerdcalSectionOrigin: Slot.49(0.00,0~0) V~tical Section Angle: 266.00° R~: Nabom 35 Depth Reference: ~7 : 49 5130119~ 1}:16 67o301t REFERENCE INFORMATION Co~-dr~e(N~") Re~*en=e: We~lCen~'e: 15-a~9, ~e~ V~ ~) ~: F~-~ ~ ~a ~ ~) R~m~: ~ - ~ (0.~,0,~) ~~ 67: 49 ~1~ 17:16 ~.3 ~e~ ~ ~ T~GET OETAIL8 NO. 'IVD+N/-8 +E/-W Target 871o. oo 133.47 2942,74 15..49AT2.3~TD 6715100-226:05 3864,56 15-49AT2.2 3 8720.00 148.00 4199.51 15-49AT2.1 BPAmoco BAKER / I~TE.Q I LEGEND 15.49,15.49A. l:Vmn #2 15-49 (15-49) 15-49 (15-4W~=B1) 15-49 (15.49P~1) 15-49A Azimuths to True Nmahl Wellpalh: (15-49/15-49A) .M4agncti¢ North: 26.96° I Crcalgd ay: atij Polais Dale: 9/I 1/2000 Ma~n. ic Fi¢ldl Strcngth: 57481 nT! Dip An81c: 80.79°[ D~(:~ (~07) ;~7~:~ Datc: 9/I 1/20001 E-ma~L Modch nOOM2OOOI Baker Hui:Jt~s INTEQ: (g0Z) 267-~D0 -4400 -4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 ~ Vertical Section at 286.00° [200ft/in] Plot 1122/2001 10:28 AM BP Amoco bp Baker Hughes INTEQ Survey Report DS15: Yertical('r~) Reference: i 67':49 5/30/1996 17:16 67.3 · we. (0~0,00N~,00Azi) FJeM: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft Latitude: 70 17 35.236 N 676296.98 ft Longitude: 148 34 21.213 W North Reference: True Grid Convergence: 1.34 deg Well: 15-49 Slot Name: 49 15-49 WeH Position: +N/-S 2048.00 ft Northing: 5960879.57 ft Latitude: 70 17 55.378 N +E/-W -217.64 ff East'mg: 676031.39 ff Longitude: 148 34 27.558 W Position Uncertainty: 0.00 ft Welipath: 15-49A Drilled From: 15-49APB1 500292265101 Tie-on ~epth: 9690.00 ft Current Datum: 67: 49 5/30/1996 17:16 Height 67.30 ft Above System Datum: Mean Sea Level Magnetic Data: 9/11/2000 Declination: 26.96 deg Field Strength: 57481 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +NI-S +K/-W Direction ff ff ff deg 0.00 0.00 0.00 266.00 Survey: MWD Start Date: 8/29/2000 ' Measured While Drilling Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation 9690.00 8653.42 Kick-off Point 11736.00 8770.81 Projected to TD Survey 9890.00 45.60 128.80 8653.42 8586.12 400.83 4219.66 5961379.10 680240.23 0.00 -4237.34 9922.00 43.30 144.30 8676.33 8609,03 384.70 4235.02 5961363.34 680255.96 34.61 -4251.54 9951.00 42.50 159.60 8697.63 8630.33 367.40 4244.26 5961 346.25 680265.61 35.96 -4259,55 9981.00 44.80 170.20 8719.37 8652.07 347.46 4249.60 5961326.44 680271.41 25.54 -4263.49 10011.00 48.80 179.40 8739.92 8672.62 325.72 4251.52 5961304.76 680273.84 26.01 -4263.89 10040.00 55.60 180.20 8757.69 8690.39 302.82 4251.59 5961281.87 680274.45 23.55 -4262.36 10070.00 63.60 184.70 8772.86 8705.56 277.00 4250,45 5961256.03 680273.91 29.63 -4259.42 10100.00 72.30 186.00 8784.11 8716.81 249.35 4247.85 5961228.33 680271.96 29.28 -4254.89 10131.00 80.40 188.20 8791.42 8724.12 219.48 4244.12 5961198.38 680268.93 27.02 -4249.09 10160.00 84.90 195.10 8795.14 8727.84 191.34 4238.31 5961170.11 680263.78 28.24 -4241.33 10190.00 89.90 200.00 8796.50 8729.20 162.78 4229.27 5961141.36 680255.41 23.32 -4230.33 10221.00 89.50 203.50 8796.66 8729.36 133.99 4217.79 5961112.31 680244.61 11.36 -4216.86 10251.00 91.20 204.00 8796.48 8729.18 106.54 4205.71 5961064.58 680233.17 5.91 -4202.89 10280.00 91.30 207.70 8795.84 8728.54 80.45 4193.07 5961058.20 680221.15 12.76 -4188.46 10310.00 89.40 210.60 8795.66 8728.36 54.25 4178.46 5961031.67 680207.16 11.56 -4172.06 10340.00 90.90 215.10 8795.58 8728.28 29.06 4162.19 5961006.11 680191.48 15.81 -4154.08 10367.00 88.60 217.10 8795.70 8728.40 7.24 4146.28 5960983.93 680176.09 11.29 -4136.69 10400.00 87.50 220.00 8796.82 8729.52 -18.55 4125.73 5960957.66 680156.16 9.39 -4114.39 ObP BP Amoco Baker Hughes INTEQ Survey Report Survey 1/22/2001 'llmm 10:27:17' ' l'ak, e: .2. Cb,erdlnalt(N~ l~q'et~ce: Well.' 15-4,9, True Nor~ ' ' Yertk~ CTVD) Reference: 67: 40 5/30/1G 17:16 67.3 .?~Cak. u~aknnaeama:,~Mlrentm'~~'~' '.'~ ,'ne: Oracle:. 10430.00 89.60 222.60 8797.58 8730.28 -41.07 4105.94 5960934.68 680136.90 11.14 -4093.07 10459.00 89.10 226.10 8797.91 8730.61 -61.81 4085.67 5960913.48 680117.12 12.19 .-4071.41 10490.00 90.10 230.50 8798.13 8730.83 -82.42 4062.53 5960892.33 680094.47 14.55 -4046.89 10520.00 89.80 234.20 8798.15 8730.85 -100.74 4038.78 5960873.46 680071.16 12.37 -4021.92 10550.00 88.70 239.10 8798.55 8731.25 -117.23 4013.73 5960856.39 680046.51 16.74 -3995.78 10580.00 88.70 242.60 8799.23 8731.93 -131.84 3987.55 5960841.17 680020.67 11.66 -3968.64 10610.00 88.70 246.40 8799.91 8732.61 -144.75 3960.48 5960827,64 679993.92 12.66 -3940.73 10640.00 88.90 249.50 8800.54 8733.24 -156.01 3932.68 5960815.73 679966.39 10.35 -3912.22 10670.00 90.10 252.00 8800.80 8733.50 -165.90 3904.36 5960805.18 679938.32 9.24 -3883.28 10700.00 90.20 255.40 8800.72 8733.42 -174.31 3875.57 5960796.09 679909.73 11.34 -3853.97 10730.00 89.10 258.50 8800.90 8733.60 -181.09 3846.35 5960768.63 679880.68 10.96 -3824.35 10760.00 88.30 261.10 8801.58 8734.28 -186.40 3816.84 5960782.63 679851.30 9.07 -3794.54 10790.00 91.20 264.40 8801.72 8734.42 -190.18 3787.09 5960778.15 679821.65 14.64 -3764.59 10820.00 93.00 268.80 8800.62 8733.32 -192.48 3757.20 5960775.15 679791.82 10.00 -3734.62 10850.00 94.60 271.20 8798.63 8731.33 -193.01 3727.28 5960773.93 679761.92 15.56 -3704.73 10880.00 94.10 270.00 8798.35 8729.05 -192.69 3697.37 5960773.54 679732.01 4.32 -3674.92 10910.00 93.30 267.80 8794.42 8727.12 -193.27 3667.44 5960772.27 679702.11 7.79 -3645.02 10942.00 68.40 263.10 8793.94 8726.64 -195.81 3635.56 5960768.98 679870.30 21.21 -3613.04 10970.00 87.40 260.40 8794.97 8727.67 -199.82 3607.87 5960764.32 679642.72 10.28 -3585.14 11002.00 89.90 258.90 8795.72 8728.42 -205.57 3576.40 5960757.64 679611.39 9.11 -3553.35 11029.00 90.90 255.60 8795.53 8728.23 -211.52 3550.07 5960751.27 679585.21 12.77 -3526.67 11062.00 90.40 255.80 8795.16 8727.86 -219.68 3518.10 5960742.37 679553.44 1.63 -3494.20 11091.00 91.70 257.10 8794.63 8727.33 -226.47 3489.91 5960734.92 679525.42 6.34 -3465.61 11121.00 92.60 260.60 8793.50 8726.20 -232.26 3460.50 5960728.44 679496.16 12.04 -3435.87 11151.00 93.30 268.20 8791.95 8724.65 -235.19 3430.71 5960724.82 679468.44 25.41 -3405.95 11180.00 93.00 268.30 8790.36 8723.06 -236.07 3401.77 5960723.26 679437.53 1.09 -3377.01 11210.00 90.80 270.00 8789.37 8722.07 -236.52 3371.79 5960722.11 679407.57 9.27 -3347.08 11240.00 91.90 271.20 8768.66 8721.36 -236.20 3341.80 5960721.72 679377.59 5.43 -3317.18 11270.00 98.40 273.90 8786.49 8719.19 -234.87 3311.92 5960722.35 679347.69 17.48 -3287.47 11300.00 97.60 279.60 8782.83 8715.53 -231.38 3282.36 5960725.15 679318.06 19.28 -3258.22 11330.00 98.70 264.30 8779.09 8711.79 -225.21 3253.25 5960730.63 679288.81 15.83 -3229.61 11360.00 92.90 288.80 8776.58 8709.28 -216.70 3224.61 5960738.47 679259.98 19.59 -3201.63 11390.00 91.10 294.80 8775.53 8708.23 -205.57 3196.78 5960748.95 679231.90 20.87 -3174.65 11420.00 93.80 299.60 8775.04 8707.74 -191.86 3170.11 5960762.02 679204.92 16.03 -3149.00 11450.00 90.50 304.70 8774.70 8707.40 -175.90 3144.72 5960777.38 679179.16 17.03 -3124.79 11482.00 90.90 310.40 8774.30 8707.00 -156.41 3119.36 5960796.27 679153.36 17.85 -3100.85 11510.00 92.50 315.60 8773.47 8708.17 -137.33 3098.90 5960814.87 679132.46 19.42 -3081.77 11540.00 90.80 320.70 8772.61 8705.31 -115.00 3078.90 5960836.72 679111.94 17.91 -3063.38 11570.00 90.20 321.80 8772.35 8705.05 -91.61 3060.13 5960859.67 679092.62 4.18 -3046.28 11600.00 90.20 325.20 8772.24 8704.94 -67.49 3042.28 5960683.35 679074.22 11.33 -3030.16 11630.00 89.80 328.20 8772.24 8704.94 -42.42 3025.81 5960908.03 679057.17 10.09 -3015.48 11660.00 90.40 327.20 8772.19 8704.89 -17.07 3009.78 5960933.00 679040.55 3.89 -3001.26 11690.00 91.20 326.00 8771.77 8704.47 7.98 2993.27 5960957.65 679023.46 4.81 -2986.54 11736.00 91.20 326.00 8770.81 8703.51 46.10 2967.56 5960995.16 678996.86 0.00 -2963.54 BP Amoco WELLPA TH DETAILS 15-49A 500292285101 Panmt Wellpath: 1~.49APBI Tie on MD: 9890.00 VerScal S~lfon Origin: Slot o 49 Vet~cal S~ction Angle: 286.00' Rig: Nabors 3S Depth Reference: 8'/: 49 51301199~ 17:16 67o30[t ,, REFERENCE INFORMATION Cc>odnale(NtE)Rele~nce: WetlCen~e: 15-49, TrueNoth Sectlm (VS) Reference: S~I - 49 (0.00,0.00) Measured Del]h R~aterenc~ 6;': 49 5/30'1~)6 17:16 67.3 ~ve Mean See Level N4NOTATION$ No. 