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Home My WebLink About196-046 e e bp o BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 17, 2005 Winton Aubert Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RECE, NOV 2 2 2005 A\aska Oil & Gas Gons, RE: Application for conversion to injection service: DS 9-31 C Anchorage Dear Mr Aubert: Enclosed is an Application for Sundry Approval to convert DS producer 9-31 C to injection service. The following supporting documentation is included for your review: · Application for Sundry Approval · Map showing wells within ~ mile radius · Cement bond log (SCMT) · Wellbore schematic · Conversion procedure Please do not hesitate to call if you require additional information. S¡1 Victoria Imeh East Waterflood Production Engineer 564-5233 09-31 C Conversion Map ò e e . ",.-'.. "--.' ,- '" .. . > "..., -' - " " .' ~ -"-'-'- '~.~, ~.~ -:;.~; ~ .", .'.", -'~ '.;.~ .. '~'.;- ">_-', :<,>::::<:~ c·-,~~·_· ':. .:_-~~ ~'~,"': :-'<:- ",':,'" ", ,- ::::':' ,:~:~,·,~:t·,~~;"&;;'!J:'~,\- \....:~<:- ':. '":.' ....,' '," ..,"-,,,~,,,,~.';i,g.. '.' . ~''''':.:.c%$«-~__~'_I:;_'.. '·'\·Å~:-'~~'~'-_'.,~ ~:.:::..:~:.':~'..".. ''''.~.. 'w._~.~:~.",,:'" . ,",;', )::~'.:'( '_:~_'''''':''Þ'I '·.i....' .~.:.~ :~I·~:.': ..' ~~. '~:¡I:" . '",:~' ." .......... .. ... ~';.:'.~.:, ~~:'..::-:. :-:..~~,~ :... ~':~. '. . . . .. . . . . . ..,. .. ..(-....¿.~--- . - . _./.H.._C..... __-,¿,_,~·O";'C;".,:,;.·_·_· e '......'.....~..~ .J>, '..~. ~ ,.. - --. ......."'~~'k'1f Schlumberger Company: BP EXPLORATION (ALASKA) INC. Well: Field: Borough: !: ~ S ..J $ ~ z UJ >- ã> 0 a. ~ m ~ gUJcð~OZ wocðC'>..Jo J::r:u.cn~~ b:§fõ~UJ~ ~Œ~ci~9 .ë c:: ~ g> .;.; g ~ e .... cu E o<üOQjo (Q ü: S ~ 0 Lo in Date Run Number Depth Driller Schlumberger Depth Bottom Lo Interval Top Log Interval Casing Fluid Type Salinit Densit Fluid Level BIT/CASlNG/TUBING STRING Bit Size From To Casin /Tubin Size Wei ht Grade From To Maximum Recorded Temperatures Logger On Bottom Time Unit Number Location Recorded B Witnessed ',- ..,.'.:..~/."",.;~;- '''--.' '. '. . D.S. 09-31':"" PRUDHOE BAY NORTH SLOPE State: ."., ."". ".". SLIM CEMENT MAPPING TOOL W/GRADIO MEASUREMENT 05-NOV-2005 1567' FSL & 998' FEL Permanent Datum: Log Measured From: Drilling Measured From: MSL RKB RKB ALASKA Elev.: K.B. 55 ft G.L. 22 ft D.F. 54 ft Elev.: 0 ft 55.0 ft above Perm. Datum . - API Serial No. 50-029-21396-03 5-Nov-2005 ONE 9170 ft 9162 ft 9162 ft 8760 ft 1 % KCL Section 2 Township Range 10N 15E .-". ,-.,..-,~.-~,--:;---.--...,-.......,."-.~-,..-...."',, . _.~ ~:'" .. '.'.".' ,. .. ,. ',' .. .".'..,.. '~". 8.7 Ibm/ al 20:25 '-l . 31----...---- II ..7 :JS -----____ ': '~=.......= - r:::::::w _________ " . ì ~ --------- Hff- __, .-------- '-.."'.. ~ .________ ,,)';1j";:- _. !IIIIIIII< n III r~~~í>lit~:rl~ ~ .________ .. ~.... I If1 ==-==C:;;TlME f { 1_· ,. a________·0 "J ... ..rï..:...______ .~. , ~ ~,.JI QiüI....::.....-------.' ~. h l/~. ~;r: . I' PF4f11W!!"'IftIllIl=== .~..~. ('J,Ii l'1lU~~~-' .. ~·4IIíii¡i~iIi--"_III!!~ - - l~I.,.J___ _" :~r .: ....4a:..1:5"'!.:¡~____; Ib\n'Ll ~lJ):-~ ~_ ~¡~~,. · .....=EFJ =E!¡~i=¡æ~I···0 . ~IIA Ill' .~~'~1i p;,"J;' ... ... .-.,... 1...:411___[._ -..~__Iò:!___7.1, J ,. .,.' _I FP-......'ÎI=..==!] ===.=I!=.II~~ ,j;. . :-~''''-¡i'~' -~ ¡¡~Ìi~J-----Illii¡¡¡; _.~._Ðl__~~_ .... _ i .. .Ill d,~L-, :..~~,~ i.' -~. 104 MV IN FREE PIPE (1HEORmCAL~1~ : ~¡ ..¡; ~ ~ I rl' PtlJJ{P¡', ~:--.. J L IW"'¡li~i ~î ~!-~.,.~ J~~ .. '. 'oJ - ; }tl ~ .I~_-=- t - ~ ~ mU1 i}" -1f t~ ~ <_._~~ ...; ~.;:' ~~ ~ ~ ;: .{. ~:j .~~ - ~ <, (~ R I~ "'~~_. - _ '- '" U;# f ~ . .'___' ... . ~ ~ -., ·~~·<f,,~j::tt~? ~ .." -I, . ~ -- -- · · · · · · · I -~ " - : _i- : · · I · I · · · I I '" ..~ , ... .... ~- '" ~ ".I I , , 11I_ ..... ....- - ..... 8~ ;;[J ~ · · Î .... ..,., - -:;... · · · I -- . --; · · · , · .. ""- ~:c. c" . .. ~ ~ - ~!-- I.... t""" ;J .... - - \ - " ~ "I .~ - 8900 t- - · · ;;ii'" .F · -- · ...... · · I!"': , .-:. · , , . , , - - \ . ~- .,- ~- ..... ... ~p. ...... "I Pl~f ......... - .... ~ · < · · " <: ~ - ~ I.... - .. .- II', I~:<. I ..~ m~ ~-, L w g¡ . I ~ f I : i t I~ '. ~ !. L '. ~ .~ . : . -~ I....... "" I ': ÞO:j..______ "-- 7 .~.: . ~..:.:,. : .... ..& ~ ... I.:MI- ./ 1'':;,,< C :'2 . ~ 'i:, . I. . iE' r ~ : CYCLE SKIPPING IN HloHLV ATTENUATlVE CEMENT ... ...... .¡;.:':':' ,:.::: i·.::: ~::::: r ~,..~ ...... . ". ': ,.. I' ,.. J ( - <. \:':.: ,:.:. ''¡:::>' .,:. :;-. ... ...... 1 ....~ '\ ... I - ..... · I · , /- · ~~ \ · \ I i · 1,( 1\ "" · \) · · - ... ..... · I · · "> · · · · t"::·: 1:-. jio,:. ~:: I\~: I] : , I'I':",L,:· .'.:«.;to' .'o'....I. ..............., '·:~:E~:J , . ,..,..... - 4;-~~ .. bp ,\"fI. ~~ ~~. }I''' -'It ''''~J- "'.." e e To: J. Bixby/D. Cismoski Date: October 10, 2005 GPB Well Ops Team leaders PECT: PBD09WL31-M From: Vickie Imeh Production Engineer lOR: 300 Subject: 9-31C - Conversion to Injection Est. Cost: $1.75M 1 S Dummy GL Vs 2 F AOGCC to witness MIT-IA to 2500 psi Current Status: Max Deviation: Min.ID: Last TD Tag: Last Downhole OP: Latest H2S Value: L TSI, Converting to injection 96 degrees @ 9694' md 2.387" LNR XO @ 8822' md 04/29/1996 11/24/2001 - Additional perfs 189 ppm - 7/18/2003 Well 9-31 was initially drilled in May 1986, and sidetracked both in April 1993 and April 1996. It had been completed with 2-7/8" cemented liner for use as a horizontal MIST injector. Water was injected between bulbs of MI at rates of 10 MBWD. It was then converted to a producer in October 2001. Well 9-31 did not flow oil until additional perforations were shot in Zone 4. Unfortunately, production quickly fell below 100 BOPD. It was finally shut-in for high water cut and low oil production in August 2003. 9-31 C is currently being converted to a water injector pending completion of surface conversion. It is hoped that the actual surface conversion will be completed by 4Q of this year. This program requests well preparation and MITIA to confirm integrity in inner annulus. 9-31 is ready for injection as soon as the IA test is completed, and appropriate state approval has been obtained. Contacts Victoria Imeh Office 564-5233 Home 748-4961 Cell 748-4961 cc: w/a: Well File Victoria Imeh TREE = 5-1/8" McEVOY SAFETY NOTES: 4-1/2" TBG & 7" lNR W8...LI-EAD = McEVOY 09-31C ARE 13 CtROME WEll ANGLE >700@ A GruA TOR = A X 8... SON 9210' & > 90° @ 9600'. KB. ElEV = 55.0' BF. ElEV = 23.0' ~ I 34' H 5-1 {2" TBG, 17#, l-80, .0232 bpf, ID = 4.892" 1 KOP= 4400' '- Max Angle = 96 @ 9694' -- ---; 37' -f5-1{2"X4-1/2"XO,ID-3.958" I DatumMD- 9521' DatumTVD = 8800' SS . I 2096' 4-1{2" CA'-'COTRCF-4A 1RSSSV, ID=3.812" 1 GAS LIFT MClNIR8...S 113-318" CSG, 72#, l-80/K-55, ID = 12.347" 1 2533' ~ . ST MD lVD DEV TYPE VlV lA TCH POR Dð.TE 1 3193 3193 0 TGPD OOf'Æ RK 16 10/24/01 Minimum ID = 2.387" @ 8822' I l 2 4802 4786 18 TGPD S/O RK 20 1 0/24/0 1 3-1/2" X 2-7/8" LNR XO 3 5605 5535 23 TGPD DV RK 0 03131/96 4 6178 6063 23 TGPD DV RK 0 05123/95 ITOPOFBKR G-21lESACKSlV, ID = 7.50" 1- 8234' 5 6704 6548 23 TGPD DV RK 0 03131/96 6 7236 7038 22 TGPD DV RK 0 04/22/93 9-518" X T' BKR LNR PKR, ID = 6.190" - 8241' I ~ ~ 7 7765 7530 21 TGPD DV RK 0 04/22/93 19-518" X T' BKR LNRHGR, ID=6.190" 1- 8246' ,....-- 8 8059 7807 19 TGPD DV RK 0 04/22/93 9 8202 7942 18 TGPD DV RK 0 05123/95 19-518" CSG, 47#, l-80, ID = 8.681" H 8400' LJ I 9-5/8" CSG MlllOUT WIt'ÐOW I 8757' 4-1f2." SWS NIP, ID = 3.813" 1 8400' - 8450' (SECTION Mll) I ~ 8774' T' x 4-1/2" BKR SABl-3 PKR, ID - 3.875" 1 14-112" BKR DEA..OYMENT SlEBIE, ID = 3.00" I 8816' I 13-1/2" X 2-7/8" ll\R XO, ID = 2.387" 8822' I I 8832' 1-14-1f2." f'NIIS NIP, ID= 3.813" (BEHlNDll\R) 1 4-1/2"TTP, 12.6#, 13-ffi, .0152 bpf, D =3,958" 1 8842' I I 8843' J-14-1f2." WLEG (BEHIND ll\R) I I 1 8850' H 8...rvÐ TT lOGGED 07/08/94 1 ÆRFORA TON SUM\1ARY REF lOG: SPERRY-SU'J fvWD lOG ON 04/27/96 ~ Mill OUT WIt'ÐOW (9-31C) ANGlE AT TOP PERF: 30 @ 8972' ~ ,\ ~~ o - 9066' (OFF CMTRAMP) No1e: Refer to Production DB for historical perf data ~O SIZE SPF INTERV Al Opn/Sqz DATE 9170' 1~2-7/8" CBP(SEr 10/16/01) I 2" 6 <'8972 - 8982 0 11/24/01 2" 6 8987 - 8999 0 11/24/01 9390'elm 1--J2-7/8" aBP(SEr07/25100) I 2" 6 9094 - 9104 ' 0 10/16/01 2-1/8" 4 9206 - 9226 C 10/16/01 9489' LJ2-7/8" CIBP(SET05l28/98) I 2-1/8" 4 9236 - 9254 C 10/16/01 2" 4 9267 - 9287 C 10/16/01 2-1/8" 4 9710- 9785 C 05128/98 10000'ctm 2-7/8" CTMaBP(SEr 02104/97) I 2-1/8" 4 10250 - 10325 C 02104/97 .-I10531'elmH2-7/8" CIBP (SET 10/12/96) I 2-1/8" 4 10775-10875 C 10/12196 10600' ASH -2-1/8" CISP I (lOST 9-25-96) ,I 10882' 2-7/8" BKRlC (PBTD) 1 7"ll\R, 29#, 13-CR-80, ID = 6.184" 1 9398' I 12-7/8" lNR, 6.5#, L80,.0058 bpf, ID -2.387" 1 1 0945' DATE REV BY COIvMENTS Dð.TE REV BY COMMENTS ffiLOHOE SA Y UNIT OS/28/86 ORIGINAL COM"LErIOO 11/24/0 1 CWS/KA ~ A [PERFS WEll: 09-31C 04/21/93 RIG SIŒTRAO< (09-31A) 09102/02 BHCITP REMOVE aBP@ 9431' CTM PERIvIIT No: 1960640 04/28/96 CTD SIŒTRA 0< 09-31 C) 09109/02 BHCltlh PERF CORRECTIOOS A A No: 50-029-21396-03 12/22/00 SIS-SlT CONVERTED TO CANVAS SEC2, T10N, R15E158T FSl & 988' FWl 01/22/01 SIS-lG REVIS 100 11/24/01 CH'TP CORRECTIOOS BP Exploration (Alaska) e e e e MECHANICAL INTEGRITY REPORT' ....... =PUD DA!E: tll ¿llqq& , :.ZG RELE;.S':::· 4/1 7111C¡~ OPER & FIELD ß P P f;Ju. 'W'"ELL NUH:BER oq ~ 2.:./ c.. I t¡(p - Ob4 C· 7" as~ng: TD: loq4~ Jill.. ff24' TVD; :?BTD: 10900 HD ;PZ(" TVD w; ""Jðw a .£hoe: ¡ù(f)() MD TVD i DV: MD -TV"'D ~r,.LL DATA :...:":1e~: 2· 7/K" Shoe: /Oq4f' MD :"Joi:'lg: 4- 12 " Packer &-&4 ~.. ill) 9·'/1'1 '(I" ::ole Size -It' a.nå ~." 4 ¡;12-4 TVDj ~'"'..., ff Iv HD ¡C; 2 ç- ;:VD .:. \.;.t' : TVD¡ Set at f774 Perfs ~q72 to Q¡04 :-:EC?.tu·n:c;..L INTEGRITY - PART 11 Annulus Press Test: ~p 15 m~n 30 min Cowments: ~~IT rtblM.'i'\I J \ ".- ~CH1L1qICÞ.~ INTEGRTTY - PART /2 Cement: Volumes:-. .A.mt. Linerl7,S bbls ; Csg ; DV C...t 701 to cover perfs 11. ç- .. bh/s. ç~/ (A¡~wJ- . Þ UJ-t/..tr ~.--y~ + soo' IAJ! ~()~;J ~(!;JÇ.. Theoret:ical Toe 3<;C;C; · Cement: Bond Log (Yes or No) 1 CBL E:valuation, zone a.bove perfs to ~ f~lO' Proåuction Log: Type ; In AOGCC File . v ~ v.J:t ~ch,;.t~1 f~ Mc;1:( J Evaluation í ! f ¡ .. ; j i '. CONCLUSIONS: e e Date: To: From: Subject: November 22, 2005 File /·"Y..A;) Jane Williamson ¡/ r I ~ Prudhoe Well9-3lC Conversion to Injector BP requested approval to convert PBU 9-31 C to injection service. This well was converted to production from injection service in 2001. When last produced in 2003, the well flowed at around 80 BOPD at a 99% water cut. Insufficient reserves remain to continue production. Conversion to injection service will provide pressure support to offset producers. I recommend approval of this request. 5 10 j- PRUDHOE BAY, PRUDHOE aL PBU_DS9 PRUDHOE BAY 09-31C ----------- -'_.~_._._--------_._- 10' 09-31C ---¡ _ Oil Rate (CD) (bbl/d) ! - Water Rate (CD) (bblld) ......... Gas Rate (CD) ( Mcfld ) ¡ ~ PPLPRESS (M) ¡ _ CumOiIProd(fvt)bl) ! - WaterCut(%) : _ Gas I Oil Ratio ( Mcflbbl) i 103 2 10 1 j j -- ---v 1 10 o ; 10 --+---,----,-------,---,-,.-.~- T-···~~--~-,---·T·----:-~-,------------.-~-,-------,--~-,'--, 2001 02 03 I ,--~~~ 04 Date 11/28/05 Schlumberger '_.~ ~ ---I.......,. ~b·-1'J- ~ b¡ ~¿ L... 'J NO. 3613 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth /2 ¡J ;2085 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 FI.'d, P,"dho. B.y, Mil.. PI. t~~' <:~; 1.3,;;;; Cì)mm¡~t\o¡1 .Þ]1f:.i1Qrage Well Job# LOQ Description Date BL Color CD PSI-07 40009685 OH LDWG EDIT OF MWD/LWD 10/12/03 1 PSI-07 40009685 MD VISION DENSITY 10/12/03 1 PSI-07 40009685 TVD VISION DENSITY 10/12/03 1 PSI-07 40009685 MD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 TVD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 MD VISION SERVICE 10/12/03 1 PSI-07 40009685 TVD VISION SERVICE 10/12/03 1 Z-02A 11132059 USIT 10/06/05 1 S-14A 10987547 USIT 09/13/05 1 Y-1OA 10889216 SCMT 02/21/05 1 D.S. 03-33A 10893093 SCMT 03/05/05 1 C-19B 10928633 SCMT 05/15/05 1 09-20_____~~-, 10889215 SCMT 02/18/05 1 D.S. 09-310::/ N/A SCMT /GJ/,,-(JA.. . '; 11/05/05 1 P-OôA 11076455 SCMT 07/29/05 1 2-22A 11084275 SCMT 07/10/05 1 K-20B 11075899 SCMT 07/04/05 1 D.S. 06-20 11062630 USIT 06/14/05 1 C-18A 10621788 SCMT 06/06/04 1 P1-07A 10621778 SCMT 04/21/04 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ;::veBde:~~, ~ ~.' . â '~ - "':::. '-- ~ÇANNED DEC 1 6 2005 Date Delivered: II 1.fìC:~ \ 06 ,- . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 196-046 302-167 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20692-01 4. Location of well at surface ,~ ~ ~ 9. Unit or Lease Name 21At 00'topSNL,of productive1692' WEL,intervaiSEC. 23, T11 N, R13E, UM~ {~""~'"'""-~.~ Prudhoe Bay Unit 4138' SNL, 4518' WEL, SEC. 23, T11N, R13E, UM At total depth ~. 10. Well Number 3420' SNL, 454' WEL, SEC. 22, T11N, R13E, UM ......... [ D-17A , 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 78.93' ADL 028284 12. Date Spudded 05/28/1996 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband' 06/11/1996 6/7/2002 115' water depth' if OffshOre N/A MSL II 16' N°' °f C°mpleti°ns Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11333 9015 FTI 10785 8971 FTI [] Yes [] NoI N/A MDI 1900' (Approx.) 22. Type Electric or Other Logs Run 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SiZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" x 30" Insulated Conductor Surface 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2704' 17-1/2" 3588 cu ft Permafrost 9-5/8" 47# L-80 Surface 9518' 12-1/4" 303 cu ft Class 'G' 7" 26# IJ4S 9011' 9672' 8-1/2" 403 cu ft Class 'G' 2-7/8" 6.16# L-80 9030' 11333' 3-3/4" 101 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 8641' - 9045' 8926' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , DEPTH, INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8900' P&A with 17 Bbls Class 'G' 8507' Set EZSV 8403' Set Whipstock , 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. S~rn~c,~b ~,l~SZ~ ~' '"~' :i i NO core samples were taken. ~Anchora~ AU6 13 2002 ......... ~, '"~ ' ~"'~ I ~ I ~ I Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests , Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Sag River 9520' 8490' Shublik 9550' 8516' Ivishak 9640' 8595' ,' / 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble-~~ ~ Title TechnicalAssistant Date (~"'0~"~~, D- 17A 196-046 302-167 Prepared By Name/Numbec Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. ~(~~,,[~ ~G ~ ~- ~-~[~?- Form 10-407 Rev. 07-01-80 ~"~ [-~q i ~ [~;~'~ Well: D-17B Rig Accept: 06/13/02 Field: Prudhoe Bay Unit Rig Spud: 06/17/02 APl: 50-029~20692-02 Rig Release: 06/25/02 Permit: 202-111 Drilling Rig: Nabors 2ES PRE-RIG WORK 01/20/02 MITOA PASSED TO 1000 PSI, BLED TBG AND IA TO 120/80 PSI FOR CMIT TXIA PREP. REMOVE INTERNAL AND INSTALL EXTERNAL CHECK VALVE ON TBG HANGER TEST PORT. 02/01/02 BLED IA FROM 1100 PSI TO 180 PSI IN 3 HOURS 30 MINUTES - TUBING TRACKED. 03/14/02 CMIT - T X IA PASSED. 04/14/02 PPPOT-T PASSED. PPPOT-IC INCOMPLETE. 05/18/O2 CMIT-TXIA TO 3000 PSI INCONCLUSIVE. LOADED WELL WITH 68 BBLS CRUDE, PRESSURED IA 5 TIMES, LOSES 120 PSI/15 MINUTES. TUBING PRESSURE TRACKED THE lAP (PRE RWO). 05/21/02 ATTEMPTED TO EQUALIZE "XX" PLUG, FOUND DRY ASPHALTINES IN PLUG. 05/22/02 POH W/5.5 TTP. NOTIFY DSO, LEAVING WELL SI. 06/06/02 P&A, PERFS PRE RWO, PERFORM WEEKLY BOP TEST. BLEED GAS OFF IA AND FLUID PACK, 23 BBLS CRUDE. RIH WITH 2" BDN, STINGER TO TAG AT GLV # 7 AT 7160' CTD, POOH TO ADD STINGER RECONFIGURE COIL, RIH TO CIRC KILL WELL, TAKING RETURNS TO FLOWLINE OR TIGER. UNABLE TO ACHIEVE ENOUGH RATE TO KILL FROM SURFACE. TAG PBTD AT 10485' CTMD. 06/O7/02 CONTINUE CIRC KILL WELL WITH 2% KCL WATER. LAY IN 17 BBLS 15.8 PPG CLASS G CEMENT FROM 10485' CTMD. PUT APPROXIMATELY 6 BBLS BEHIND PIPE. CONTAMINATE AND CLEAN OUT TO 8900' CTD. FREEZE PROTECT WELL WITH CRUDE TO 2500'. FREEZE PROTECT FLOWLINE WITH 55 BBS CRUDE. LEAVE WELL SHUT IN, NOTIFY PAD OP. RDMO 06/08/02 RIG UP TO DRIFT & TAG, UNABLE TO CLOSE SSV, RDMO. GREASE TO FIX SSV. NOTIFY DSO OF WELL STATUS. 06/10/02 DRIFT & TAG WITH 3.80" CENT, SB TO CEMENT TOP @ 8914' SLM, RECOVERED SMALL AMOUNT CEMENT IN SAMPLE BAILER. NOTIFIED DSO, LEFT WELL S/I. 06/11/02 DID A STRING SHOT FROM 8622' TO 8632' AND THEN CHEMICAL CUT TUBING AT 8630'. 06/1 2/02 CIRC OUT WELL SCANNED G 2; 2002 BP EXPLORATION Page 1~ Operations Surnmar Report Legal Well Name: D-17 Common Well Name: D-17 Spud Date: 3/9/1982 Event Name: REENTER+COMPLETE Start: 6/13/2002 End: Contractor Name: NABORS Rig Release: 6/25/2002 Rig Name: NABORS 2ES Rig Number: Date From -To Hours Task COde NPT Phase Description of Operations 6/13/2002 09:00 - 09:30 0.50 MOB P PRE PJSM for moving the rig. 09:30 - 10:30 1.00 MOB P PRE Move shop, camp and pits from D-22B to D-17B. 10:30 - 12:00 1.50 MOB P PRE Move Rig to D-17B. 12:00 - 14:00 2.00 MOB P PRE Spot camp, pits, shop and rig. 14:00 - 15:00 1.00 RIGU P PRE RU lines and stairs. Berm around cellar and cuttings tank. 15:00 - 16:00 1.00 RIGU P PRE Inspect rig. ACCEPT RIG AT 15:00 HRS, 6-13-2002. Install secondary annular valve. 16:00 - 16:30 0.50 RIGU P PRE Pre-spud safety meeting with all personnel. 16:30 - 17:30 1.00 RIGU P PRE Pull BPV w/lubricator. (100 psi on the 5-1/2" tbg x 9-5/8" csg annulus). 17:30 - 21:00 3.50 WHSUR P SURF RU flowlines to tree and circulate out diesel freeze protect, at 3 BPM. 21:00 - 22:00 1.00 WHSUR P SURF Open well and monitor. No pressure. Blow down and RD lines. 22:00 - 22:30 0.50 WHSUR P SURF Install TWC, test from below to 1,000 psi - okay. 22:30 o 00:00 1.50 WHSUR P SURF ND tree. 6/14/2002 00:00- 03:00 3.00 WHSUR P SURF Finish ND/NU. 03:00 - 06:30 3.50 WHSUR P SURF SET TEST PLUG. TEST UPPER PIPE RAMS, AND HYD CHOKE TO 250 PSI LOW AND 3,500 PSI HIGH, FOR 5/5 MIN. TEST ANNULAR AND MANUAL KILL AND CHOKE TO 250 PSI LOW AND 3500 PSI HIGH, FOR 5/5 MIN. TEST TD, (2) TIW VALVES, DART VALVE TO 250~3,500 PSI FOR 5/5 MIN. TEST BLIND RAMS, HYD KILL AND CHOKE VALVES TO 250~3,500 PSI FOR 5/5 MIN. WITNESSING OF TEST WAIVED BY CHUCK SCHEVE OF THE AOGCC. 06:30 - 07:30 1.00 WHSUR P SURF Pull TWC with lubricator. 07:30 - 08:30 1.00 PULL P DECOMP RU casing handling equipment. Make up landing joint. 08:30 - 09:30 1.00 PULL P DECOMP Pull tubing hanger to floor with 200K (15K over). Cap off control lines and rig up spooling unit. 09:30 - 10:00 0.50 PULL P DECOMP Lay down landing joint and hanger. 10:00 - 19:30 9.50 PULL P DECOMP Pull and lay down 5-112" pup, 201 jts of 5-1/2", 17 lb/fi, L-80, BTC tubing, plus a 13.95' cutoff, 11 GLM, and SSSV. Recovered 23 clamps and 3 SSCL bands. 19:30 - 21:00 1.50 PULL P DECOMP Clear rig floor. 21:00 o 23:30 2.50 WHSUR P DECOMP PU window milling BHA. 23:30 - 00:00 0.50 WHSUR P DECOMP PU and set RTTS 2' below tubing spool. 6/15/2002 00:00 - 05:00 5.00 WHSUR P DECOMP MU pack-off running tool and screw into pack-off. Finish bleed down annulus pressure, and change out pack-offs. Plastic pack with 4 sticks and test to 5,000 psi for 10 min. - okay. 05:00 - 07:00 2.00 BOPSUF ~ DECOMP MU test assembly, set and test lower Rams to 250 / 3,500 psi for 5/5 min. Pull test plug, install WB, laydown test joint. 07:00 - 08:00 1.00 BOPSUF; ~ DECOMP MU running tool and retrieve RTTS packer. Monitor well - okay. 08:00 - 13:00 5.00 STWHIP ~ WEXIT RIH with mills making a guage run and picking up 4" DP singles needed to drill to TD. 13:00 - 14:30 1.50 STWHIP ~ WEXlT Cut and slip 100' of drill line. Service Top Drive. 14:30 - 15:00 0.50 STWHIP P WEXlT Continue to RIH and tag up on 5-1/2" tbg stub at 8,639' drillpipe depth. 15:00 - 16:30 1.50 STWHIP P WEXIT Sweep the hole at 11 BPM. UWT= 205K, DWT=165K, ROT = 185K, TQ = 5,000 fi-lb. Flow check, pump slug. 16:30 - 20:00 3.50 STWHIP P WEXIT POOH to BHA, SLM - no correction. 