'IV0 MD Annotauon 1 8586.12 9890.00 Kk:k.offPoklt 2 870~.51 11736.00 PmjectedtoTD BAKER HU~.HE INTEQ TARGET DE?A1L$ No. TVD +N/-S +E/-W Target 8710.00133.47 2942.?4 15-49AT2.3eTO 8715.00-226.05 3684.56 1549AT2.2 3 8720.00 148.00 4199.51 15-49AT2.1 BPAmoco LEGEND 15-49,15-4g~F~n #2 15-49 (15-49) 15-49 (15-4g/~PB1) 15-49 (15-49PB1) ~T Azimuths to True No~th I /I\ M,tasnctic Norlh: 26.~°1 c.a::d By: Brij Polli~ Dill: 9/I 1/2000 I/ St~¢nSth: 5748l nT~ C~dac~ mlorma~,an /'~f-,, Dip An81~: 80.79'! M~cl: BGGM20~I I ~1400 -4200 -4000 -3800 -3600 -,3400 -3200 -3000 -2800 Vertical Seotion at 266.00° [200rUin] Plot 1122/2001 10:28 AM ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X (set IBP f/GSO) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 603' FNL, 5162' FEL, Sec. 22, T11N, R14E, UM At top of productive interval 307' FNL, 914' FEL, SEC 22, T11N, R14E, UM At effective depth At total depth 559' FNL, 2198' FEL, SEC 22, T11N, R14E, UM 5. Type of Well: Development __X Explorato~__ StratigraphY__ (asp's 676031, 5960879) (asp's 680274, 5961276) (asp's 678996,5960995) 6. Datum elevation (DF or KB feet) RKB 67.3 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 15-49A 9. Permit number / approval number 200-113 10. APl number 50-029-22651-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 3600' Production 9288' Liner 7237' Liner 2289' 11736 8772 feet Plugs (measured) feet 11090 feet Junk (measured) 8796 feet Size Cemented 20" 260 Sx AS 9-5/8" 1030 Sx CS III, 305 Sx Class G, & 345 Sx CS II 7" 200 Sx Class G 4-1/2" 325 Sx Class G 2-7/8" 26 bbls 15.8 ppg LARC Set IBP on 11/16/2000 @ 11090' MD. Measured Depth True vertical Depth 110' 110' 3667' 3572' 9355' 8213' 9744' 8799' 11736' 8772' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 10130' - 10320'; 10430'- 10560'; 10640'- 10680'; 10797'- 10830'; 10870'- 11011'; (isolated below IBP are 11150' - 11203' & 11280' - 11650% 8792' - 8797'; 8799' - 8800'; 8802' - 8802'; 8803' - 8802'; 8798' - 8797'; (isolated below IBP are 8793' - 8791' & 8786' - 8773'). 4-1/2", 12.6#, L-80 Tbg @ 9212' MD. 7" X 4-1/2" BAKER S-3 PACKER @ 9177' MD. 4-1/2" HES HXO SVLN SSSV @ 2223' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure RECEIVED DEC 07 2000 ~'.~,o n;~ · c,~s Gens. Commission ............. Anchorage 14. Prior to well operation Subsequent to operation OiI-Bbl 1438 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 41756 0 2702 5018 0 Casing Pressure Tubing Pressure - 986 363 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended Service 17. I hereby certi,~ that the foregoing is true and correct to the best of my knowledge. Signpr:dstonEvans,~/~'J~/.,'~ ~ ~'~ Title: DS 15 Surveillance Engineer Prepared by Paul Rauf 564-5799 ~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 15-49A (~ DESCRIPTION OF WORK COMPLETED SET IBP FOR GSO Date Event Summary 10/09/2000: 11/1612000: RIH & mn PDS Mem STP/Jewerly Log. Saw majority of gas flow f/11530' - 11650'. Performed a gas shutoff w/an IBP as follows: MIRU CTU. PT'd equip to 3500 psi. Killed well w/filtered Seawater. RIH &set 2-1/8" IBP in the 2-7/8" Liner @ 11090' CTM to isolate the following perforation zones located @: 11150' - 11203' (Zone lA) 11280' - 11650' (Zone 1 B) Confirmed set. POOH. FP'd well. RD CTU. Placed well BOL & obtained production data. Page 1 MEMORANDUM TO: Julie Heusser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 20, 2000 THRU' Tom Maunder, ~ P. I. Supervisor-'~'" ' ~' t t/3 ~ FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve System Tests BPX / DS-15 Prudhoe Bay Field / PBU Monday, November 20~ 2000: I traveled to BPX's DS-15 to witness two miscellaneous Safety Valve System tests on oil producing wells 15-14 and 15-49A in the Prudhoe Bay Field. Kurt Horst (BPX operator) conducted the tests in a safe and proficient manner. Both wells SVS systems passed their tests. The wellhouses were inspected and found to 'be in good condition and the pad was clean. SUMMARY: I witnessed the SVS tests on two wells on Drillsite 15 in the Prudhoe Bay Field.. 2 wells; 4 components; 0 failures. 2 wellhoUses inspected; 0 failures. Attachments: SVS PBU DS-15 11-20-00 JJ~xls CC: NON-CONFIDENTIAL SVS PBU DS-15 11-20-00 JJ.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: BPX Operator Rep: Kurt Horst AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBF/PBU/DS-15 Separator psi: LPS 188 Date: 11/20/00 HPS 685 Well Permit Separ Set L/P Test Test Test Date. Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 1'5-i4 181-1700 685 600 480 P P ' OIL 15-49A ii ~0.,113¢'~ 188 150 140 P P OIL Wells: 2 Components:.. 4.Failures: 0 Failure Rate: 0.0% I-]90 Day Remarks: 2 Misc. 'SVS.tests; 0 failures. 2 wellhouses were inspected; no exceptions noted. 11/21/00 Page 1 of 1 SVS PBU DS-15 11-20-00 JJ.xls TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOG~ Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Robert Richey ProActive Diagnostic Services, Inc. 310 K Street Suite 200 Anchorage, AK 99501 LoG CD-ROM MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR FLOPPY FILM BLUELINE Open Hole I I 1 ,,, Res. Eval. CH 1 1 1 15-49a -- ~10-09-00 Mech. CH 1 Rpt or Caliper Sur~ey ~ ~ C ~ ~' ~"D 1 BL/1F Print Name: Naska 0il & Gas Cons. Comm[Ssio~ Anchorage ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog, com Website: ~v~,~v. memorvl.oa, c~o.i~. TRANSMITTAL ProActive Diagnostic Services, Inc. State of Alaska AOG~ Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Robert Richey ProActive Diagnostic Services, Inc. 310 KStreet Suite 200 AnChorage, AK 99501 LoG CD-ROM MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR FLOPPY FILM BLUELINE Open Hole I I 1 15~9a 10~)9~0 1 1 1 Mech. CH 1 .... Caliper Survey I Rpt or 1BL/1F Signed: Print Name: Date: ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: Ixtsanchorage~memorylog. com Website: ww~¥. memo 1012100 Scklumbe NO. 569 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATFN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.8. [3-Z6 20329 RS? I.A. tC..- ~ ~"'~ t,~ 000727 I I 1 D.8. Z5-49A 20370 .CN~ ~ ~--J~O 00083[ · I I 1 · · · , .. . · · · · · · __ SIGNED: DATE: Please sign a.d return o.e copy of this transmittal to Sherrio at tho above a.dress or fax to (907) STATE OF ALASKA ALA , OIL AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well , Oil r~l Gas D Suspended r'l Abandoned ["'1 Service BP Exploration (Alaska), Inc. . ~ 200-113 3. Address --~I' 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612 50-029-22651-01 4. Location of well at surface ~ -~-?:...~..~ 9. Unit or Lease Name 603' FNL, 5162' FEL, Sec. 22, T11N, R14E, UM (asp's 67~031, 5960879)I ,i :.i}i ~'" Prudhoe Bay Unit At Top Produdng Interval!' ~'~'~' ',~:~'~i~ [ 10. We#Number 307' FNL, 914' FEL, SEC 22, T11N, R14E, UM (asp's 680274, 5961276) · 15-49A At Total Depth ', ___*~~ 11. Field and Pool 559' FNL, 2198' FEL, SEC 22, T11 N, R14E, UM (asp's 678996, 5960995); ................-~"~"--~"g Prudhoe Bay Field 5. Elevation in leer (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. RKB 67 feetI ADL 28306 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Su,~.~ (~l'bAband. 115. Water Depth, if offshore 16. No. of Completions August 21, 2000 August 29, 2000 September,,~, Z0'00 I N/A ~eet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11736' MD /8772' TVD 11702' MD /8773' TVD YES [~] No r~I 2223, feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR & Mere GR/CCL/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110 30" 260 Sx AS 9-5/8" 40# L-80 Surface 3667' 12-1/4" 1030 Sx cs III, 305 Sx Class G, & 345 Sx CS II 7" 26# L-80 Surface 9355' 8-1/2" 200 Sx Class G 4-1/2" 12.6# L-80 5062 9744' 6" 325 Sx Class G 2-7/8" 6.5# L-80 9447' 11736' 4-1/8" 26 bbls 15.8 ppg LARC 24. Pedorations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 9212' 9177' 10130' - 10320' MD; 8792' - 8797' TVD; @ 4 SPF 10797' - 10830' MD; 8803' - 8802' TVD; @ 4 SPF~\ L, %~ L=D~EI:~I-H~II~I'~RVAL (MD) AMOUNT & KIND OF MATERIAL USED 10870' - 11011' MD; 8798' - 8797' TVD; @ 4 SPF 11150'- 11203' MD; 8793'- 8791' TVD; @ 4 SPF UL El U U ~J (See Sidetrack Summary for details) 27. AI~ Date First Production Method of Operation (Flowing, gas/~'¢j~ c~, ,~~.. · September 15, 2000 Gas Lift Date of Test Hours Tested f Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 9/26/2000 3.0 Test Pedod ·I 25627 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -1166 psi 24-Hour Rate · 1484 38030 0 28. CORE DATA r'~ !