20:00 - 21:00 1.00 STWHIP P WEXIT Stand back BHA. 21:00 - 21:30 0.50 STWHIP P WEXlT RU wireline loggers and EZSV setting tool. 21:30 - 23:00 1.50 STWHIP P WEXlT RIH, tag tbg stump at 8,641' WL depth. Log collars, set EZSV ~1~1~1~1~.,~) ~!1~'[ Z ~ ?nr~ Printed: 6/28/2002 2:32:59PM BP EXPLORATION Page 2 OPerations Summary Report ,, Legal Well Name: D-17 Common Well Name: D-17 Spud Date: 3/9/1982 'Event Name: REENTER+COMPLETE Start: 6/13/2002 End: Contractor Name: NABORS Rig Release: 6/25/2002 Rig Name: NABORS 2ES Rig Number: Date From~To Hours. Task COde NPT Phase Description of Operations , : 6/15/2002 21:30 - 23:00 1.50 STWHIP P WEXlT 2' above collar. Top of EZSV at 8,507'. Check string weight, POOH. 23:00 - 23:30 0.50 STWHIP P WEXlT RD wireline loggers. 23:30 ~ 00:00 0.50 STWHIP P WEXIT Pressure test 9-5/8" casing to 3,000 psi for 30 min - okay. 6/16/2002 00:00 ~ 01:00 1.00 STVVHIP P WEXIT Finish casing test. Clear rig floor. 01:00 ~ 03:00 2.00 STWHIP P WEXIT Make up whipstock + milling BHA. Orient MWD. 03:00 ~ 04:30 1.50 STWHIP P WEXIT RIH to 962'. Shallow test MWD. 04:30 ~ 07:30 3.00 STWHIP P WEXIT Continue to RIH to 8,428'. Test MVVD. 07:30 ~ 08:30 1.00 STWHIP P WEXIT Orient whipstock to 84 deg RHS. Tag up on EZSV and set whipstock at 8,507'. 08:30 - 10:30 2.00 STWHIP P WEXlT Displace hole to 10.6 ppg LSND milling fluid. 10:30 ~ 17:30 7.00 STWHIP P WEXlT Mill window from 8,483' - 8,499' at 2-3 ft/hr. UWT=190K, DWT= 160K, ROT=180K, Torque = 7/9K ft-lb off/on. Continue drilling formation to 8,515'. (Recovered 120 lb of metal cuttings, and a questionable trace of cement in returns). 17:30 - 19:00 1.50 STWHIP P WEXlT Sweep hole at 10.5 BPM and 2,320 psi. Work thru the window with pumps off/on - no problems. Monitor well. 19:00 ~ 19:30 0.50 STWHIP 3 :WEXlT Pull into casing above whipstock, to 8,468'. Perform FIT to 11.5 EMW with 357 psi surface pressure. 19:30 - 22:30 3.00 STWHIP 3 WEXlT Pump slug and POOH to BHA. 22:30 - 00:00 1.50 STWHIP 3 WEXlT Stand back HWDP and LD DC. 6/17/2002 00:00 - 01:00 1.00 STWHIP ~ WEXlT LD milling BHA. (All mills were in guage). 01:00 - 01:30 0.50 STWHIP > WEXlT Clear rig floor. 01:30 - 02:30 1.00 DRILL ~ INT1 Flush BOP stack, service WB, function BOPE. 02:30 - 03:30 1.00 DRILL P INT1 MU drilling BHA, adjust motor bend to 1.5 deg. 03:30 - 04:30 1.00 DRILL N SFAL INT1 Computer failure in MWD unit, change out same. 04:30 - 05:30 1.00 DRILL P INT1 Test and orient MWD. 05:30 - 08:30 3.00 DRILL P INT1 Shallow pulse test MWD, RIH to 8,351'. 08:30 - 09:30 1.00 DRILL N DPRB INT1 Pipe plugged. Circulate plug free and continue circulating one ~ipe volume. 09:30 - 10:30 1.00 DRILL P INT1 Orient toolface to 85 deg RHS, pass thru window. 10:30 - 11:00 0.50 DRILL P INT1 Ream undergauge hole from 8,506'- 8,515'. UWT=185K, DWT=155K. 11:00 - 12:00 1.00 DRILL P INT1 Drill to 8,526'. AST=.75 hr, ART=.25 hr. 12:00 - 12:30 0.50 DRILL N RREP INT1 Engine downtime due to over heaing. (Variable spee~oler for radiator fan was malfunctioning). 12:30 - 00:00 11.50 DRILL 3 INT1 Drill ahead with 1.5 deg motor. AST- 4.5~:m,;~RT = 4 hr. 6/18/2002 00:00 - 03:00 3.00 DRILL 3 INT1 Drill ahead with 1.5 deg motor to 9~J;k33'. 03:00 - 04:00 1.00 DRILL N SFAL INT1 Failure of Sperry-Sun com~n MWD unit. Change out computers (second--out for this well). MAD pass from 9,003'-9,033~t,-'~0' per hour. 04:00 - 15:30 11.50 DRILL 3 INT1 D~, 56. AR'r= 7.2~ hr,AST= 4.15 hr. 15:30 - 16:30 1.00 DRILL P INT1 ' late HI-VIS weighted sweep at 12 BPM and 3,250 psi. ' Monitor well. 16:30 - 17:30 1.00 DRILL P POOH to inside 9-5/8" casing at 8,445'. (No overpull while ~ POOH). 17:30 - 19:00 1.50 DRILL PJ INT1 Cut and slip 75' of drilling line, service top drive. 19:00 - 19:30 0.50 DRI~,,~'~' INT1 RIH to 9,456'. No fill on bottom. (passed thru window w/o problems). 19:30 - 21:00 /,,4~0 DRILL P INT1 Circulate sweep around, circulate hole clean at 12 BPM and 2~ 3,250 psi. 3.00 DRILL ~ INT1 POOH to 2,i~.l~l,J'~lr~...,~' t~J, JJ~ 2 1 2002 6/19/20~,,,,,~ 0-0:00- 01:00 1.00 DRILL ~ INT1 POOH to BHA. Printed: 6/28/2002 2:32:59 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other ~' [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 2100' SNL, 1692' WEL, SEC. 23, T11N, R13E, UM At top of productive interval 4138' SNL, 4518' WEL, SEC. 23, T11 N, R13E, UM At effective depth 3576' SNL, 5223' WEL, SEC. 23, T11N, R13E, UM At total depth 3420' SNL, 454' WEL, SEC. 22, T11N, R13E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 78.93' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-17A 9. Permit Number 196-046 10. APl Number 50- 029-20692-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured Effective depth: Casing true vertical measured true vertical 11333 feet 9015 feet 10785 feet 8971 feet Length Plugs (measured) Junk (measured) Tagged TOC at 10785' (09/2000) Size Cemented MD Structural Conductor 110' 20" x 30" 8 cu yds Concrete 110' Surface 2704' 13-3/8" 3588 cuft Permafrost 2704' Intermediate 9518' 9-5/8" 303 cuft Class 'G' 9518' Production 661' 7" 403 cu ft Class 'G' 9011' - 9672' Liner 2303' 2-7/8" 101 cu ft Class 'G' 9030' - 11333' i 'il ..... !: .... Perforation depth: measured 10465'- 10485', 10485'- 10535', 11030'-11160' true vertical 8955' 8960', 8960' 8969', 8970' 8969' AlaSi(~ Tubing (size, grade, and measured depth) 5-1/2", 17~, L-80 to 8926'; 4-1/2", 12.6~, L-80 to 9045' Packers and SSSV (type and measured depth) 9-5/8" Baker packer at 8926'; 5-1/2" HES SSSV Nipple at 1998' TVD 110' 2704' 8488' 8062'-8624' 8078'-9015 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 14. Estimated date for commencing operation May 29, 2002 16. If proposal was verbally approved 15. Status of well classifications as: []Oil [] Gas [] Suspended Service Name of approver Date Approved Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Numbec Terrie Hubble, 564-4628 17. I hereby certify that the foregoin is true and correct to the best of my knowledge Signed Brian Robertson Title Senior Drilling Engineer Conditions of Approval: Notify Commission s.o representative m~.witness Plug integrity X BOP Test /',. Location clearance Mechanical integrity Te¢~ ~11~_ ~equired 10 Approved by order of the Commission Form 10-403 Rev. 06,15,88 Date Commissioner Date 6 Submit Ir{ Tril~h~cate To: Tom Maunder - AOGCC Date: May 21,2002 From: Phil Smith - BPXA GPB Rotary Drilling Subject: Reference: DS D-17A Application for Sundry Approval - P&A for Sidetrack Operations APl # 50-029-20692-01 / Approval is requested for the proposed P&A of PBU well D-17A. The original well, D-17, was drilled in March 1982. D-17A initially produced at 3000 BOPD at 50% watercut following a CTU sidetrack in 1996. The well declined to approximately 1000 BOPD and was shut in mid- 1999 for high GOR. A kinley was run in November of 2000 indicating extensive tubular corrosion.~ Additional perfs in a Z2C lens were considered, but the prospect of continued difficult cleanouts in combination with the severely corroded tubing and IA communication does not warrant further expense prior to repositioning the well. D-17A is targeted for a rig sidetrack to restore wellbore, annular integrity and provide a more optimum off-take point. This well will also serve as a critical long term GD/GDWFI off- take point. The D-17B sidetrack is currently scheduled for Nabors rig 2ES, beginning around June 20, 2002, after the completion of the D-22B sidetrack. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. Scope Pre-Riq Work: 1. Pull the XX plug from the sliding sleeve at 8860' MD. u,,ll~ ~1~ ~,t.'~ · ~-~'"~'~ 2. Liquid pack tubing and IA to surface. Lay cement abandonment plua Squeeze away and / or , , ~ · . dress off cement such that the top is between 8800 and 8950 MD. ~amtam annular pressure during the operation to ensure cement does not enter the annulus above the planned cut depth in the event of a near-packer tubing leak. 3. Drift the tubing as required for the chemical cutter. Tag cement top. . String shot and chemical cut the tubing at or below 8600'. Test the integrity of the cement plug and 7" casing to 3000 psi for 30 minutes. Bleed casing and annulus pressures to zero. 6. Cycle the tubing hanger Iockdown screws. Test the 9 5/8" casing packoff. . Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. D-17A Application for Sundry Ri.q 1. 2. 3. 4. 5. 6. Operations: MIRU Nabors 2ES. Circulate out freeze protection and displace well to seawater. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull 5 Y2" tubing from cut. Change out 9 5/8" casing packoff if necessary. MU window milling BHA drift down to the KOP. Change well over to milling fluid. Test casing to 3000 psi. 7. Set a bridge plug on wireline at +_8520' such as to avoid cutting a casing collar with the window mill. 8. RIH with 9 5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on bridge plug. Mill window in casing at _ 8500' MD. Perform FIT to 11.5 ppg. POOH. 9. Kick-off and drill the 8 W' section as per the directional plan to top of Sag River formation. 10. Run and cement a 7" drilling liner, displace with mud. 11. Test casing to 3000 psi. Drill out shoe and 20' of new formation, displace well to 8.5 ppg QuickDRILn mud. 12. Drill 6 1/8" production hole as per directional plan to TD well at +_10,337' MD. 13. Short trip, CBU, spot liner running pill, POH. 14. Run and cement a 4 ~", 12.6#, 13-Cr solid production liner to TD. Displace with perf pill and seawater. Set liner top packer. Circulate the well to clean seawater at the liner top, POOH. 15. Test the well (all casing strings) from the 4-1/2" landing collar to surface to 3000 psi for 30 minutes. 16. Run 4 Y2", 12.6# 13-Cr completion tying into the 4 W' liner top. 17. Set packer and test the tubing to 3000 psi and annulus to 3000 psi for 30 minutes. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 19. Freeze protect the well. 20. Rig down and move off. Post-Ri.q Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. 4. Perforate. Estimated Pre-rig Start Date: Estimated Spud Date: Phil Smith Operations Drilling Engineer 564-4897 06/01/02 06/20/02 D-17A Application for Sundry TREE = 6" CIVV ~VELLHEAD= MCEVOY A CTUA TOR= OTIS KOP = 2900' ~tum ~s= 8800' D-17A Pre I 1998' Id 5 1/2" HES DMY SSSV, ID=3.10" I 26os" I-i~ $,~" ~v Packer 13-3/8" 72#, L80, BTRS Casing Id 2704' I J5 1/2" 17.0# L-80 IPCTubing GAS LIFT MANDRELS ST MD TVD DEV TYPE SIZE LTCH COMMENTS 12 3001 2921 7° OTIS 5 1/2 RA 11 5082 4745 37° OTIS 5 1/2 RA 10 6273 5687 36° OTIS 51/2 RA 9 6427 5812 36° OTIS 5 1/2 RA 8 6991 6273 33° OTIS 5 1/2 RA 7 7146 6403 32° OTIS 5 1/2 RA 6 7541 6742 30° OTIS 5 1/2 RA 5 7697 6878 28° OTIS 5 1/2 RA 4 8021 7166 27° OTIS 5 1/2 RA 3 8168 7298 27° OTIS 5 1/2 RA 2 8598 7654 40° OTIS 5 1/2 RA 1 8748 7772 38° OTIS 5 1/2 RA Pre-rig tubing cut Id 8soo' I 15 1/2" "XA" Sliding SIv; I.D.=4.562" Id 8860' ITubing SealAssembly Id 8906' 19 5/8" Baker Packer; 4.75" I.D. Id 8926' I~o~o~" Liner I-t901~' I~o~o~-,,~"Linerl-~ 9029' I ~-~'~" ~'#,'~°,"~scs" I-! 9518' Ipre-rig CTU Cement P&A; TOC Id 8940' 9006' 9030' 9045' J~4-1/2" OTIS 'X' NIP, ID=3.813 J Jd PBR & GS Fishingneck J J--~4-1/2" 12.6#, L-80 TBG TAIL J JMilloutWindow J--J 9672' J J7" 26#, L80, BRTS Liner I-I 10483'1 J 11333' id2 7/8" FL4S Liner, 6.16#, L-80, .0058 bpf DATE REV BY COMMENTS 01/17/02 DEW Proposed Pre Rig CTU Cement P&A; Tubing cut. PRUDHOE BAY UNIT WELL: D-17A PERMIT No: 196-046 APl No: 50-029-20692-01 Sec. 22, T11 N, R13E BP Exploration (Alas ka) CANVAS UPDATE: 03/08/01 WELLHEAD= ~OY A CTUA'-i;bR~ .............. b~r~s' ~'~'"~'~"'~ 72.98' "~'~7"~'~'""~' 42.98 KOP = 8500' "~'~"~"~'~'i~"; ............... "~'i~"~b"; .................................. ~'6~'~~' Datum TVDss= 9035' I13-3/8" 72#, L80, BTRS Casing D-17 Proposed Co,.,pletion I-! 2704' 4 1/2" 12.6# 13 Cr-80 Tubing ITo,:, of'~" ?,,#, ,_-8o. E, TC-M,..ir,,,r I'-I ~350' ITop of Whip Stock Id 8500" 8518' [~ 8600' I~ 8860' I~ I Bridge Rug I Pre-rig tubing cut Id 2200' I-'[ 4 1/2"'X' Landing Nipple, ID=3.813" I 2608- I-!~ ~,~" ov Packer I GAS LIFT MANDRELS ST MD 'I'VD DEV TYPE SIZE LTCH COMMENTS 6 3000 3000 7.2° OTIS 41/2X11/2 PA, 5 3776 3750 22.0° OTIS 41/2Xll/2 RA 4 5938 5500 37.7° OTIS 41/2X1 1/2 RA 3 6562 6000 35.7° OTIS 41/2X1 1/2 RA 2 8026 7250 26.0° OTIS 41/2X1 1/2 RA 1 9200 8250 29.8° OTIS 4 1/2 X I RA 9228. I-'14.~/2,''x'N'P''D=3.813'' I I 9253' Id7"x41/2" Baker S-3 Packer I I9278' I-I"-''~'''x'"'",'~:~.~'' I i 9303' I-I~-,,~,, ,x., .,~, ,~=3..~,.I Id ~aker 5"X7" ~eback Sleeve; 9318' I/ZXP Liner top packer ;'H~ I/Liner hanger I 7" 26¢, L-80, BTaM Liner I~ 9468' 15 1/2" "XA" Sliding Sly; I.D.-=4.562" Id [Tubing Seal Assembly I-I I~,~,,Baker Packer;4.75" I.D. Id 8~25' I' I Pre-rig CTU Cement P&A; TOC I-I 8940' I I soos' I-I~-~" OT,S'X'.,~.,~=~.~ ITOPOF7" Liner I--I ~0~' ITOP OF 2-7/8" Linerl--! 9029' 19-5/8- 47#. L80, BTRS Csg Id 9518' 10337' I I Millout Window I-i 9672' I 7" 26#, L80, BRTS Liner I-I 10483'1 11333' I--12 7/8" FL4S Liner, 6.16#, L-80, .0058 bpf I DATE REV BY COMMENTS 01/17/02 DEW Proposed completion for D-17B. 01/22/02 DEW Update proposed completion for D-17B with new GLM design. PRUDHOE BAY UNIT WELL: D-17A PERMIT No: APl No: 50-029-20692-02 Sec. 22, T11N, R13E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 D- 17A Abandonment Cement Subject: D-17A Abandonment Cement Date: Thu, 23 May 2002 11:10:56 -0500 From: "Smith, Phil G (FAIR)" <SmithPG 1 ~BP.com> To: "Winton Aubert (E-mail)" <winton_aubert~admin. state, ak.us> Winton, The volume of cement expected to abandon the current D-17A wellbore will be based on the entire liner volume from PBTD to the production packer area, roughly 11,333' to 8940' MD. Comprising this is 2304' of 2 7/8" liner at 0.0058 bpf + 89' of 4 1/2" tailpipe at 0.0152 bpf for a total volume of approximately 15 bbls (14.7 bbls calculated). Regards, Phil Smith Operations Drilling Engineer 1 of 1 5/23/2002 8:19 AM 03 P E RM I T DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 06/09/98 RUN RECVD 96-046 96-046 96-046 96-046 96-046 96-046 96-046 IEL/GR/SP CN/GR SSVD 7335 7461 SLIM1/GR-MD SLIM1/GR-TVD 10 -407 ~L~sEPIA 11327-9500 ~SEPIA 11311-9500 ~EPIA 11327-9500 qL/CN/SR ~.-T/SCHLUMBERGER SLIM1/GR MWD DAILY WELL OPS ~ ~1~ Iq~ / TO (:~/p?/~&/ Are dry ditch samples required? yes ~__~d received? Was the well cored? yes ~Analysis & description received? Are well tests required? yes ~_~Received? ye_~-~n'o' Well is in compliance A~ Initial COMMENTS 1 06/28/96 1 06/28/96 1 06/28/96 1 07/19/96 1 09/12/96 FINAL 09/12/96 FINAL 09/12/96 , BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Date: October 31, 1996 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Steve McMains Subject: Revised Completion Reports for Wells S-28A, S-02A, D-17A, R-39A A quality check of our surveys found that incorrect surveys were submitted for the wells S-28A, S-02A, D-17A, and R-39A. A miscommunication between vendors resulted in outdated geomagnetic models being used. The problems have been resolved and the survey data recalculated. The enclosed Completion Reports show the revised bottomhole locations. Corrected surveys are attached, and are the true and correct surveys for these wells. If there are any questions please contact me at 564-5894. Thank you. Sincerely, Theresa Mills Coiled Tubing Technical Assistant 3 *-~. STATE OF ALASKA ' - ALASKA C,_ AND GAS CONSERVATION COM,,,:SSION ,eLL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPE]'~)ED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 96-46 3. Address 8. APl Number P. 0. Box 196612, Anchora~Te, Alaska 99519-6612 5 o . 029-20692-01 4. Location of well at surface 9. Unit or Lease Name 2100' SNL, 1692' WEL, Sec. 23, T11N, R13E '~V.':-~.:.;'-.'~7':?~::;~ Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1141'NSL, 762' EWL, Sec. 23, T11N, R13E 11. Field and Pool At Total Depth :: .... ' ........ Prudhoe Bay Field/Prudhoe Bay Pool 3423 SNL, 442' WEL, Sec. 22, T11N, R13E 5. Elevation in feet (indicate KB. DF, etc.) 16. Lease Designation and Serial No. KBE= 78.93 I 028284 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 5/28/96 6/11/96 6/17/96I n/a feet MSL] one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD] 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11,320' 8931'TVD 11,291'MD ' 8919'TVD YES [] NO []J 1998feet MD 1910' 22. Type Electric or Other Logs Run 23. CASING. LINER AND CEMENTING RECOFD SETtiNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'FI'OM HOLE SIZE CEMENTING RECOF~ AMOUNT PULLED 2-7/8" 6.16# L-80 9030 11320 3-3/4" 18 bbls Cement 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 11,030 '- 11,160' 8890'- 8889'; 2" 4 spf 10,485'- 10,535~ 8880'- 8890'; 2" 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 6/30/96 FL Date of Test Flours Tested PRODUCTION FOR OlL-BBL GAS-MCF WATER-BBL CHOKE SlTF IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence et oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~' 30. GEOLOGIC MARKERS FO, ,rlON TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, ME_AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag R 9521' BKB 8411' ss Shub/ik 9551' BKB 8438' ss Ivishak 9840'BKB 8516'ss 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed c~¢?~~--~ Title Coiled Tubino Drillincl Enclineer Date 10/21/96 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 D-17A Anadrill ******************** Survey Program ******************** Company Well Name Location 1 Location 2 Magnetic Declination Magnetic Model Magnetic Model Date Grid Convergence Angle Grid Zone KBE Date Anadrill Job Number AFE APl BP Exploration D-17A Prudhoe Bay North Slope Borough, Alaska 28.40 deg IGBG-95 5/27/96 Alaska State Plane Zone 4 78.93 ft 10/2/96 37952 4P0786 50-029-20692-01 Well Head Location Grid X 653471.00 Grid Y 5958888.00 Lat (N/-S) 70° 17' 40.659" Long(E/-W) -148° 45' 26.314" 70.29462751 -148.75730949 Azimuth from Tie-In to TD is Departure from Tie-In to TD is 300.07 1411.66 deg ft Tie-In Point (TIP) Measured Depth True Vert Depth Inclination Azimuth Latitude (N/-S) Departure (E/-W) 9600.00 ft 8560.26 ft 28.52 deg 244.69 deg -2030.05 ft -2807.24 ft ********** Note: All Directions & Coordinates are referenced to TRUE North ********** _. . . Anadrill- Schlumberger Alaska District D-17A Anadrill Survey Calculations Minimum Curvature Method Measured Interval Vertical Target Station Azimuth Latitude Departure Displacement at Azimuth DLS Depth Depth Section Incln. +N/-S +E/-W ft ft ft ft deg deg ft ft 9600.00 0.0 8560.26 1412.41 28.52 244.69 -2030.05 -2807.24 9678.00 78.0 8628.79 1433.57 28.52 244.69 -2045.98 -2840.91 9729.00 51.0 8671.79 1449.44 36.40 246.20 -2057.31 -2865.80 9779.00 50.0 8710.08 1469.76 43.60 252.10 -2068.61 -2895.83 9829.00 50.0 8746.07 1494.61 44.40 259.50 -2077.10 -2929.46 deg/ ft deg 100ft 3464.35 234.13 0.00 3500.97 234.24 0.00 3527.79 234.33 15.53 3558.79 234.46 16.26 3591.11 234.66 10.40 9879.00 50.0 8782.15 1522.75 43.40 269.70 -2080.38 -2963.88 9917.00 38.0 8810.33 1545.72 41.00 279.60 -2078.37 -2989.26 9946.00 29.0 8832.40 1563.65 39.90 285.70 -2074.27 -3007.60 9969.00 23.0 8850.06 1578.15 39.90 294.20 -2069.24 -3021.44 10000.00 31.0 8872.62 1599.34 46.90 307.30 -2058.27 -3039.57 3621.13 234.93 14.28 3640.78 235.19 18.59 3653.52 235.41 14.16 3662.08 235.59 23.69 3670.89 235.90 36.69 10030.00 30.0 8890.89 1622.59 58.00 315.00 -2042.58 -3057.35 10059.00 29.0 8904.67 1646.32 65.40 327.00 -2022.74 -3073.29 10095.00 36.0 8917.56 1676.06 72.60 328.50 -1994.33 -3091.20 10136.00 41.0 8926.70 1711.00 81.60 329.50 -1960.11 -3111.76 10171.00 35.0 8929.88 1741.44 88.00 328.80 -1930.20 -3129.63 3676.89 236.25 42.18 3679.21 236.65 44.43 3678.71 237.17 