-~ I ~ I ~ I A I Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. U I'~ I ~ I I~! ~ L ~ This 10'407 iS submitted as directed per the 10-401 form approved August 3, 2000 {Permit #200-113) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top of Sag River Sand Top of Shublik Top of Sadlerochit Top of Zone 1 l~ GEOLOGIC MARKERS(~'~ MEAS. DEPTH 9345' 9394' 9496' TRUE VERT. DEPTH 8205' 8245' 8329' 8731' Top of Zone lA 9996' 1OO46' 8762' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. RECEIVED OCT ? 7 Oil & C~ O0~s. 31. LIST OF ATTACHMENTS Summary of 15-49A CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the lollowing is true and correct to the best of my knowledge. Signed ~(~f)t. ~ ~, ,_ _~~'~ Title Coil Tubin.q Drillin.q E n.qineer Lamar Gantt Date INSTRUCTIONS Prepared by Paul Rau! 564-5799. 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 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 15-49A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summar~ 8/20/2000: 8/21/2000: 8/22/2000: 8/23/2000: 8/24/2000: 8/2512000: 8/26/2000: 8/27/2000: 8/28/2000: 8/29/2000: 8/30/2000: 8/31/2000: 9/01/2000: 9/02/2000: 9/03/2000: 9/11/2000 - 9/14/2000: MIRU CTU#4. Accepted CTU 10:00 hrs. MIRU Nabors 3S. Rig accepted 07:00 hrs. Completed BOPE test. RIH & tagged top of Whipstock @ 9744' MD. Began window milling operations through the 4-1/2" liner. Milled window f/9744' to 9750.5'. Drilled FM to 9761' & POOH. MU E-line coil. RIH & drilled to 9810'. Swapped to FIo Pro. Ddlled to 9840' MD & POOH. RIH & drilled to 9911'. POOH - bit, motor, & BTM half of orienter left behind in hole as fish. RIH & made several attempts to recover fish - no recovery. Made one additional attempt to latch fish - no recovery. RIH w/OH Whipstock & set @ 9885'. POOH. RIH & tagged top of Whipstock @ 9869' MD. Drilled off Whipstock to 10185' & POOH. RIH & drilled to 10565'. Drilled to 10945' & became stuck. Circ'd Crude & freed CT. Drilled ahead to 11198'. Drilled to 11263' & POOH. PT'd BOPE. RIH & drilled to 11330'. Drilled to 11587' & POOH. RIH & drilled to TD @ 11736'. Conditioned hole for liner run. POOH. MU 2-7/8" 6.5# FL4S L-80 liner. RIH & landed liner @ 11736'. TOL = 9447'. Dropped ball & disconnected f/liner. Pumped 26 bbls of 15.8 ppg LARC to cement liner in place. Did not see wiper dart land in liner wiper plug. Cleaned out wellbore w/KCL Water & POOH. Found dart & liner wiper plug @ running tool. Liner not wiped. RIH w/milling BHA & tagged up @ the landing collar @ 11702'. Did not tag any cement. POOH. Tested liner lap to 1500 psi - lost 35 psi in 15 min. RIH w/Mem GR/CNL/CCL logging tools & logged well. POOH. MU perf guns. RIH w/CT conveyed Perf guns & shot 957' of Initial Perforations f/: 10130'- 10320' MD (Zone lA) 10430' - 10560' MD (Zone lA) 10640' - 10680' MD (Zone lA) 10797'- 10830' MD (Zone lA) 10870'- 11010' MD (Zone lA) 11150'- 11203' MD (Zone lA) 11280'- 11650' MD (Zone lB) Used 2" carriers & shot all Perfs @ 4 SPF& overbalanced press. POOH w/guns. ASF. FP'd well. RDMOL. 3S released 1100 hrs. CTU#4 released 1300 hrs. Installed GLV's. Drifted to 10037' SLM (HAW). Placed well 15-49A on initial production & obtained a valid well test. Sidetrack Summary Page 1 BP Amoco WELLPATH DETAILS 15-49A 500292265101 Parent Wellpath: 1~49APB1 Tie on MD: 9890.00 Vart]celSecdonOrlgln: Slot-49(0.00,0.00) Vertical Section Angle: 266.00° Rig: Nabore 3S Depth Referonce: 67:495/30/199617:16 BPAmoco LNTEQ / "~;~';' LEGEND tS-4e 05-49) 1,~4g (15-4gAFf31) 1549 (15-49PB1) 15-49A T ( I 5.49/15-49A} Azimuths to Tn~ Norlh Magn~ic R~d I ~ . ~p Angle: 80.79 REFERENCE INFORMATION Co-ordinate (N/E) Refereme: Well Centre: 15.49, True North Vertical OVD) Refemoce: Reid - Moan Sea Lsvel Section (VS) Reference: Slot - 4g (0.(30,0.00) Measured Depth Reference: 67: 49 5/30/1996 17:16 67.3 above Mean Sea Level Calculation Method: Minimum Curvature 500.-.--~ ................................................... ~ ........... ~ ........... ~ ........... ~ .......... ~ ................................................................ ~ il; .... ................. : ......................... ............... 8200......~ ................................................................................................................................................ '-i -soo-.--i .......... i ........... i ........... i .......... i ......... i- ......... ~ ......... ! ..... i ..... ,. ......... ! .... ! ......... i ........ i ....... !. .......... i ......... i ....... ~ ........ ~ ..... !- ......... ~ ~' ...i. ........................................... i ........................................................... i......~ ...................... ~0'00 ~s~)o 3000 3soo 400o 4soo ~' "'i ~/~ ..................... Wesf~-)/East(+) [500fdi n] ...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' ! ,~,4~ 8800-~ ~ .............................. i ................... ! ........................ ;--! ..... i-. !. i .i i ...... i i ....... i ...... ; ..... i ....... i ...... i : i : i : . . i : : - -4400 -4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 Vertical Section at 266.00' [200ft/in] Prepared by Baker Hughes INTEQ INTEQ 'nd of Well Survey CalculatiJns Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLANE Company: Field: Well: Job No: AFE No: AP1 No: BHI Rep: BP Exploration Alaska, Inc. Prudhoe Bay Unit 15-49A (Drilled from 15-49APBI) 71888 4K-006 50-029-22651-01 Rig: Nabors 3S RKB Height: 67.300 Vertical Sect. Plane: 266.000 Mag. Declination: 27.123 Grid Correction: 1~340 Job Start Date: i~!~~iiiiiiii=:i!iiiiii!i Meas. Depth (ft) 9890.00 9922.00 9951.00 9981.00 10011.00 10040.0~ 10070.00 10100.00 10131.00 10160.00 Incl. Angle (deg) 45.60 (deg) 128.80 43.30 144.30 42.50 44.8( 159.60 170.20 48.80 179.40 55.60 180.20 63.60 184.70 72.30 186.00 80.40 188.20 84.90 195.10 10190.00 89.90 200.00 10221.00 89.50 203.50 10251.00 91.20 204.00 10280.00 91.30 207.70 10310.00 89.40 210.60 10340.00 90.90 88.60 87.50 10367.00 10400.00 10430.00 89.60 10459.00 89.10 10490.00 90.10 10520.00 89.80 10550.00 88.70 10580.00 88.70 10610.00 88.70 88.90 90.10 10640.00 10670.00 215.10 217.10 220.0~ 222.60 226.10 230.50 234.20 239.10 242.60 246.40 249.50 252.00 10700.00 90.20 255.40 10730.00 89.10 258.50 10760.00 88.30 261.10 91.20 264.40 93.00 266.80 94.60 271.20 94.10 270.00 93.30 267.80 88.40 263.10 87.40 260.40 89.90 258.90 9O.90 255.6~ 90.40 255.80 91.70 257.10 10790.00 10820.00 10850.00 10880.00 10910.00 10942.00 10970.00 11002.00 11029.00 11062.00 11091.00 11121.00 11151.00 11180.00 11210.00 11240.00 92.60 93.30 260.60 268.20 93.00 268.30 90.80 270.00 91.90 271.20 TRUE V. Depth (ft) 8653.42 8676.33 8697.63 8719.37 8739.92 8757.69 8772.86 8784.11 8791.42 8795.14 8796.50 8796.66 8796.48 8795.84 8795.66 8795.58 8795.70 8796.82 8797.58 Subsea TVD (ft) 8586.12 8609.03 8630.33 8652.07 8672.62 8690.39 8705.5( 8716.81 8724.12 8727.84 8729.20 8729.36 8729.18 8728.54 8728.36 8728.28 8728.40 8729.52 Coords. - True N(+)/S(-) (ft) 400.83 384.70 367.40 347.46 325.72 302.82 277.00 249.35 219.48 191.34 162.78 133.99 106.54 80.45 54.25 29.O6 -18.55 E(+)/W(-) (ft) 4219.66 4235.02 4244.26 4249.60 4251.52 4251.59 4250.45 4247.85 4244.12 4238.31 4229.27 4217.79 4205.71 4193.07 4178.46 4162.19 4146.28 4125.73 Coords.- ASP N(+)/S(-) Lat. (Y) 5961379.10 5961363.34 5961346.25 5961326.44 5961304.76 5961281.87 5961256.03 5961228.33 5961198.38 5961170.11 5961141.36 5961112.31 5961084.58 5961058.20 5961031.67 5961006.11 5960983.93 5960957.66 E(+)/W(-) Dep. (X) 680240.23 3960.48 680255.96 680265.61 680271.41 680273.84 680274.45 680273.91 680271.96 680268.93 680263.78 680255.41 680244.61 680233.17 680221.15 680207.16 680191.48 680176.09 680156.16 Dogleg Severity (°/100ft) 0.00 34.61 35.96 25.54 26.01 23.55 29.63 29.28 27.02 28.24 23.32 11.36 5.91 12.7~ 11.56 15.81 11.29 5960827.64 9.39 8730.28 -41.07 4105.94 5960934.68 680136.90 11.14 8797.91 8730.6~ -61.81 4085.67 5960913.48 680117.12 12.19 8798.13 8730.83 -82.42 4062.53 5960892.33 680094.47 14.55 8798.15 8730.85 -100.74 4038.78 5960873.46 680071.16 12.37 8798.55 8731.25 -117.23 4013.73 5960856.39 680046.51 16.74 8799.23 8731.93 -131.84 3987.55 5960841.17 680020.67 11.66 8799.91 8732.61 -144.75 5960815.73 5960805.18 5960796.09 5960788.63 5960782.63 679993.92 8733.24 8733.50 8733.42 8733.60 8734.28 8734.42 8800.54 8800.80 8800.72 8800.90 8801.58 8801.72 -156.01 -165.90 -174.31 -181.09 -186.40 3932.68 679966.39 679938.32 679909.73 679880.68 679851.30 679821.65 679791.82 5960778.15 3904.36 3875.57 3846.35 3816.84 3787.09 3757.20 -190.18 8800.62 8733.32 -192.48 8798.63 8731.33 -193.01 3727.28 8796.35 8729.05 -192.69 3697.37 8794.42 8727.12 -193.27 3667.44 8793.94 8726.64 -195.81 3635.56 8794.97 8727.67 -199.82 3607.87 8795.72 8728.42 -205.57 3576.40 3550.07 8795.53 8728.23 -211.52 8726.20! 