20.37 3677.64 237.79 22.08 3676.99 238.34 18.39 10206.00 35.0 8930.33 1772.55 90.50 325.80 -1900.75 -3148.53 10266.00 60.0 8928,45 1826,25 93.10 327.20 -1850.75 -3181.63 10286.00 20.0 8927.80 1844.19 90.60 325.20 -1834.14 -3192.74 10300.00 14.0 8927.90 1856,90 88.60 324.50 -1822,70 -3200,80 10335.00 35.0 8929.88 1888.75 84.90 324,20 -1794.31 -3221.17 3677.78 238.88 11.16 3680.76 239.81 4.92 3682.08 240.12 16.00 3683.39 240.34 15.14 3687.20 240.88 10.61 10370.00 35.0 8934.30 1920.75 80.60 321.50 -1766.64 -3242.12 10405.00 35.0 8941.22 1952,66 76,60 321.70 -1739.76 -3263.43 10445.00 40.0 8950,70 1989,23 76,00 317.90 -1710.08 -3288.51 10480.00 35.0 8958.81 2021.67 77,20 317.60 -1684.88 -3311.40 10515.00 35.0 8965.84 2054,51 79,60 315,80 -1659.93 -3334.91 3692.21 241.41 14.47 3698.21 241.94 11.44 3706.57 242.52 9.35 3715.40 243.03 3.53 3725,19 243.54 8.51 10563.30 48.3 8973.57 2100.36 82.00 316,20 -1625.64 -3368.03 10596.00 32.7 8977.49 2131.66 84.20 314.60 -1602.52 -3390.82 10630.00 34.0 8979.54 2164.61 88,90 313.20 -1579.00 -3415,27 10670.00 40,0 8978.14 2203.15 95.10 317.40 -1550,61 -3443,37 10705,00 35.0 8974,85 2236,92 95,70 311.10 -1526.30 -3468.32 3739,83 244.23 5.04 3750,44 244.70 8.30 3762.62 245,19 14.42 3776.40 245,76 18.72 3789.30 246.25 18.00 Anadrill - Schlumberger Alaska District D-17A 10740.00 35.0 8972.04 2271.20 93.50 310.40 -1503.53 -3494.75 10775.00 35.0 8971.03 2305.73 89.80 308.00 -1481.43 -3521.85 10810.00 35.0 8972.32 2340.55 86.00 302.20 -1461.33 -3550.45 10846.30 36.3 8975.83 2376.64 82.90 294.90 -1444.07 -3582.16 10887.00 40.7 8979.73 2416.91 86.10 292.80 -1427.69 -3619.20 3804.45 246.72 6.59 3820.74 247.19 12.60 3839.42 247.63 19.80 3862.28 248.04 21.76 3890.62 248.47 9.39 10923.00 36.0 8980.36 2452.60 91.90 292.80 -1413.75 -3652.37 10938.00 15.0 8979,57 2467.45 94.10 292.80 -1407.94 -3666.18 10973.00 35.0 8976.01 2501.99 97.60 292.80 -1394.45 -3698.27 11010.00 37.0 8971,66 2538.27 95.90 289,30 -1381.26 -3732.56 11045.00 35.0 8968,18 2572.30 95.50 286,40 -1370.59 -3765,70 3916.44 248.84 16.11 3927.23 248.99 14.67 3952.43 249.34 10.00 3979.93 249.69 10.46 4007.37 250.00 8.32 11053.00 8.0 8967.48 2580.04 94.60 286.20 -1368.35 -3773.35 11080.00 27.0 8966.06 2606.17 91.40 285.40 -1361.01 -3799.29 11110.00 30.0 8966.12 2635.00 88.40 282.70 -1353.73 -3828.39 11138.00 28.0 8967.12 2661.33 87.50 277.90 -1348.73 -3855.91 11173.00 35.0 8969.44 2693.46 84.90 276.20 -1344.44 -3890.57 4013.80 250.07 11.52 4035.71 250.29 12.22 4060.68 250.53 13.45 4084.99 250.72 17.43 4116.31 250,94 8,87 11198.00 25.0 8972.53 2716.06 80.90 275.20 -1341.97 -3915.25 11234.00 36.0 8979.70 2748.03 76.10 275.00 -1338.84 -3950,37 11259,00 25,0 8986.49 2770.07 72.40 278.00 -1336.12 -3974.27 11280.00 21.0 8993.67 2788.66 67.60 283,20 -1332,51 -3993.66 11299.00 19,0 9001,11 2805,48 66.30 285,30 -1328.21 -4010,60 4138.85 251.08 16.48 4171.08 251.28 13.34 4192.86 251.42 18.77 4210.09 251.55 32.61 4224.82 251.68 12.26 11320.00 21.0 9009,79 2824.07 64.90 287.60 -1322.79 -4028,94 4240.54 251.82 12.00 ******************** End Of Survey ******************** Anadrill- Schlumberger Alaska District Schlumberger- GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) TO: September 9, 1996 BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Slim I GR, Slim I GR TVD for well D-17A, Job # 96236, was sent to: BP Exploration (Alaska)Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 OH LIS Tape Bluelines each Film each State of Alaska ...................................... : ...... ~ ' ...... ~ ..... I OH LIS Alaska-Oil'"& Gas Conservation ' I Blueline each Attn: Lori Taylor I RFolded sepia each 'A~rrc01 Porcupine Drive hor_a, ge, AK 99501 ARCO Alaska, Inc. Dede Schwartz, ATO-1336 Attn: Records Processor Anchorage, AK 99510-0360 _1 OH LIS Tape I Blueline e~,ch Exxon Company U.S.A. Alaska Interest Organization Attn: Susan Nisbet 800 Bell Street, EB3083 Houston, TX 77002-7420 I OH LIS Tape I Blueline each Certified Mail Z 777 937 468 Phillips Company Attn: Marty Gray, Room B-2 P.O. Box 1967 Houston, TX 77251-1967 I OH LIS Tape 1 Blueline each Certified Mail Z 777 937 470 Mobil Oil Company Attn: Barbara Sullivan 12450 Greenspoint Dr., Suite #550B Houston, TX 77060 I Blueline each Certified Mail 7 777 937 461 Please Note: No depth shifting per Greg Bernaski PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Date Delivered: Received by: HOWARD OKLAND Attn. ALASK~ OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 12 July 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL D-17A DESCRIPTION Run # 1 Run # ECC No. 6702.00 6713.00 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 O~ (907) 563-7803 Date: RECEIVED ,JUL 1 9 1996 STATE OF ALASKA ALASK/--"IL AND GAS CONSERVATION C('f-'MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPEt~)FI-) [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 96-46 3. Address .8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 5o-029-20692-01 4. Location of well at surface 9. Unit or Lease Name 2100' SNL, 1692' WEL, Sec. 23, T11N, R13E~-'~¥ ..............~;'~_.-~ ' ' Prudhoe Bay Unit lO. Well Number At Top Producing Interval t At Total Depth .... ] ...~_~_ ~ ~'];~ Prudhoe Bay Fie/d/Prudhoe Bay Poo/ 3459' SNL, 385' WEL, Sec. 22, T11N, ~;~ ,- ............. , ...... 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE= 78. 93 028284 12. Date Spudded 13. Date T.D. Reached 14. Date Comp..~,~..,,,,~//,~:~"'Susp' or Aband. 15. Water Depth,n/aiffeetOffshoreMSL 16. No. of Completions 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11,320' 8931'TVD 11,291'MD 8919' TVD YES [] NO []I 1998 feet MD 1910' 22. Type Electric or Other Logs Run _ 23. CASING, LINER AND CEMENTING RECORD t . SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2-7/8" 6.16# L-80 9030 11320 3-3/4" 18 bbls Cement 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) 11,030; 11,160' ' 8890; 8889'; 2" 4 spf 10,485'- 10,535' 8880; 8890'; 2" 4 spf 26. ACID, FRACTURE, CEMENT SQUEF-TE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 6/30/96 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE JGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure OALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence ot oil, gas or water. Submit core chips. ORIGINAL ~nchorago Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS ..... ~,MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, ME. AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag R 9521 ' BKB 8411' ss Shublik 9551' BKB 8438' ss Ivishak 9640 'BKB 8516'ss RECEIVED Alaska, 0il & Gas Cons. Comrmssior) Anchor~.ge 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~/~.~ TitleOoi/odTobin. Ori/,il?.Enqineor_ _ _ Date ~,/~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Daily Operations Well: D-17A Accept: Field: Prudhoe Bay Spud: APl: 50-029-20692-01 Release: Permit: 96-46 CTD Unit: 5/27/96 5/28/96 6/17/96 4985 Date Day Depth RECEIVED 5/27/96 1 9689 JUL. 1,5 1996 MIRU. Perform BOP test. Witnessed by AOGCC. MU BHA #1. 5 / 2 8 / 9 6 2 9689 Alaska Oil & Gas Cons. Commission Anch0r~ge MU BHA, Baker tools and nozzle. RIH circ. SW to 9660. Swap hole over to mud. POH while swapping over. Picked up bit, Drillex 2-7/8 mtr, Anadril BHA. Ran in hole. Attempt to orient to HS. Only got 60° and orienter stopped turning. Not a good beginning. Tagged TD @ 9695 CTMD. POOH. Pulled one gripper block that was nicking pipe while POOH. Change out orienters and surface test. 1000 psi required to turn it. Reduce TFA of bit. RIH w/ BHA #3. 5/29/96 3 9949 Ran in w/ BHA #3. Drilled from 9692 to 9811. Ran wiper to window. Ran GR survey from window to 9750. Depth on-no correction. Continued drilling. Penetration slowed past 9903. Bit continued to gradually slow down. Pulled bit @ 9939 to change bits. Bit badly cored but in gauge. Serviced inj head (3 hr.). RIH w/ BHA #4, TSP bit. Drill ahead, about 5'/hr in Zone 3. 5/30/96 4 10021 Drill ahead, about 5'/hr in Zone 3. Lost approx. 12 bbls mud over the last 24 hours. Pump plunger leak. Shut down to repack same. Drilled ahead slowly. Penetration rate varied from 1 to 11 ft/hr. Toolface drifted right. Had some difficulty rotating all the way back around. Drilled ahead. At 9968 penetration dropped to nothing. Unable to make progress. Took survey and pulled out to change bits. TSP bit starting to core. Aisc gummed on sides. RIH w/used PDC and 2.75° motor, BHA #5. Drilled to 9991'. ROP initially at 40 fph. Slowed to 13 fph. Wiper trip to window, clean. Took 2 hrs to orient to start building angle. MWD having problems with dirty signal while drilling also. ROP picked up to 25 -40 fph below 9990', bottom Zone 3? Taking a lot of set down weight and differential to drill. Bit is worn. Drill to 10021'. Building angle. MWD pulsar hanging up in dog leg 5/31/96 5 10063 Drilled to 10051. Building angle too fast. Up to 42 deg/100. Pull out to change from 2.75 to 1.75 bent mtr. Bit starting to core. Tried to dump GR data while at surface. Connection problems with doing this. Aborted getting GR retrieved from tool until data collection equipment is fixed. Picked up tools and ran back in. Oriented to 16 deg toolface and continued drilling. Drilled to 10063', 50 fph. BHA hanging up in dogleg. Ream from 9970' - TD while orienting around. Problems orienting (took 40 cycles to get 15 orientations). Could not orient passed 220° in open hole. Orienter torque too Iow. Picked up above window and oriented. RIH to bottom. Still needed to orient. Orienter quit. Survey on bottom showed unreasonable turn rate (68°/100). Possible azimuth error being introduced as hole angle builds. Will put steering package on top. POOH. Bit worn on sides, but still in gauge. Change out BHA, including Baker tools. 6/1/96 6 10196 Change out BHA, including Baker tools. Running GR tool on btm now-standard rig up. Check head. Run in and locate RA tag on whipstock. Correct depth. Logged 9970 to 10036 in memory (data lost prior due to retrieval problem) for correlation. Tag btm @ 10064. Take survey on btm and pull back to 9970 to transmit same due to dogleg too high for Anadril. Continue drilling to get horizontal. Orienter not working well. Drill to 10170', 40 fph to 60 fph. 89° at the bit. Trip for BHA change. Change out Tomahawk orienter to Sperry Sun orienter. RIH w/ BHA #8, 1° motor. Encountered ledges at 10064' and 10141'. Tagged and corrected to 10170'. Drilled ahead, turning left. 35 fph. 6/2/96 7 10267 Drilled ahead, turning left. 25 fph. Some problems sliding. Building angle. At 10267 reoriented to begin dropping angle. Discovered metal in micromotion meter- shaved coil!. Investigated and found piece of hard junk metal had been dragged into the packoff while the pipe was being run down, and wedged in the brass and severely gouged the pipe on the right hand side over a 250 ft inter Estimated worse case 40% of metal thk ,ss removed. rig down injector head and cut the bad coil out. Rig down section 5. Back to the road. !!!@Z!@!! Decided to pull out and 6/3/96 8 1O267 Unable to receive approval from DS to use spooling trailer. Lay coil out on road. Cut off approx. 600' of damaged coil. Straighten coil in welding jig, difficult. Welders must shut down for the day (they can only work 18 hours). 6/4/96 9 10267 2 welds failed inspection. WO welders who went back to bed after 18 hr day. (Only welder available). 6/5/96 1 0 10267 Third weld failed inspection. Fourth weld passed. install coil connector and pressure test BOPs. Spooled coil. Moved back onto D-17A. Stabbed pipe. Preparing to 6/6/96 1 1 10267 Stab coil back into inj head. Re-stab inj onto tower. MU hoses. Check into bop-one piece of metal-remove same. MU annular. Secure lub hose. Function test and PT all BOP 300 psi & 3800 psi. PU lubricator. Fill coil w/ mud and flush same. Spot SW for picking up tools 6/7/96 12 10600 Drilled from 10420 to 10516 where the BHA became differentially stuck during a survey. Spotted 10 bbl of dead crude in open hole and BHA popped free. Continued drilling to 10582 where assembly quit drilling. Tried reaming lower section of hole at several different tool face orientation but still couldn't make progress on btm. POH. PU new bit, 1.2 deg. motor. Downloaded GR. RIH. Tied-in to RA tag at WS. Found TD at 10598 after tie-in. Drilling. 6/8/96 1 3 10842 Finished reaming interval 10550 to 10600 to alleviate stacking. Trouble getting started drilling. Finally started to make hole. Drilled and surveyed from 10600 to 10705 with high side toolface to build angle away from shale. Angle built to 95.7° by 10705. Re-oriented to level off again and get back to prognosed plan. At 10741 could not get a survey due to excessive pump noise. Pulled wiper trip to window. Checked suction screen and pump suction valves. Found success in taking suction from Pit #1 only. Drilled to 10810' and stuck pipe while surveying and orienting. Worked pipe to 75K. Pumped 10 bbls dead crude. Pipe came free. Drilled to 10842'. 6/9/96 14 10922 Drilled down to 10857. Unable to get further Anadril signals due to Iow battery. Pulled out to change batteries, dump prior data, and change orienter. When at surface, lost drain plug from Drillex mtr- could not verify if it fell on the master valve. Could not find bleed screw in work area. Removed BOP tarp it inspect same-could not find bleed screw. Tried to fish on top of master gate with rev circ junk basket- no recovery. Laid down Anadril tool- discovered data lost due to too Iow a battery. Removed all fluid on top of gate w/vac truck, could not see screw- give up on same.. Picked up fresh tools including new bit. Lost 3 carbide gauge pads from previous bit but bit still in gauge. Ran in hole and ran tie in strip across RA tag in whipstock. Drilled to 10922. Could not get MWD survey. Pulsar bad. POH. At surface found pulsar impeller torque very loose. Changed out MWD. Found loose gage buttons on bit. Changed out bit and Drilex motor. 6/1 0/96 1 5 1 1218 Drilled from 10922 to 11098. Blew packing on mud pump. PU into casing to repair pump. Drilled to 11130. Blew pump seal. PU to casing to repair. Drilled at high ROP to 11150, end of target in 25P. Began dropping angle to achieve 8820' ss at TD. Encountered very hard drilling at base of 25P. Broke through 24N and ROP increased for 15 ft then hit very hard drilling again. Reamed last 200 ft on high side. Got through hard spot. Back to high ROP at 11208. Drilling at 11218 at 26 FPH. Have approximately 100 ft left to drill to reach 8920 TVDss. 6/1 1/96 1 6 1 1320 Repaired pump while in the casing. Washed back into open hole. Tagged up @ 11200. Had to ream to get past the spot. Tagged prior TD of 11223. Had difficulty drilling- acting like BHA wall stacking. Reamed from 11150 (where we started working drift down) at several different tool face orientations. Began drilling again but slowly. Stacked again @ 11233. Reamed hole again at several different toolfaces. No evidence of reaming from the drilling pressures. Try to drill again. No success. Tried long trip to 10300 ft and back down to try to reshape coil a little and maybe get by if BHA is wall stacking-no success. Pulled out to inspect BHA. Found bit beginning to ring but in fairly good condition. Make up new BHA with 1.6° ben~ .,w A-3 bit and no jars. logging. Drilled to TD at ~20' MD. Begin conditioning hole for 6/1 2/96 1 7 11320 Condition hole for logging. Pull out of hole and lay down bottom hole assembly. and misc. tower equipment. Wait on wind to subside. Rig down lubricator. Rig down hoses 6/1 3/96 1 8 1 1320 R/d inj head and tower sections, RU DS e-line CTU for open hole logs. Test e-line. Found dead short in line 3 and small leak in line 7. Determine shorts to be in collector at reel. Replace collector. MU atlas logging tools. RIH with gamma ray, resistivity and neutron tools. Work through tight spots at 9,872', 10,070' & 11.190'. Log from TD (11,333' elm) to 9500'. Pull out of hole to 800' and wait on orders for possible sonic logging. 6/1 4/96 1 9 1 1320 Prepare to run bhcs/gr. Wireline crossover contaminated with fluid. Redress head. Head shorted again. Rehead. MU bhcs/gr BHA. RIH, short while RIH at 4200 ft [#1 wire]. POOH. Found internal resistance leak in cable head tension tool, c/o tool. MU bhcs/gr BHA. RIH to fluid level. Another leak. POH and work on cable head. RIH and attempt sonic log. Gamma ray not working on bottom. Sonic has to much noise and cycle skipping. POH and lay down tools. Set crews to shop for rest and re-grouping. Maybe we will have better luck tomorrow. 6/1 5/96 20 1 1320 Wait on logging crew. Change plans and cancel rest of open hole logs. Order 150 ton peak crane. Pick tower sections 1,2,3,4 and injector head. Rig up hoses and electrical lines to tower. Pick up tongs. Pick up first two joints of liner. Tong will not put out any more than 200 ft-lb. They also leak hydraulic fluid like a lawn sprinkler. Lay down tongs. Call everybody we can think of for a replacement set of tongs. All the operating sets are across the river. Do it the old fashion way with a pair of 36" pipe wrenches. Pick up and run 74 joints of 2-7/8", FL4S liner. Pick up lubricator. Make up running tool. Latch up to liner top. RIH with liner while pumping at minimum rate. 6/1 6/96 2 1 1 1320 RIH with liner while pumping at minimum rate. Run through window with no wt loss. RIH at 50 fpm pumping 0.5 bpm. Set down at 10.847 ft bkb. Work liner down at various speeds, no luck, attempt to wash down at 1.5 bpm. Pull out of hole. Hydraulic system in pump skid down. Resume pumping and disconnect from liner. POH to check "GS" running tool. RIH and latch liner at the same place. Pull out of hole to lay down liner and go to plan "b". Got to surface and no liner. Run back in hole and tag top of the liner 8544'. Just as we were attempting to latch into the "GS", the main hydraulic pump on the coiled tubing unit went out. Called out unit 4932 to provide hydraulic power to get out of the hole. 6/1 7/96 22 1 1320 Rig up CTU 4932 to supply hydraulic press for CTD unit 4985. Test RIH and POOH, OK, except speed limited to 75 fpm due to gpm of smaller hydraulic pump. Attempt to latch PBR with GS spear. No luck, several attempts, circ and non- circ. POOH. No marks on GS spear, spear OK. RU wireline to prove if GS profile is OK. RIH and latch GS on second attempt. GS is OK. Shear off and POOH with wireline. R/d wireline. Cut 20 ft off CT. MU new baker fishing BHA, longer BHA will line up better with PBR GS profile. RIH with fishing BHA, check wts every 1000 ft. Tag top of liner at 8,932'. It is stuck solid. Pulled up to 75,000# while pumping and jarring. No luck. Order out 30 bbls dead crude. Keep 75,000# tension on liner until crude gets here. Pumped the dead crude and displace 10 bbls outside liner. Started jarring and it came loose on the 5th hit. Pulled up to 8000' to check weights. Looks OK. Started down with liner while pumping dead crude out the float shoe. Saw a slight weight bobble at 8550' and near TD. Sat down on bottom. Disconnected "GS" running tool. Top of liner is at 9,030'. Circulate out dead crude and pull out of the hole. Flush coil with seawater. Spot 100' of seawater at top of well. Out of hole and start to rig down. 6/20/96 Well was SI on arrival. Pump dart thru CT to verify displacement 3 times. Found that Camco pump counter needed adjusting. Tested BJ pump against densiomenter and densio is right on. RIH and circulate and condition wellbore fluids. Tag @ 10136' CTD and unable to work past. Assume CT connector (2.315") is too close of tolerance to drift (2.347") of liner. POOH. Change out CTC to 2.300". RIH with BHA #2. Sting into TIW seal assy and circ flopro. Unsting and circ flowpro. Sting back in and pump 18.5 bbls cement and unsting from TIW seal assy and POH while ciculating flo pro. RIH with BHA #3. RU HB&R pump. Pooh while displacing liner with high vis flo pro,leave liner displaced with high vis flopro, Circulate flo pro out of tubing using fsw while pulling out of hole. clean returns at surface. RDMO 6/27/96 Ran memory GR/CCL for tie in. Tagged TD at 11271 ft uncorrected depth. Flagged coil at 11154 ft and 10604 ft uncorrected depth. With Icg processed, we need +20 ft correction for lower interval and +17 for the upper interval. The correction at the jewelery is +14 ft. There are some stretch differences along the horizontal section between this and the open hole CNL 6/13/96. While running in we tagged up at 9986 ft, 10021ft, 10313 ft, 10993 ft and 11058 ft. We were able to work our way down, pumping to help. Between 10300 ft and 10900 ft we lost weight every 30 ft or so, indicating some kind of restriction at the liner joints or mabey we were hitting with the knuckle joint. We got stuck at 9080 ft on the way out and were unable to circulate as if we were packed off. Acted as if something was beside us. Finally came free. Ran a motor and 2.27" bit into and back out of 2 7/8" liner. Saw nothing. We tagged and stalled 16 ft off bottom but didn't go deeper in case we brought more problems on ourselves. Flags were only 1 ft off tie in run indicating good repeatable depth counters. No wear on bit. Perforated the following intervals in two runs: 11030 - 11160 ft 2" guns 4 spf 90 degree phasing 6.5 gm Alphajet charges 10485 - 10535 ft ........ Perforation was done with the well full of seawater, estimate 500 psi overbalance. Depth reference CNL 6/13/96 Despite the milling run, there seems to be something in the 2 7/8" that occasionally rolls beside the coil. We were able to easily work past it each time. However the small clearance between the liner 2.347" drift ID and the coil is a concern. With the perforating debris left in the well. I would recommend a FCO with a hangwall assembly and Biozan before running coil past the perfs in future. · . CO~PAH¥ BP EXPLOraTION LOC~TION I P~UDNOE BAY LOCATION 2 MAGNETIC DECLINATION 2~,37 ~A?E: 11-~UN£-?~ ~ELL NUMBER 0 AFE NO 4POY~6A WELL H~A~ LO~A?ION: ~EP(E/-W) AZIHUTN FROM ROTARY TABLE TO TARgeT IS 251,i0 TIE IN POINT(TIP> : M~ASURED DEPTH TRUE VERT ~EPTH INCLINATION AZI~UT~ bEPARTUR~(£/-W) ?~OO,O0 8451,30 28.50 243,50 -2087.40 -2755,80 RECEIVED JUL 1 ,5 1996 Alaska Oil & G-~s Cons. Commission Anchorage PAC~ ~0, 2 )-17 A RECEIVED M~ASUR~ INTERVAL VERTICAL ~EPTH ~£PTH ft ft ft 9600.00 0.0 8481,30 967E,00 78,0 8549,85 9729.00 51,0 8592.85 9779,00 50.0 8631.15 .9829.00 50,0 8667,14 ******,w***** ANADRILL SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD***~**** TARGET STATION AZIMUTH LATITUDE SECTION INCLN, N/-S ft deq deg ft 0,00 28,50 243,50 -2057,40 36,89 28,50 243.50 -2104,01 64.I0 36.40 247,30 -2II5,29 96.18 43.60 253,20 -2126,02 130,69 44.40 260,60 -2133.87 D~PARTUR~ DISPLAC£MENT at AZIMUTH DLS E/-W deo/ ft ft de9 lOOft -2765.80 3465,10 232,96 0,00 -2799,11 3501,69 233,07 0.04 '2824.00 3528,38 233,17 1J.7~r n -2854.24 3559,02 233,32 16,26 '2888.03 3590.83 233,54 10.40 9879,00 9917o00 9946,00 9?69,00 10000,00 10030,00 10059,00 10095,00 1013~,00 10171,00 50.0 8703,21 164,15 38,0 8731,39 187,31 29,0 8753,47 203.14 23,0 8771,12 214.43 31,0 8793,68 227,72 30.0 8811.95 239,06 27,0 8825,73 247,25 36,0 8838.62 254.37 41.0 8847,77 261,98 35,0 8850,?4 268,54 43,40 270,80 -2136.49 41.00 280,70 -2133.99 39,90 286.80 -2129.53 39.90 295,30 -2124,24 46,90 308,40 " -2112,93 58,00 316,10 -2096,89 65.40 328,10 -207&,75 72,60 329,60 -204G,00 81,60 330,60 -2013,39 88.00 329,?0 -I983.i5 -2922,50 3620,16 2~3,83 14,28 -2947,~4 3639.I~ 234,I0 18,59 -2966,I0 3651,~9 234,32 I4,16 -2979.84 3659,48 234.52 23,69 -2997,75 3667,56 234,82 36,69 -3015,23 3672,6~ 235,I8 -3030.79 3674,04 235,58 -3048.15 3672,27 236,10 -3068,05 3669,70 236.73 -3085,34 3667,72 237,27 42,15 44.43 20 ~' 22,08 1G,39 10206.00 10266,00 10286.00 10300.00 10335,00 35,0 8851,40 276,23 60,0 8849,51 290.23 20,0 8848,87 295,00 14.0 8848.~6 298,66 35,0 8850.95 308,08 90,50 326,90 -1953,34 93,I0 328,30 -1902,72 90,60 32~,30 -I885,90 88,60 325,60 -I874,30 84,90 325.30 -1845.52 -3103,67 3667,20 237,82 11,I6 -3135,80 3667,~1 238,75 4,92 -3146,60 366~,47 239,06 16,00 -3154,44 3669,26 239,28 15.13 -3174,25 3671,76 239,83 I0,61 10370,00 10405,00 10445,00 10480,00 10515,00 · . 10563,30 10596,00 10630.00 I0670,00 10705,00 35.0 8855,37 318,31 80.60 322,60 -I817.46 35,0 8862,28 329,14 76,60 322,80 -I790,I7 40,0 8871,76 342.56 76.00 319.00 -1760,02 35,0 8879.87 355,45 77.20 3!8,70 -1734,38 35,0 8886,91 369,01 79,60 316.90 -1708.9~ 4~,3 8894,63 385,40 32,7 8898,56 401,9I 34,0 8900,61 416,84 40.0 8899,21 433.54 35,0 8895,91 448,66 82,00 317.30 -1674.06 84,20 315.70 -I650,52 88.90 314,30 -1626,53 95,i0 318,50 -1597,60 95.70 312,20 -1572,82 -31V4.67 3675,47 240.36 -3215,46 3680.20 240,8~ -3239,96 3687,14 241,49 -3262,37 3694,74 242,00 -32~5,40 3703,31 242,52 14,47 11,44 ?,35 3,53 S,5I -3317,85 3716,26 248,23 5.04 -3340,20 3725,74 243.70 8.30 -3364.19 3736,76 ' 244.20 14.42 -3391.74 3749.16 244.78 18,72 -3416,21 3760,.89 245.28 18,00 10740.00 10775,00 10810,00 10846,30 108~7.00 35.0 8893.I1 465.7I 35,0 8892,10 483,62 35,0 8893,36 503.62 3~,3 8896,90 527,5I .40,7 8900,80 556,72 93,50 3Ii,50 -1549,55 89,80 309.I0 -1526,93 86.00 303,30 -1506,28 82.90 296,00 -1488,42 86,I0 293,?0 -I471.33 -3442,20 3774,89 245.76 -3468,87 3790,07 246,24 -3497,08 3607,65 246,70 -3528,45 3829,54 247,13 -3565.18 3856,85 247,57 6,59 12,60 I9.50 21,76 9,39 10923.00 · 1093G,00 10973,00 11010,00 11045,00 36,0 8901,42 583,I2 ?1,90 293.90 -I456,76 15.0 8900,64 594,11 94.I0 293.90 -1450,69 35,0 8897.07 619,66 97,60 293,?0 -1436,58 37,0 8892,72 ~47,36 95.90 290,40 -1422.74 35,0 8889.25 674.86 95,50 287,50 -1411,43 -3598,07 3881,78 247,96 I6,1I -3611,76 3892,22 248,12 14,67 -3643,59 3916.57 248,48 I0,00 -3677,62 3943,23 248,85 I0.46 -3710,55 3969,93 249.17 3,32 P~£ NO, 3 . D-I7 ~ *******~***** ANADRILL ************** SURV£¥ CALCULATIONS ************* CIRCULAR ARC M£THOD******** ~£ASUR£~ INTERVAL VERTICAL OEPTH DEPTH ft ft ft 11053,00 8,0 8888,54 11080,00 27,0 8857o13 11110,00 30,0 8887,18 III38,00 28.0 888~,I8 II173,00 35.0 8890,50 TARGET STATION AZIMUTH LATITUDE SECTION INCLN, N/-S ft deg deg ft 681,28 94,60 287.30 -1409,04 703,15 91,40 286.50 -140i,2! 728,00 88,40 283.80 752,I5 87,50 279,00 -I387,84 783,25 e4,?O 277,S0 -1382,89 11198,00 25.0 8893.59 I1234,00 36,0 8900,77 I1259,00 25.0 8~07,55 11280,00 21,0 8914,74 It279,00 19,0 8722,1~ 805.60 80,90 276.30 'I379.95 837,53 76,i0 276.10 -!37~.I4 859,06 72,40 277,I0 .i~?~.~, 97 876,04 67,60 2~4,30 'I268,98 11320,00 21,0 8930,85 905,88 .- nu,~: ~'~, AT 11320 D£PARTUR~ ~ISPLAC£H£N? at ft ft -3718,16 3976,19 -3743.95 3997,57 -3772,?0 4021,98 -3800.33 4045,8I -3834,89 4076,61 AZIMUTH de9 249,25 247,48 247,73 249,94 250,1Z DLS deq/ lOOft 11,52 12,22 13.45 17.4~ 8,~7 -3857,52 4098,80 250,33 16,46 -3894,5~ 4130,56 250,54 13,34 -3918,42 4152,00 250,69 15,77 -3937,74 416~,72 '~ -3~72,83 4!78,71 25i,I2 12,00 PAG~ NO, CDI~PANY BF' EXPLDRAIIDN WZLL NA~Z D-12 A LOCATION I PRUDHDE. BAY LOCATION ~AGN~TIC DECLINATION 28,37 G~iD CDNV~GEHCZ ANGLE 0.00 WELL HUmBeR 0 APl NO 50-029-2067Z-01 A~ NO 4PO786A RECEIVED ft ft INC_CH; SURVEY ANALY:I: ************* CIRCULAR ARC METHOD******** CUMINC CHG I.RATE AZM_CHG CUMAZR_CNG deq/lOOft deg de9 TURN RATE dei/lOOft JUL. 1 5 199G AlaskaOil & Oa~Cons.~ommission CLOSURE TDDL.FAC~ DL3 DL3RT ft de~ deq/lOOft de~/lOOft**2 9600.0 9678,0 9729.0 9779,0 8481,30 0,00 0,00 0.00 0.00 0.00 0.00 8549,85 0,00 0.00 0,00 0,00 0.00 0,00 8592.85 7,90 7,90 15.49 3,80 3.80 7.43 8631,15 7.20 15,I0 14,40 5,90 9.70 !1,80 8667,I4 0,80 15,90 1.60 7.40 17,!0 14,80 1078,97 0.00 0.00 0,00 1085,89 90,03 0,04 0,05 I0~6.51 16.0~ 15,9~ 31.28 1086,~6 30 ~" ,w 16.26 0.54 0,00 0.00 10,~0 11.72 9879,0 9917,0 9946,0 9969.0 I0000.0 8703,21 -I,00 I4,90 -2,00 10.20 27,20 20,40 8731,39 -2,40 12,50 -6.32 9,90 37:20 26.05 8753.47 -1,10 11.40 -3,79 6,10 43,30 21,03 8771,12 0,00 11,40 0.00 8,50 51~80 36,96 8793,68 7,00 18.40 22,58 IS.IO 64.?0 42.26 I074,65 101,71 I4,2~ 7,75 1064.0~ 113.47 18,5t 11.35 1055,95 I07,~4 14,16 15.27 i044,4~ 93,26 23.69 41.45 1083.34 83,83 36,69 41.~4 10030,0 10059.0 10095,0 10136,0 10171,0 8811,95 Ii,I0 29,50 37,00 '7.70 ' 72.60 25,67 8825.73 7,40 36,?0 25,52 I2,00 84,60 41,38 883~.62 7.20 44.10 20,00 1,50 86,10 4,I7 8847.77 9,00 53.10 21.95 1.00 87.10 2,44 8850,94 6,40 59.50 18,2~ -0.70 86,40 -Z,O0 1007,15 31,24 42,1S 18,29 962,06 57.97 44,43 7.75 ?50,24 11,28 20,37 66.82 911,05 6,20 22,08 4,I6 10~.?~ 57,04 18,39 10,53 I0206,0 10266.0 10286.0 10300.0 10335,0 8851,40 2,50 62,00 7,I4 -3,00 83,40 -8,57 8849.51 2,60 64,60 4,33 1,40 84,80 2,33 8848,87 -2,50 62,I0 -12.50 -2.00 82.80 -10,00 8845,96 -2,00 60,I0 -14,29 -0.70 82.10 -5,00 8850.95 -3,70 56,40 -!0.57 -0.30 81,80 -0.86 842.70 50,22 I1.16 20,68 7~4,3V 28,27 4,92 10,39 764,98 141.32 16,00 55,41 751,47 160.73 I~.13 6.21 876,83 6,~5 I0,61 12,94 10370.0 10405.0 10445.0 104eO.O 10515.0 8855,37 -4.30 52.10 -I2.29 -2,70 79,10 -7.7I 8862,28 -4.00 48.10 -11,43 0,20 79.30 0.57 887i,76 -0,60 47,50 -1,50 -2,80 75,50 -9.50 8879,87 1,20 48,70 3.43 -0.30 75.20 -0,86 8886,91 2,40 51.10 6.86 -1,80 73,40 -5.14 6~4.66 i4S.24 14,47 11.05 552.I1 177.23 11.44 8,66 615.65 99.68 ~.35 5,23 5&4,I4 13,67 3,53 16,64 717.83 175.o,~' 8,51 14.23 10563,3 10596,0 10630,0 10670,0 10705,0 8894,63 2,40 53.50 4,97 .0,40 73,80 0,83 889S.56 2,20 55,70 6,73 -1,60 72,20 -4.8~ ~00,61 4,70 60,40 13.82 -1.40 70,80. -4.12 8899,2! 6,20 66,60 15.50 4,20 75,00 10,50 8895,91 0,60 67,20 1,71 -6.20 68,70 -18.00 509,10 9,35 5.04 7,1Y 479.55 35.