8795.16 8727.86 -219.68 3518.10 8794.63 8727.33 -226.47 3489.91 8793.50 -232.26 3460.50 8791.95 8724.65 -235.19 3430.71 8790.36 8723.06 -236.07 3401.77 8789.37 8722.07 -236.52 3371.79 8788.66 8721.36 -236.20 3341.80 5960775.15 12.66 10.35 11.34 10.96 9.07 14.64 Vertical Section (ft) -4237.3, -4251.5, -4259.5: -4263.4~ -4263.8~ -4262.3~ -4259.4: -4254.8! -4249.0! -4241.3: -4230.3: -4216.8~ -4202.8! -4188.& -4172.0~ -4154.01 -4136.6! -4114.3! -4093.0' -4071.4~ -4046.8! -4021.9~ -3995.71 -3968.6, -3940.7~ -3912.2: -3883.2~ -3853.9~ -3824.3! -3794.5, -3764.5! 10.00 -3734.6: 5960773.93 679761.92 15.58 -3704.7! 5960773.54 679732.01 4.32 -3674.95 5960772.27 679702.11 7.79 -3645.~ 5960768.98 679670.30 21.21 -3613.¢ 5960764.32 679642.72 10.28 -3585.1z 5960757.84 679611.39 9.11 -3553.3~ 5960751.27 679585.21 12.77 -3526.6~ 5960742.37 679553.44 1.63 -3494.2( 5960734.92 679525.42 6.34 -3465.61 5960728.44 679496.16 12.04 -3435.8~ 5960724.82 679466.44 25.41: -3405.9~ 5960723.26 679437.53 1.09 -3377.0] 5960722.11 679407.57 9.27 -3347.0~ 5960721.72 679377.59 5.43 -3317.1~ Meas. ° Ind. TRUE TR~I~r Subsea Coords. - True ~ 'oords. - ASP Dogleg Vertic~ Depth Angle Azi. V. ~el~._ TVD N(+)/S(-) E(+)/W(-) Nt,, ~-) E(+)FvV(-) Severity Section ,,, (fi) (de~) (de~) (ft) (fi) (~) (~) Lat. (Y) DeF. (X) (°/100ft) (ft) 11270.00 96.40 273.90 8786A9 8719.19 -234.87 3311.92 5960722.35 679347.69 17.48 -3287A 11300.00 97.60 279.60 8782.83 8715.53 -231.38 3282.36 5960725.15 679318.06 19.28 -3258.: -- 11330.00 96.70 284.30 8779.09 8711.79 -225.21 3253.25 5960730.63 679288.81 15.83 -3229.~ 11360.00 92.90 288.80 8776.58 8709.28 -216.70 3224.61 5960738.47 679259.98i 19.59 -3201.{ 11390.00 91.10 294.80 8775.53 8708.23 -205.57 3196.78 5960748.95 679231.90 20.87 -3174.{ 11420.00 90.80 299.60 8775.04 8707.74 -191.86 3170.11 5960762.02 679204.92 16.03 -3149.( 11450.00 90.50 304.70 8774.70 8707.40 -175.90 3144.72 5960777.38 679179.16 17.03 -3124.q 11482.00 90.90 310A0 8774.30 8707.00 -156.41 3119.36 5960796.27 679153.36 17.85 -3100.8 11510.00 92.50 315.60 8773.47 8706.17 -137.33 3098.90 5960814.87 679132.46 19.42 -3081.q 11540.00 90.80 320.70 8772.61 8705.31 -115.00 3078.90 5960836.72 679111.94 17.91 -30632 11570.00 90.20 321.80 8772.35 8705.05 -91.61 3060.13 5960859.67 679092.62 4.18 -3046.5 11600.00 90.20 325.20 8772.24 8704.94 -67.49 3042.28 5960883.35 679074.22 11.33 -3030.1 m, 11630.00 89.80 328.20 8772.24 8704.94 -42.42 3025.81 5960908.03 679057.17 10.09 -3015.~ 11660.00 90.40 327.20 8772.19 8704.89 -17.07 3009.78 5960933.00 679040.55 3.89 -3001.~ 11690.00 91.20 326.00 8771.77 8704A7 7.98 2993.27 5960957.65! 679023.46 4.81 -29862 11736.00 91.20 326.00 8770.81 8703.51 46.10 2967.56 5960995.16 678996.86 0.00 -29632 ~nd of Well Survey Calculati~ss Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLANE Meas. Depth (~t) 9770.00 9800.00 Company: Field: Well: Job No: AFE No: API No: BHI Rep: Incl. Angle (del~) 36.46 BP Exploration Alaska, Inc. Prudhoe Bay Unit 15-49APB1 (Drilled from 15-49) 71888 4K-006 50-029-22651-71 Rig: Nabors 3S RKB Height: 67300 Vertical Sect. Plane: 266.000 Mag. Declination: 27.123 Grid Correction: 1340 Job Start Date: Survey Date: Survey Type: ::::?:?:::::::?:?::::::::::::::5:::::::::::::: (del~) 88.30 TRUE V. Depth (ft) Subsea TVD fit) Coords. - True N(+)/S(-) (ft) E(+)/W(-) (ft) Coords.- ASP N(+)/S(-) Lat. (Y) E(+)/W(-) Dep. (X) 680173.70 8559.67 8492.37 431.19 4153.82 5961407.91 34.80 103.00 8584.10 8516.80 429.52 4171.11 5961406.65 680191.02 9830.00 36.50 118.60 8608.53 8541.23 423.31 4187.32 5961400.82 680207.37 128.70 39.30 8632.22 8654.34 8670.44 45.60 8564.92 8587.04 8603.14 9860.00 9890.00 413.09 400.42 390.13 9913.00 4202.58 4218.37 4231.17 45.60; 128.80 5961390.96 5961378.66 5961368.67 128.80 680222.8~ 680238.95 680251.99 Dogleg Severity (°/100ft) Vertical Section -4173.7 0.00 29.02 -4190.9 30.76 -4206.6 22.66 -4221.1 21.00 -4236.0 0.00 -4248.0 MEMORANDUM TO: THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Aug. 27, 2000 SUBJECT: Dan Seamount Commissioner c:~/-~O,/~ Blair Wondzell P.I. Supervisor Jeff Jones J',.o.-~J~ Petroleum Inspector NON- CONFIDENTIAL Blowout Preventer Test Nabors-Dowell 3S BPX DS-15 15-49A 200-113 PBFIPBU Operator Rep.: Gary Goodrich Contractor Rep.: Eloy Muniz Op. phone: 659-5515 Rig phone: 659-5514 Op. e-mail: Rig e-mail: Test Pressures Rams: 250/3500 Annular: 250/2500 Choke: 250/3500 P/F P/F Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. Standing Order Posted .~P Upper Kelly Lower Kelly Ball Type Inside BOP Quantity P/F N/A N/A 1 P N/A Visual' Alarm P P P P BOP STACK: Quantity Size/Type P/F Stripper 1 5 1/8 TOT P Annular Preventer 1 7 1/16" P #1 Rams I Blind/Shear P ~r2 Rams 1 2 3/8" PIS P #3 Rams 1 2 7~8" Slip P #4 Rams 1 2 7/8" Pipe P #5 Rams N/A Choke Ln. Valves 1 3 1/8" P HCR Valves 1 3 1/8" P Kill Line Valves 2 3 1/8" P Check Valve N/A CHOKE MANIFOLD: Quantity P/F No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector P P P ,P P P Quantity P/F Inside Reel valves 1 P ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 2800 P Pressure After Closure ~:2000 P 200 psi Attained 21 sec. P Full Pressure Attained 48 sec. P Blind Switch Covers: All P Nitgn. Bottles (avg.): 4(~1800 P Sunday, August 27~ 2000: I traveled to BPX's PBU DS-15 to witness a weekly BOPE test on Nabors Rig 3S performing a re-drill operation on well 15-49A. The testing lasted 5.5 hours and I observed no failures. I witnessed a successful test oft_he H2S and methane gas detector alarm system. I presented Nabors-Dowell representative Eloy Muniz with a draft copy of the H2S Preparation Checklist and we discussed each item. The Nabors-Dowell crews performed the testing in a safe and proficient manner, The rig and it's equipment appeared clean and in good cOndition and the drillsite well organized. Summary.: I witnessed a successful weekly BOPE test on Nabor-Dowell Rig 3S Performing a re-drill operation on BPX's well # 15-49A. Total Test Time: 5 112 Number of failures: 0_ Attachments: 0_ cc: V07rtcdo.xls 8/29/00 ALASKA OIL AND GAS CONSERVATION COPlPllSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Kara Coil Tubing Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 ge~ Prudhoe Bay Unit 15-49A BP Exploration (Alaska), Inc. Permit No: 200-113 SurLoc: 603'FNL, 5162'FEL, Sec. 22, TllN, R14E, UM Btmhole Loc. 473'FNL, 2221'FEL, Sec. 22, TllN, R14E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling 'new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Commissioner BY ORDER OF THE COMMISSION DATED this .~ ~ day of August, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEiVE JUL 21 ?.000 q ~aska 0{.'i & Gas Cor, s. Commission Ancflorage la. Typeolwork: Dri, r"l Reddllr~] I lb. Type ot well. Exploratory r'] StratigraphicTestD Development Oil F~'] Re-entry D Deepen DJ Service D Development Gas D Single Zone [~] Multiple Zone D 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska), Inc. RKB 67 feet 3. Address 6. Properly Designation Prudhoe Bay Field P. O. Box 196612 Anchorage, AK 99519-6612 ADL 28306 Prudhoe Bay Oil Pool 4. Location of well at surface .~ ,/ ,/ 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 603' FNL, 5162' FEL, Sec. 22, T11N, R14E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 191' FN L,' 1165' FEL, Sec. 22, T11 N, R 14E, UM 15-49A #2S 100302630-277 At total depth 9. Approximate spud date Amount 473' FNL, 2221' FEL, Sec 22, T11 N, R14E, UM August 9, 2000 $200,000 12. Distance to nearest property line J 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 28307, 2221' @ TD feetJ No Close Approach feet 2560 11730 MD / 8767 TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickolf depth: 9730' MD Maximum hole angle 95° Maximum surface 2450 psi~l At total depth (TVD) 3300 psi~ @ 8800' 18. Casing program Settin~l Depth size Specifications Top Bottom Quant~ of Cement Hole Casin~l Wei~lht Grade couplin~l LenCh MD TVD MD TVD (include sta~le data) 3-3/4" 2-7/8" 6.4 L-80 FL4S 2300' 9430' 8274' 11730' 8767' 27 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 12299 feet Plugs (measured) Tagged PBTD @ 10218' MD on 6/09/1999. tree vertical 8799 feet ClBP @ 11400' MD. Effective Depth: measured 10218 feet Junk (measured) tree vertical 8794 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 260 Sx AS 110' 110' Surface 3600' 9-5/8" 1030 Sx CS III, 305 Sx Class G, & 345 Sx CS II 3667' 3572' Production 9288' 7" 200 Sx Class G 9355' 8213' Liner 7237' 4-1/2" 325 Sx Class G ORIGINAL 12299' 8799' Perforation depth: measured 10233'-110365'; 10395'-10520'; 10550'-10996'; 11045'-11190'; 11238'- 11335'; 11440'- 11670'; 11700' - 11816'; 11900'- 12053'. tree vertical 8797' - 8810'; 8809' - 8811'; 8811' - 8810'; 8811' - 8818'; 8820' - 8819'; 8821' - 8822'; 8822' - 8821'; 8818' - 8816'. 20. Attachments Filing fee r~ Property Plat D BOP Sketch [~] Dive,er Sketch D Drilling program r~ Drilling fluid program Time vs depth plot D Refraction analysis D Seabed report D 20 AAc 25.050 requirements D 21.1 hereby certify that the fo~and correct to the best of my knowledge Questions? Call Dan Kuru@263-4837. Signed ~~"~'~~ Title: Coil Tubing Drilling Engineer Date '"~ ~ ,~/~ Dan Kara ~ Prepared b)~ Paul Rauf 263-4990 Commission Use Only Permit NUmber APl number ~V~ I Appr~a~d.,~te i/~) ISee cover letter Zoo - //~e~ 50- O e.~-. Z ~ ~'~/'"-,. , _/VlV b Ifor other requirements Conditions of approval Samples required [~ Yes J~ No Mud ,ogYequi~d [~ Yes [] ,o Hydrogen sulfide measures ~! Yes D No Directional survey required J~ Yes D No Required working pressure lor BOPE F"~2M; D 3M; r-~ GM;; ~ 1OM;D r~3500psiforCTU~ Other: ORIGINAL SIGNED BY by order of ] /0~) ~proved by D Taylor Seamount commissioner the commission Date ~) ,.~ Form 10-401 Rev. 12/1/85 · Submit in triplicate DS 15-49A CT Sidetrack and Completion Intended Procedure Objective: Drill a sidetrack from the existing wellbore to reach new target. Existing perfs will be isolated with two CIBPs, the window milled off a whipstock with a service CTU and the well sidetracked with CTD. A 2-7/8" liner will be cemented and perforated. Intended Procedure: Install mechanical whipstock at 9730' (above CIBP) and mill window in 4-1/2" liner with service CTU. · RU CTD. Directionally drill a 3-3/4" well from 9730' to 11730' (2000' openhole) to access Zone 1 reserves. Run 2-7/8" blank liner from TD to 9430' (300' of 4-1/2" liner lap). Cement in place. Run memory CNL, perforate, place on production. NOTE: Drill cuttings will be disposed of at GNI and drilling mud will be disposed at GNI or Pad 3. RECEIVED JUL 2 1 2000 .Alaska 0[';. & Gas Cons. Commission Anchorage July 19, 2000 DS 15-49A Potential Drilling Hazards POST ON RIG H2S production is not anticipated from this well. Continue to ensure all H2S monitoring equipment is operational. BHP: 3300 psi @ 8800' ss (7.2 ppg EMW), BHT 200 °F (estimated pressure). No over-pressured zones are anticipated. Maximum anticipated WHP w/full column of gas: 2450 psi. High perm intervals are expected across the Sadlerochit. No major faults are anticipated. The well will be drilled with 8.9 ppg mud. RECEIVED JUL 2 1 2000 AJask~ O~; & Gas C~ns. Con, mission Anchorage July 19, 2000 SSSVN @ 2223' 9-5/8" Shoe @ 3667' 4-1/2", 12.6#, L-80 Production Tubing to Surface X Nipple @ 9200' 7" x 4-1/2" Baker S-3 Packer @ 9177' 4-1/2" TT / 4-1/2" Liner Top @ 9212' 7" Shoe @ 9355' 4-1/2" Liner RECEIVED JUL 2 1 200O ,Alaska Oi~ & Gas Cons. Con~fnission Anchorage 2-7/8" FL4S Liner Top @ 9430' Window through 4-1/2" Liner @ 9730' off Whipstock 2-7/8" FL4S Liner Cemented & Perf'd 3-3/4" Open hole TD @ 11730' Install CIBP @ 9750' to Isolate Existing Perfs in 4-1/2" Liner ClBP @ 11400' PCR 7/19/2o00 BP Exploration Alaska, Inc. WELLPATH DETAILS ~.~.., .o.h: 27. ,2 g~: ~!~j~,~,;,~; Parent Wellpath: 15-49 1000~ ............ ~ ~ ~ ........ ' v~,~ o,g,.., s,,. ~o.00,o.~ i .................... i : i ........... V(~,"ficel ..q~ctlon Angle: 266.00 ........................... Depth Refecence: I~49 6Z3Oft 500-"~ ................................... ~ ......................................................... ? .......................................................... ? ................................. ~''--'v-''~-~ · + ............. ~ ......................... ! ~ 3~64.69 16-49A T3 438710.00 -205.60 .. 9720.m ~2.10 4224.~5 16-49AT1 I 49AT4~ J -5oo'""i .................................... ~ ........................................................... ~ ........................................................... i ........................................................... i ........................................................... i ............................................................................................................................ "i i i ............. i ..~ .............................................................................................. o ........................................................ o .......................................................... ~ ......................................................... ? ......................................................... ~ .................................................... ................... · ; ..................... * ~ i -~ooo ............... i ............................. ~, i .......................... .......... i .......................................................... i ~"- ........... ". ........... ~ .......... i .......... ~ .......... ~ .......... ~ .......... ~ .......... ~ .......... ~ ........... ~ .......... ~ ........... "' .......... ~ .......... ~ .......... " ~ ~'"'"'"'"'- .......... ~ .......... ~ ........... I .......... ~ ........... ~ ........... ~ ........... ~ ........... I ........... t ........... ~ ........... ~ ........... ~ .......... 1 .......... 2500 3000 3500 40~)0 4500 5000 5500 West(-)/East(,) [S00fUin] i .......... i i ..... i':..".'i..'..' ' ! i ..... ! i i \ 1 15~49A'~4OTD J I Plan#1 15-49A ~1 i ..................................................... ! ...................... '"~ ......... ~ ....................... i ........... i ........... 1 ........... ~ ........... i ........... i ........... i ........... i ........... i ........... : ........... ~ ........... ~ ........... ~ ........... i ........... i ........... 1 ........... ~ ........... ~ ........... ~ ........... : ........... r .......... i' .......... i: .......... ~ ........... i .......... ~ .......... i ........... i- .......... r .......... t .......... i- .......... ', ........... '.. ........... ..' .......... ~ .......... r .......... ..' .......... : ........... .., .......... T .......... ? .......... ~ ........... ,.. ........... ~ .......... ! .......... ~ ......... -4400 -4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 Vertical Section at 266.00° [200fl/in] REFERENCE INFORMATION Co-ordinate (N/E) Reference: Wellhead: 1649, True Nollh Vertical (TVD) Reference: Field - Mean Sea Level Section (VS) Reference: Slot - (0.00,0.00) Measured Depth Reference: 16-49 67.3 above Mean Sea Leval Calculation Method: Minimum Cuwature ANNOTATIONS NO. TVO MD Annotation I 8383.10 9640.00 ~ Point 2 ~9.67 e730. C0 Kk~k.~ff Point 43 a4~1.76 9770,00 8700.00 ~ 1730.00 Prepared by Baker Hughes INTEQ RECEIVED JUL 2 1 2000 A~aska 0~ & ~as Cons.'"~"~, Anchoraae Proposal Calculations HU(~Jr~R~ Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ .and ALASKA STATE PLANE Company: BP Exploration Alaska~ Inc. Vertical Sect. Plane: 266.000 TRUE Job No: Field: Prudhoe Bay Unit Mag. Declination: 27.123 AFE No: Well: 15-49A Plan #1 Grid Correction: 1.340 API No: ~0-029-226~1-01 Rig: Nabors 3S Total Correction: 2~.783 BHI Rep: Surface Location Dip: 80.72~; Job Start Date: X: 676031.$ RKB Height: 67.300 Job End Date: Y: 5960879.1 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)fvV(-) Severity Section Comments (de~) (des) (ft) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) 9640.00 31.67 85.42 8383.10 424.73 4084.08 5961399.22 680104.53 0.00 4099.15 0.00 0.00 0.00 Tie-in Point 9695.00 31.37 82.30 8429.99 427.80 4112.66 5961402.96 680133.03 3.02 4127.84 -101.75 -0.55 -5.67 9700.00 31.55 82.64 8434.26 428.14 4115.25 5961403.36 680135.61 4.97 4130.44 45.16 3.52 6.74 9727.00 32.51 84.40 8457.15 429.75 4129.48 5961405.31 . 680149.80 4.97 4144.73 44.87 3.57 6.53 9730.00 32.87 84.80 8459.67 429.91 4131.09 5961405.50 680151.41 13.99 4146.35 31.14 12.00 13.33 Kick-off Point 9740.00 34.68 87.91 8467.99 430.26 4136.64 5961405.98 680156.94 25.00 4151.90 45.00 18.08 31.08 9760.00 38.50 93.33 8484.05 430.10 4148.54 5961406.10 680168.85 25.00 4163.79 42.42 19.10 27.10 9770.00 40.49 95.70 8491.76 429.60 4154.88 5961405.75 680175.20 25.00 4170.10 38.06 19.93 23.74 1 9780.00 39.75 99.41 8499.41 428.75 4i61.27 5961405.05 680181.60 25.02 4176.44 108.71 -7.44 37.08 9800.00 38.63 107.13 85!4.92 425.87 4173.55 5961402.45 680193.95 25.02 4188.58 105.87 -5.59 38.62 9820.00 38.04 115.15 8530.62 421.41 4185.10 5961398.26 680205.60 25.02 4199.92 99.88 -2.94 40.08 9840.00 38.01 123.28 8546.38 415.41 4195.83 5961392.51 680216.47 25.02 4210.37 93.59 -0.17 40.64 9860.00 38.53 131.32 8562.10 407.91 4205.67 5961385.25 680226.48 25.02 4219.85 87.18 2.61 40.20 9880.00 39.59 139.08 8577.63 398.98 4214.53 5961376.53 680235.54 25102 4228.29 80.86 5.28 38.84 9900.00 41.13 146.44 8592.88 388.67 4222.34 5961366.41 680243.60 25.02 4235.63 74.83 7.74 36.77 9920.00 43.12 153.29 8607.72 377.08 4229.05 5961354.97 680250.58 25.02 4241.81 69.22 9.92 34.27 9940.00 45.48 159.61 8622.04 364.28 4234.61 5961342.31 680256.44 25.02 4246.79 64.14 11.81 31.60 9960.00 48.16 165.41 8635.73 350.38 4238.98 5961328.51 680261.12 25.02 4250.51 59.61 13.41 28.98 9980.00 51.11 170.72 8648.69 335.48 4242.11 5961313.69 680264.61 25.02 4252.97 55.64 14.75 26.54 10000.00 54.28 175.59 8660.81 319.69 4243.99 5961297.95 680266.86 25.02 4254.13 52.20 15.85 24.35 10020.00 57.63 180.07 8672.01 303.14 4244.61 5961281.42 680267.86 25.02 4253.99 49.25 16.76 22.44 10040.00 61.13 184.23 8682.20 285.95 4243.95 5961264.22 680267.60 25.02 4252.56 46.73 17.49 20.80 10060.00 64.75 188.12 8691.30 268.25 4242.03 5961246.48 680266.09 25.02 4249.83 44.61 18.09 19.42 10080.00 68.46 191.77 8699.24 250.18 4238.85 5961228.34 680263.34 25.02 4245.84 42.84 18.57 18.28 10100.00 72.25 195.24 8705.96 231.87 4234.45 5961209.93 680259.37 25.02 4240.61 41.39 18.95 17.36 10120.00 76.10 198.57 8711.42 213.47 4228.85 5961191.40 680254.20 25.02 4234.18 40.22 19.24 16.63 , 10140.00 79.99 201.79 8715.56 195.11 4222.10 5961172.89 680247.88 25.02 4226.60 39.32 19.46 16.09 10160.00 83.91 204.93 8718.36 176.94 4214.24 5961154.54 680240.45 25.02 4217.93 38.65 19.61 15.70 Alaska O;i & ~as Gons. Co~misaJ( 10180.00 87.85 208.02 8719.80 159.09 4205.35 5961136.49 680231.98 25.02 4208.24 38.21 19.70 15.48 /~n~nra~o Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Seventy Section Commen~ (de~) (de~) (ft) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) (°/100ft) (Wellheadl (°/100ft) (°/100ft) 10190.89 90.00 209.70 8720.00 149.56 4200.10 5961126.84 680226.95 25.02 4202.56 37.99 19.73 15.40 2 10200.00 90.42 210.31 8719.97 141.66 4195.54 5961118.84 680222.58 8.11 4197.65 55.37 4.61 6.67 10250.00' 92.72 213.65 8718.60 99.28 4169.08 5961075.84 680197.12 8.11 4169.29 55.37 4.60 6.68 10300.00 95.01 217.00 8715.22 58.58 4140.24 5961034.49 680169.24 8.~1 4138.63 55.46 4.59 6.70 3 10350.00 92.92 220.48 8711.76 19.69 4109.03 5960994.87 680138.95 8.12 4105.69 120.97 -4.19 6.97 10400.00 90.81 223.96 8710.14 -17.31 4075.46 5960957.10 680106.25 8.12 4070.47 121.22 4.22 6.94 10419.16 90.00 225.28 8710.00 -30.95 4062.00 5960943.15 680093.11 8.12 4056.41 121.33 -4.22 6.94 4 10450.00 90.00 227.78 8710.00 -52.17 4039.62 5960921.42 680071.23 8.10 4033.08 90.00 0.00 8.10 10500.00 90.00 231.83 8710.00 -84.43 4001.43 5960888.27 680033.81 8.10 3993.47 90.00 0.00 8.10 10550.00 90.00 235.88 8710.00 -113.91 3961.06 5960857.85 679994.14 8.10 3951.81 90.00 0.00 8.10 10600.00 90.00 239.93 8710.00 -140.47 3918.71 5960830.31 679952.42 8A0 3908.29 90.00 0.00 8.10 10650.00 90.00 243.98 8710.00 -163.97 3874.59 5960805~78 679908.86 8.10 3863.15 90.00 0.00 8.10 r~..___ 10700.00 90.00 248.03 8710.00 -184.29 3828.92 5960784.40 679863.68 8.10 3816.60 90.00 0.00 8.10 10750.00 90.00 252.08 8710.00 -201.34 3781.93 5960766.25 679817.10 8.10 3768.89 90.00 0.00 8.10 10800.00 90.00 256.13 8710.00 -215.03 3733.85 5960751.44 679769.35 8.10 3720.23 90.00 0.00 8.10 10850.00 90.00 260.18 8710.00 -225.29 3684.92 5960740.05 679720168 8.10 3670.89 90.00 0.00 8.10 10900.00 90.00 264.23 8710.00 -232.07 3635.39 5960732.~1 679671.33 8.10 3621.11 90.00 0.00 8.10 10950.00 90.00 268.28 8710.00 -235.33 3585.51 5960727.69 679621.53 8.10 3571.13 90.00 0.00 8.10 11000.00 90.00 272.33 8710.00 -235.06 3535.52 5960726.79 679571.55 8.10 3521.20 90.00 0.00 8.10 11050.00 90.00 276.38 8710.00 -231.26 3485.68 5960729.42 679521.63 8.10 3471.58 90.00 0.00 8.10 11100.00 90.00 280.43 8710.00 -223.95 3436.22 5960735.57 679472.02 8.10 3422.51 90.00 0.00 8.10 11150.00 90.00 284.48 8710.00 -213.16 3387.41 5960745.21 679422.97 8.10 3374.24 90.00 0.00 8.10 11200.00 90.00 288.53 8710.00 -198.96 3339.48 5960758.29 679374.72 8.10 3327.01 90.00 0.00 8.10 11250.00 90.00 292.58 8710.00 -181.40 3292.68 5960774.75 679327.52 8.10 3281.05 90.00 0.00 8.10 11280.70 90.00 295.07 8710.00 -169.00 3264.60 5960786.49 679299.16 8.10 3253.56 90.00 0.00 8.101 5 11300.00 90.11 296.63 8709.98 -160.58 3247.23 5960794.50 679281.60 8.12 3236.59 85.85 0.59 8.10! 11350.00 90.41 300.68 8709.75 -136.61 3203.36 5960817.44 679237.18 8.12 3193.86 85.85 0.59 8.101 11400.00 90.70 304.73 8709.27 -109.60 3161.30 5960843.46 679194.50 8.12 3153.07 85.87 0.58 8.101 11450.00 90.98 308.78 8708.54 -79.68 3121.26 5960872.43 679153.77 8.12 3114.42 85.91 0.58 8.10 11500.00 91.27 312.84 8707.56 -47.02 3083.43 5960904.20 679115.19 8.12 3078.12 85.97 0.57 8.10 11550.00 91.54 316.89 8706.33 -11.77 3048.01 5960938.62 679078.95 8.12 3044.33 86.05 0.55 8.10 11600.00 91.81 320.94 8704.87 25.90 3015.17 5960975.50 679045.24 8112 3013.23 86.15 0.54 8.11 11650.00 92.07 324.99 8703.17 65.78 2985.08 5961014.67 679014.22 8.12 2984.99 86.27 0.52 8.11 11700.00 92.32 329.05 8701.25 107.68 2957.89 5961055.92 678986.06 8.12 2959.73 86.41 0.50 8.11i 11730.05 92.46 331.49 8700.00 133.75 2943.00 5961081.64 678970.57 8.12 2946.04 86.56 0.48 8.11 TD RECEIVED JUL 2 1 2000 Alaska O.;-i & Anchorage ARCO ALASKA, INC. SSSVNIP Tubing Casing Casing Gas Lift MandrelNalve 1 Gas Lift MandrellValve 2 Liner Gas Lift MandrelNalve 3 PKR 9200' MIN ID = 3.813" (4-1/2" HES X Nip) NIP TTL Perf Perf Perf IBP Perf Perf Perf FISH JUL 2 1 2000 0[4 & Gas C0r~s. Commission Anchorage APl: 500292265100 SSSV Type: Annular Fluid: 6.8 Diasei/8.5 Reference Log: Last Tag: 10128 Last Tag Date: 7/10/98 Depth Annotations Depth Comment Prudhoe Bay Well Type: PROD Orig Compltn: 4/7/96 Last WlO: 4/7/96 Ref Log Date: 1/1/60 'iD: 12299 flKB Max Hole 95 deg ~ 12299 Angle: 9200 9200' MIN ID = 3.813" (4-1/2" HES X Nip) General Notes Date Note GLM'S HAVE LOWER PSI RATE THAN NORMAL CK WIACE/FE 4/7/96 TTL ELM ~ 0: ELM Tubing Tail (Not Logged) Other (plugs, equip., etc.) - JEWELRY Depth TVD Type Description 2223 2180 SSSVNIP 4-1/2" HES HXO SVLN SSSV Nipple 9177 8071 PKR 7" x 4-1/2" Baker S-3 Packer 9200 8090 NiP 4-1/2" HES X Nipple 9212 8099 TTL 4-1/2" Tubing Tail W/L Re-entry Guide 11400 8820 IBP CTM; CIBP (Set for Mechanical GSO) Fish - FISH Depth Description 12294 FISH Casing Strings. All Size Weight Grade Top Btm 9.625 40.00 *L-80 0 3667 7.000 26.00 L-80 0 9355 4.500 12.60 L-80 5062 12299 Tubing Strings -All Size Weight Grade Top Btm 4.500 12.60 L-80 0 9212 Gas Lift Mandrels/VaNes Stn MD TVD Man Man vMfr Mfr Type I 3791 3691 Camco ;BG2LSMOI CAMCO GLV 1.0 2 6931 6301 Camco :BG2LSMOI CAMCO GLV 1.0 3 9108 8017 Camco ;BG2LSMOiCAMCO GLV 1.0 1. CA vlv ran in this rnandral requires modified latch 2. CA vlv ran in this mandrel requires modified latch 3. CA vlv ran in this mandrel requires modified latch Perforations Interval TVD Zone 10550-10996 8811 -.8810 ZONE lB 11045-11190 8811 -8818 ZONE lB 11238- 11335 8820-8819 ZONE lB 11440 - 11670 8821 - 8822 ZONE lB 11700-11816 8822- 8821 ZONE lB 11900-12053 8818-8816 ZONE lB 5-49 Comment 112 of split dng off 4-1/2" SSSV 5-3/4"x1/4" Feet DescriptiOn 3667 Casing 9355 Casing 7237 Liner Feet Description 9212 Tubing V Type V OD Latch Port TRO Angle @ TS: 33 dag ~ 9496 Angle @ TD: 95 deg ~112299 Rev Reason: TAG/Visual Last Update: 6/20/99 ID 3.813 0.000 3.813 0.000 0.001 Date 6/21/97 Date Vlv Run Commenl INT 0.250 2505 4/14/96 (1) INT 0.250 2242 4/14196 (2) INT 0.313 0 4/14/96 (3) Status FeetsPF Date Type Comment O 446 4 4/3/96 IPERF O 145 4 4/3/96 IPERF O 97 4 4/3196 IPERF O 230 4 413/96 IPERF O 116 4 413196 IPERF O 153 4 4/3196 IPERF Drilling Wellhead Detail '~ CT Injector Head Methanol Injection Otis 7' WLA Quick Connect----- -i ! Alignment Guide Flange ~, ,~_0.