~3 8.30 9,?S 449.i2 I6,61 i4.42 18.01 412.82 34,05 1G.72 10,73 552,65 36,48 18,00 2,04 10740,0 8893,11 -2,20 65.00 -6,29 -0,70 68.00 -2,00 10775,0 8~92,10 -3,70 61,30 -10,57 -2,40 65,60 -6,86 10810.0 8893,38 -3,80 57.50 -10,~6 -5,80 59.80 -16.57 10846,3 8896,90 -3,10 54,40 -8.54 -7.30 52.50 -20.11 10887,0 8?00,80 3,20 57,60 7,86 -2.10 50.40 -5.I6 351.02 162,39 &,59 32.59 320.98 147,00 I2,60 17,16 2~2,31 123..~ '~19,80 20.57 265,24 112,43 21,76 5,40 381,46 84,2~ 9,39 30,39 10923.0 I0938,0 10973.0 11010,0 I1045.0 8901,42 5,80 63,40 16,I! 0,00 50,40 0,00 8900,64 2,20 65,60 14,67 0,00 50,40 0.00 '8897,07 3.50 69,10 10,00 0.00 50,40 8892,72 -1,70 67,40 -4.5? -3.50 46.?0 -9,46 8889,25 -0.40 67,00 -1.14 -2,90 44,00 -8.29 ~--,,. 0.31 16,11 I8,67 202,56 0.71 14,67 9.62 178,91 0.17 10,00 13.34 154.7V 115.85 I0,46 1,23 237,18 33,26 a,32 6,10 Pt~G£ HD, 3 1)-17 i~ SURVEY A~ALY$I~ ~))~l~ CIRCULAR ARC METHOD~N~ TVD IHC CHG CU~IHC CHG ft de~ deg 11053,0 8888,54 -0,90 66,10 110e0,0 8887,I3 -3,20 62,90 11II0,0 8887,I8 -3.00 59,90 11138,0 8888,18 -0,90 59,00 II173,0 8890,50 -2,60 56,40 I.RAT£ AZ~.CHG CU~AZ~.CHG ?URH.RA?£ deg/IOOft deg det det/1OOft CLOSUR£ ?ODL.FRC£ DLS bLURT ft deg deQ/lOOf: deg/lOOft~2 -11,25 -0,20 43,80 -2,50 128,70 I67,~3 11,52 -11,85 -0,80 43,00 -2,~6 ii2,93 165,97 12,22 2,59 -I0,00 -2,70 40,30 -9,00 96,I4 135,0I 13,45 4,12 -3,2I -4,80 35,50 -17,14 82,02 100,71 17,43 14,21 -7,43 -I,70 33.80 -4,86 133,42 ?7.75 8,87 2~,46 11198,0 8~93,59 -4,00 52,40 11234,0 8900,77 -4,80 47,60 11259,0 ~907,55 -3.70 43,90 11280,0 8914,74 -4,80 39,I0 11299,0 8922,18 -1,30 37,80 -16,00 -I,00 32,80 -4,00 55,38 166,I3 16,48 30,46 -13,33 -0,20 32,60 -0,56 40,42 177,71 13,34 G,72 -14,80 3,00 35,60 12,00 29,70 142,43 18,77 21,71 -22,86 5,20 40,80 24,76 19,67 135,35 32,61 65,90 -6,84 2,10 42~90 I1,05 66,14 146,93 I2,26 107,12 11320,0 8~30,85 -I,40 36,40 -6,67 · . HO?E: SURVEY AT 11320' iS PROJECTE~ TO l~,. 2,30 45,20 I0,95 -1,53 124,23 I2,00 1,24 TO: David j ~~ton~ Uf ~ali fnai'l State Alaska Alaska Oil and Gas Conservation Commission DATE: May 27, 1996 THRU: Blair Wondzeii, ¢'~ FILE NO: P. I. Sup'ervisor ah9keldd.doc Chuck Scheve, ¢~ SUBJECT: Petroleum inspector BOPE Test- CTU BPX -PB U-D-17 PTD # 96-46 Prudhoe Bay Field Sunday May 27, 1996: ! traveled to BPX's D-17 Well and witnessed the BOPE test on Camc6 CTU ~985. The CTU BOP's consisted of 1 set of pipe rams to close on the coil tubing, 1 set of pipe rams to close on the. liner to be run after drilling the sidetrack, 1set of slip rams, 1 set of blind shear rams ,and a annular preventer. The tests were performed by pressuring between the BOPs and the master valve on the tree,this also pressured against the wing valve on the tree. After testing the blind shear and pipe rams a leak developed in either the master valve or the wing valve making it difficult to vedfy the pressure test on the choke and kill line valves. These tests were verified by opening valves to atmosphere downstream of the choke and kill line valves. Summary: ! witnessed the BOPE test on Camco's CUT on BPX's D-17 Well ~,scn,, ,eh,: sh9ka 1 dd.xls x Unclassified Confidential (Unclassified if doc. removed ) Confidential , STATE OF ALASKA OIL AN-, GAS CONSERVATION COMiliifSSiON BOPE Test Report Or'c,'~AT~ON. Drlg: ,g Con,factor: Operator: Well Name: Casing Size: Test: Initial Workover: Camco CTU Rig No. 985 PTD # BPX Rep.: D-17 Rig Rep.: 4.5 Set @ 9,045 Location: Sec. X Weekly Other DATE: 55/27/~6 96-48 Rig Ph.# Paul BaRe/ " 23 T. f f N R. f 3E Meridian Umiat , , , Test ' ~.~-,I~SC. iNSPECTiONS: Location Gen.' OK Housekeeping: OK (Gen) PTD On Location 'rES Standing Order Posted NO Well Sign NO Drl. Rig CTU Hazard Sec. BOP STAC}(: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F P 300/1000 NA NA ~ 500/4000 P ~ 500/4000 P 1 500/4000 P I 500/4000 P 2 500/4000 P NA MUD SYSTEM: Tdp Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector FLOOR SAFETY VALVES: Quart. Upper Kelly / IBOP NA Lower Kelly I IBOP ,",lA Ball Type NA Inside BOP Pressure P/F I i NA I t CHOKE MANIFOLD: No. Valves 5 No. Flanges Manual Chokes 2 Hydraulic Chokes NA Test Pressure 500/4000 500/4000 P P/F Visual Alarm minutes sec. minutes sec. Remote; ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: Psig. Number of Failures: 0 ,Test Time: 5.0 Hours, Number of valves tested 9 Repair or Replacement of Failed , Equipment will be made within days. Notify the Inspector and follow with Written or F~ed verification to the AOGCC Commission Office at: Fax No. 276-7542 inspecter North Slope Pager No. 659-3607 or 3687 lf,/our call is not returned by the inspector within 12 hours please contact the ~ I REMARKS: After testing pipe rams and blind rams a leak developed in either the master or win~ vane making it difficult to ve~, fl?,,e pressure test on the choke and kill line vanes, i i Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector FI-021L (Rev.12/94) STATE WITNESS REQUIRED? YES NO 24 HOUR NOTICE GIVEN YES x NO Waived By: V~rrtnessed By: AH9KE1DD.XLS Chuck Scheve ALASKA OIL GAS CONSERVATION COMMISSION TON~ KNOI/I/LE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 4, 1996 Ted Stagg, Coiled Tubing Ddlling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit D-17A BP Exploration (Alaska), Inc. Permit No 96-046 Surf Loc. 2100'SNL, 1692'WEL, Sec. 23, Tl lN, R13E, UM Btmhole Loc. 3756'SNL, 331'EWL, Sec. 23, TllN, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to re-ddll the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Bloweut 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 pdor to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. David W. Jq,hnston \ ~- ~ Chairman ~ / ~ BY ORDER OF T OMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section -w/o encl Dept of Environmental Conservation - w/o encl BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To~ Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Date: Feburary 27, 19! Attention' Blair Wondzell Subject: D-17A Permit to Drill Revisions A Permit to Drill application form 401 has been submitted for well D-17A. Please accept the enclosed revised BOPE sketches and the drilling program for this well. The estimated spud date for this well is March 12, 1996. If there are any questions please contact me at 564-5894. Thank you. Sincerely, Theresa Mills Coiled Tubing Technical Assistant 3 FEB 29 1996 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrillCIIlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenCII Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE=78.93 AMSL feet Prudhoe Bay Fie/d/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 028285 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAc 25.025) 2100' SNL, 1692' WEL, Sec. 23, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1141'NSL, 762' EWL, Sec 23, T11N D-17A 2S100302630-277 At total depth 9. Approximate spud date Amount 3756' SNL, 331'EWL, Sec. 23, T11N, R13E March 11,1996 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) t/ line prop L 28284 @ 331' feet no close approach feet 2560 10350 MD(8852TVDss) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.o35 (e)(2)) Kickoff depth a~so TVO feet Maximum hole angle 9o o Maximum surface 2500 psig At total depth (TVD) 8800Y3430 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3.75" 2 7/8" 6.16# L-80 FL-4S 1325 9025 7995 10,350 8852 70 c.f. 19. To be completed for Redrill, Re-entry, and Deepen Operations. F Present well condition summary Total depth: measured 10497 feet Plugs (measured) .AJa$~a Oil & Gas Cons. Commissior~ true vertical BKB9335 feet Anchorage Effective depth: measured 10398 feet Junk (measured) fi/lat 10398'MD(11/88) true vertical BKB 9249 feet Casing Length Size Cemented Measured depth True Vertical depth Structural BKB Conductor 110 20X30 8 c.y. 146 146 S u rfa ce 2668 13 3/8 3588 c.f. 2704 2704 I nte rmed late 9483 9 5/8 303 c.f. 9518 8488 Production Liner 1472 7 403 c.f 9011-10483 8062-9322 Perforation depth: measured 10052'-10069', 10074'-10090' Sqzd: 9980'-10038', 10090'-10110' true vertical 8875;8908'ss (two intervals) 8812;8863', 8908;8925'ss 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby c~,~foregoing is true and correct to the best of my knowledge --__ Signed Tit le Coiled Tubin~l Drillin~l En~lineer Date · Commission Use Only /' Permit Number APl number Approval d~te See cover letter ~'"-,/-7Z~'' 50-0'27-..~.O~,~._,-<:~)I ~,~/z./'//~,~ Ifor other requirements Conditions of approval Samples required [] Yes .J~ No Mud log requirea []Yes j~J'No Hydrogen sulfide measures .j~ Yes [] No D~rectional survey requ~re(~ t~ Yes [] No Required working pressure for B.OPE D,.,?.M; [~M; 1-15M; I-I10M; []15M; Other: uriglrlal ~51gnea By by order of ~_,/ Approved by 0avid W. Johnston Commissioner Form 10-401 Rev. 12-1-85 Submit in' plicate CREE: 6" CIW WELLHEAD: McEVOY ACTUATOR: OTIS D-17A Proposed CT Sideti k KB. ELEV = 78.93' BF. ELEV = 42.98' 13-3/8", 72#/ft, L-80, BTRS 12704'1 KOP: 2900' t MAX ANGLE: 40°/8600 FOC 5-1/2", 17#/ft, L-80, AB BTRS TUBING (IPC) TUBING ID: 4.892" CAPACITY:.0232 BBL/FT BOT Packer has communication between tailpipe and liner. Plug in nipple will not provide tubing integrity 7" LINER 901 1' 9-5/8", 47#/ft, 8~ L-80, BTRS I 951 I~ I'i I SSSV LANDING NIPPLE 998' OTIS )( 4.562" ID) GAS LIFT MANDRELS Pocket ( OTIS W/RA LATCH~ pos- N~ MD(BKB) TVDss tion* 12 3001' 2921' 11 5082' 4745' 12:00 10 6273' 5687' 8:00 9 6427' 5811' 4:00 8 6991' 6273' 2:30 7 7146' 6403' 6:00 ' 6 7541' 6742' 7:00 5 7697' 6878' 6:001 4 8021' 7166' 7:00 3 8168' 7298' 9:00 28598' 7654' 1~: :0300 1 8748' 7771' * 6:00 is Iow side of hole SLIDING SLEEVE OTIS "XA" (4.562" ID) TUBING SEAL ASSY. 9-5/8" PACKER ( BOT ) (4.750"1D) 18860' 1 8906' 1 8926' 41/2",12.6#/ft, L-80 TAILPIPE 41,2 X"NIPPLE .... I (OTIS) (3.813" iD) 9006' 4 1/2" TAILPIPE STUB 19045' D Proposed Whipstock = 9678' MD Top squeeze cement = 9930' MD