~5") 7-1/16", 5M Ram Type Dual J=l--Li ... ~ GateBOPE ~ P ' (~ ~ Flanged Fire Resistant aan~ " ~ Kelly Hose to Dual HCR Choke Manifold ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure - Annular BOP5000(Hydril),7-1/16"psi WP ID Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16', 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline toStandpipe manifold Upper Annulus Lower Annulus · . RECEIVED · JUL 2 1 2000 A~aska Oki & ~'as ~o~,ls, L;omrnission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 17, 2000 Dan Seamount & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Prudhoe-EOA, Pt. Mac, & Lisburne Well Work This listing is provided as required under the terms of Conservation Order No. 341 (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for July 17- 24, 2000: Well Work Planned 06-21A 15-12A 15-27 CT SIDETRACK (NABORS CDR) CT SIDETRACK (NABOR 3S) CT PACKER CEMENT RESQUEEZE 15-37A 15-42A GNI-02 CT SIDETRACK (NABORS CDR) CT SIDETRACK (NABOR 3S) PERFORATION If additional data or scheduling information is needed, please call me at 263-4990 or E-mail me at prauf@ ppco.com. Engineering Aide EOA Wells Group Part of the BP Amoco Group RECEIVED JUL 2 1 2.000 A~aska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · . _ - .~asl~a 0i~ a Gas Cons. N~0rage 1. Type of request: Abandon_X Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 603' FNL~ 5162' FEL, Sec. 22, T11N, R14E, UM At top of productive interval 191' FNL, 1165' FEL, Sec. 22, T11N, R14E, UM At effective depth At total depth 772' FNL, 3975' FEL, Sec. 23, T11N, R14E, UM 5. Type of Well: Development __X Exploratory _ Stratigraphic _ (asp's 676031, 5960879) (asp's 680019, 5961389) (asp's 682503, 5960864) 6. Datum elevation (DF or KB feet) RKB 67.3 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 15-49 9. Permit number / approval number 196-034 10. APl number 50-029-22651 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12299 feet Plugs (measured) Tagged PBTD @ 10218' MD on 6/09/1 999. true vertical 8799 feet ClBP @ 11400' MD. Effective depth: measured 10218 feet Junk (measured) true vertical 8794 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 260 sx AS 110' 110' Surface 3600' 9-5/8' lO3O Sx cs III, 305 sx Class G, 3667' 3572' &345 SxCS II Production 9288' 7" 200 Sx Class G 9355' 8213' Liner 7237' 4-1/2" 325 SX Class G 12299' 8799' Perforation depth: measured 10233' - 110365'; 10395' - 10520'; 10550' - 10996'; 11045' - 11190'; 11238' - 11335'; 11440"- 11670'; 11700'- 11816'; 11900'- 12053'. true vertical 8797' - 8810'; 8809' - 8811'; 8811' - 8810'; 8811' - 8818'; 8820' - 8819'; 8821' - 8822,; 8822' - 8821'; 8818' - 8816'. Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-8O Tbg O 921Z MD. ORIGINAL Packers & SSSV (type & measured depth) 7" X 4-1/2" BAKER S-3 PACKER @ 9177' MD. 4-1/2' HES HXO SVLN SSSV ~ 2223' MD. 13. Attachments Description summary of proposal _~X Detailed operations program __ BOP sketch __X 15. Status of well classification as: 14. Estimated date for commencing operation July 26, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __X Service 17. I hereby certify that ~ing is true and correct to the best of my knowledge. 1'"1oo S ~ Dan Kara {,/ Gas __ Suspended __ Questions?Call Dan Kart @ 263-~t837. Title: Coil Tubing Drilling Engineer FOR COMMISSION USE ONLY Date Prepared by Paul Rauf 263-4990 Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance __. Mechanical Integrity Test __ Subsequent form required 10- Approval no. ..... _Approved bY order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 108 82-40/I 021 LLARS ' OVER $1000 ,',O4, ? 5000 WELL PERMIT CHECKLIST COMPANY /¢~)o WELL NAME/C~d(/5"--~ROGRAM: exp ... FIELD & POOL ADMINISTRATION 1. ENGINEERING INITCLASS z~ x]-~,// Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and.number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet:regulation ................ 26. BOPE press rating appropriate; test to ~ Dsig. 27. Choke manifold complies w/APl RP~53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOL AREA N N N N N N N N :N N N N N dev ~ redrll ~ serv wellbore seg · ~r ,,,~.~:::3 UNIT#, ann. disposal para req ON/OFF SHORE GEOLOGY , 30. Permit can be issued wlo hydrogen sulfide measures ..... Y /~ ~' 31. Data presented on potential overpressure zones ....... ,~~ ~~. 32. Seismic analysis of shallow gas zones .......... . ".. II A~PR D~AIEj 33. seabed cOndition survey (ifoff-shore)... .......... ' J~'~"~ ~./~.~./~ 34. Contactnameiphoneforweeklyprogressreports[exploratoryonl~NN '" , APPR DATE (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and . IE) will not c!.rcumvent 20 AAC 25.252 or 20 AAC 25.412. ENGINEERING: U!g.[A..nnular COMMISSION: Comments/Instructions: c:~nsoffiCe\wordian\diana\checklist (rev. 02/17100) I§ -i ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well PerTTlitting 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 APPEN.DIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 02/01/30 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** ~ ~ 02/01/25 71888 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: glen.las ~Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame ~Well Information Block #MNEM.UNIT Data Type Information STRT.FT 9767.0000: Starting Depth STOP.FT 9913.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP AMOCO WELL. WELL: 15-49APB1 FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 603' FNL, 5162' FEL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray DATE. LOG DATE: 23-Aug-00 API. API NYUMBER: 500292265171 ~Parameter Information Block #MNEM.UNIT Value Description SECT. 22 : Section TOWN.N liN : Township RANG. 14E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 67 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 67 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 ~Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 15-49APB1 was kicked off @ 9770' MD (8492' SSTVD) from the wellbore of Well 15-49. (5) Well 15-49APB1 was drilled to TD @ 9913' MD (8603' SSTVD) on Run 2. (6) The interval from 9889' MD (8586' SSTVD) to 9913' MD (8603' SSTVD) was not logged due to sensor to bit offset. (7) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BPX (SWS, 30/08/00). (8) A Magnetic Declination correction of 26.96 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour SSTVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 1 22.83 ft. 28.47 ft. 2 22.83 ft. 28.74 ft. CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9776 07 9781 58 9786 11 9787 68 9791 02 9792 60 9800.26 9801.83 9815.78 981.8 54 9829 16 9831 52 9844 31 9850 02 9854 41, 9857 95, 9867 20, 9870 15, 9874.82, EOZ END 9770. 9775 9780 9782 9785 9787 9790 9793 9815 9819 9830 9832 9847. 9852. 9855. 9859. 9866. 9871. 9876. 36 28 6O 76 12 29 81 76 19 13 34 12 27 58 00 92 41 13 00, -5.70703 -6.29688 -5.50977 -4 91895 -5 90234 -5 3125 -9 44531 -8 06738 -0 589844 0.59082 1 18066 0 59082 2 95215 2 55762 0 59082 1 96777 -0.787109 0.983398 1.18066 BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: t 85 records... Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MI~EM VALU WDFN mwd.xtf LCC 150 CN BP AMOCO WN 15-49APB1 FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 30-Aug-00. *** INFORMATION TABLE: CIFO ~INEM CHAN DIMT CNAM GR GR GRAXll ROP ROP ROPSll ODEP .................. 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 API 2 ROP MWD 68 1 F/HR Size 4 4 Total Data Records: 4 Tape File Start Depth = 9767.000000 Tape File End Depth = 9913.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 13 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 Length 4 4 8 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd. x t f LCC CN WN FN COUN STAT 150 BP AMOCO 15-49APB1 Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX ROPS ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per'frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool 1 GRAX MWD 2 ROPS MWD Code Samples Units Size 68 1 API 4 68 1 F/HR 4 Length 4 4 8 Total Data Records: 4 Tape File Start Depth = 9767.000000 Tape File End Depth = 9913.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 13 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/01/25 71888 01 **** REEL TRAILER **** MWD 02/01/30 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR 9767.0000 -814.9540 9767.5000 29.6282 9800.0000 27.3860 9900.0000 -999.2500 9913.0000 -999.2500 2 records... 132 bytes 132 bytes ROP -999.2500 -999.2500 76.3886 16.5427 1.6518 Tape File Start Depth = 9767.000000 Tape File End Depth = 9913.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 9767.0000 -999.2500 -999.2500 9767.5000 -999.2500 -999.2500 9800.0000 30.3800 78.2190 9900.0000 -999.2500 18.1710 9913.0000 -999.2500 -999.2500 Tape File Start Depth = 9767.000000 Tape File End Depth = 9913.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS **** REEL HEADER **** MWD 01/06/19 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/06/19 71888 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: glen.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block ~MNEM.UNIT Data Type STRT.FT 9760.0000: STOP.FT 11735.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NYUMBER: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value BP AMOCO 15-49A Prudhoe Bay Unit 603' FNL, 5162' FEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 29-Aug-00 500292265101 ~Parameter Information Block #MNEM.UNIT Value SECT. TOWN.N RANG. PDAT EPD F LMF FAPD F DMF EKB F EDF F EGL F CASE F OS1 ~Remarks Description 22 : Section liN : Township 14E : Range MSL : Permanent Datum 0 : Elevation Of Perm. Datum RKB : Log Measured from 67 : Feet Above Perm. Datum KB : Drilling Measured From 67 : Elevation of Kelly Bushing N/A : Elevation of Derrick Floor N/A : Elevation of Ground Level N/A : Casing Depth DIRECTIONAL : Other Services Line 1 (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 15-49A was kicked off from the wellbore of 15-49 through a window in 4-1/2" liner at 9771' MD (8492' SSTVD). (5) Well 15-49A was drilled to TD @ 11736' MD (8704' SSTVD). (6) The interval from 11709' MD (8705' SSTVD) to 11736' MD (8704' SSTVD) was not logged due to sensor to bit offset. (7) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BPXA (SWS, 31-Aug-2000). (8) A Magnetic Declination correction of 26.96 degrees has been applied to the Directional Surveys° 113 MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth (SSTVD), feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 1 22.83 ft. 28.47 ft 2 22.83 ft. 28.47 ft 3 24.51 ft. 30.15 ft 4 24.57 ft. 30.21 ft 5 24.57 ft. 30.21 ft 6 24.57 ft. 30.21 ft CURVE SHIFT DATA BASELINE, MEASURED, 9569 74, 9575 22, 9590 67, 9592 82, 9596 15, 9610 23, 9775 98, 9781 46, 9791 43, 9792 21, 9797 89, 9808 25, 9818 43, 9829 16, 9844 41, 9854 19, 9866 52, 9870 63, 9886 61, 9889.74, 9901.67, 9921.04, 9923.78, 9931.80, 9937.08, 9942.29, 9949.91, 9991.85, 9996.35, 10005.5, 10018.7, 10033.2, 10046.9, 10054.7, 10056.7, 10063.3, 10068.1, 10091.8, 10098.0, 10107.0, 10125.8, 10154.0, 10166.7, 10173.8, 10187.5, 10191.6, 10200.0, 10227.3, 10237.1, 10239.7, 10243.4, 10258.0, 10269.5, 10272.2, 9562 11, 9567 39, 9582 85, 9585 59, 9588 72, 9601 63, 9770 31, 9775 59, 9785 17, 9787 13, 9789.08, 9809.43, 9818.82, 9828.37, 9847.35, 9854.78, 9866.13, 9870 23, 9887 39, 9891 31, 9903 44, 9922 61, 9925 74, 9933 95, 9938 65, 9944 83, 9950 89, 9994 00, 10000.5, 10007.5, 10020.5, 10035.0, 10048.5, 10057.1, 10058.5, 10064.9, 10070.6, 10095.4, 10101.7, 10109.9, 10125.2, 10155.8, 10168.5, 10174.5, 10189.9, 10193.8, 10201.8, 10231.1, 10240.3, 10242.4, 10246.1, 10261.1, 10272.6, 10274.6, DISPLACEMENT -7.62988 -7.82422 -7.82422 -7.2373 -7.43359 -8.60645 -5.67285 -5.86816 -6.25977 -5.08594 -8.80371 1.17383 0.391602 -0.783203 2.93457 0.586914 -0.390625 -0.391602 0 782227 1 56445 1 76074 1 56445 1 95605 2 15137 1 56543 2 54297 0 977539 2 15137 4 1084 1 95605 1 76074 1 76074 1 56445 2 34766 1 75977 1 56543 2 54297 3 52051 3 7168 2 93457 -0.586914 1 76074 1 75977 0 782227 2 34766 2 15137 1 76074 3 7168 3 12988 2 73926 2 73926 3 12988 3 12988 2 34668 10274.2, 10277.9, 10313.6, 10317.3, 10323.6, 10327.1, 10332.2, 10337.7, 10366.2, 10369.9, 10446.0, 10445.8, 10472.0, 10474.4, 10555.3, 10556.5, 10560.4, 10563.6, 10575.4, 10576.6, 10600.1, 10598.9, 10631 3, 10629.7, 10633 4, 10632 4, 10680 5, 10682 10691 5, 10691 10701 4, 10703 10709 5, 10711 10716 9, 10715 10763.2, 10766 10771.7, 10771 10779.7, 10781 10785.9, 10788 10794.1, 10794 10809.2, 10818 10814.2, 10824 10819 7, 10830 10841 10846 10855 10864 10892 10906 10930 10950 10956 4, 10844 3, 10847 5, 10855 7, 10863 3, 10891 4, 10906 8, 10932 0, 10952 8, 10960 51 1, 8, 0, 9, 0, 9, 8, 5, 1, 5, 2, 5, 8, 3, 1, 9, 5, 0, 2, 4, 3, 11004.2, 11008.3, 11018.1, 11020.0, 11022.0, 11024.1, 11026.3, 11028.5, 11037.9, 11041.6, 11055.6, 11056.2, 11067.9, 11070.7, 11077.7, 11080.4, 11084.0, 11087.9, 11129.1, 11124.6, 11136°9, 11135.9, 11144.1, 11146.9, 11151.6, 11154.9, 11168.2, 11171.7, 11225.0, 11228.9, 11247.5, 11252.0, 11255 0, 11259.5, 5, 11268.6, 9, 11285.4, 0, 11307.5, 9, 11318.4, 6, 11338.0, 0, 11466.0, 3, 11476.7, 8, 11509.1, 9, 11520.6, 1, 11544.0, 1, 11629.3, 11267 11279 11304 11313 11335 11466 11477 11505 11519 11540 11630 EOZ END 3.7168 3.7168 3.52051 5.47754 3.7168 -0.196289 2.34766 1.17383 3.12988 1.17383 -1.17383 -1.56543 -0.977539 1.95605 -0.390625 2.34766 1.56543 -0.978516 2.73926 0.196289 2.15234 2.54297 0 9.38965 9.97656 10.7588 3.32617 0.978516 -0.391602 -0.782227 -0.782227 -0.390625 1 36914 2 34766 3 52051 4 1084 1 95703 2 15137 2 15234 3.71582 0.586914 2.73926 2.73926 3.91211 -4.49902 -0.978516 2.73828 3 32617 3 52148 3 91211 4 49902 4 49902 1 17383 5 47754 3 52148 4 49902 2 34668 0 -0.586914 3.32617 0.782227 3.91211 -0.783203 ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 192 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP AMOCO WN 15-49A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 31-Aug-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAX10 0.0 2 ROP ROPS10 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GR MWD 68 1 API 4 2 ROP MWD 68 1 F/HR 4 Total Data Records: 48 Length 4 4 8 Tape File Start Depth = 9760.000000 Tape File End Depth = 11735.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 57 records... Minimum record length: Maximum record length: 42 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP AMOCO WN 15-49A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0.0 * FORMAT RECORD (TYPE% 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 API 4 2 ROPS MWD 68 1 F/HR 4 Total Data Records: 48 Tape File Start Depth = 9760.000000 Tape File End Depth = 11735.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 57 records... Minimum record length: Maximum record length: 42 bytes 4124 bytes **** TAPE TRAILER **** MWD 01/06/19 71888 01 **** REEL TRAILER **** MWD 01/06/19 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH 9760 0000 9760 5000 9800 0000 9900 0000 10000 0000 10100 0000 10200.0000 10300.0000 10400.0000 10500.0000 10600.0000 10700.0000 10800.0000 10900.0000 11000.0000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11735.0000 GR 23.8744 24.2785 25.3600 21.8680 46.8750 44.2242 59.6565 57.5570 73.7421 40.7810 73.8091 68.6895 73.2683 116.0683 42.2578 71 0095 55 6151 40 7015 30 1689 33 1154 37 3265 38 1804 -999.2500 2 records... 132 bytes 132 bytes ROP -999.2500 -999.2500 77.3124 80.4985 78.6081 57.1183 47.1569 84.3483 74.5283 130.2690 102.6033 104.2885 121.1635 28 6954 77 9031 57 5512 28 4733 8 1535 71 7945 123,9149 62.5688 78.4790 -999.2500 Tape File Start Depth = 9760.000000 Tape File End Depth = 11735.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet [] Tape Subfile 3 is type: LIS DEPTH 9760.0000 9760.5000 9800.0000 9900.0000 10000.0000 10100.0000 10200.0000 10300 0000 10400 0000 10500 0000 10600 0000 10700 0000 10800 0000 10900 0000 11000 0000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11735.0000 GRAX ROPS -999.2500 -999.2500 -999.2500 -999.2500 32.3820 78.4790 26.0940 86.5280 34.0620 73.8190 37.7340 53.6880 58.3590 41.5880 41.6150 97.3550 72.1480 37.7900 45.2350 124.3270 56.1720 104.4430 62.5790 49.9350 66.7540 31.4060 92.6170 54.3150 34.2190 78.4500 72.6370 58.0320 59.7660 18.3980 39.8680 27.1260 30.6250 85.6680 35.2350 122.2450 36.4850 42.9250 38.0080 75.7120 -999.2500 88.1420 Tape File Start Depth = 9760.000000 Tape File End Depth = 11735.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS
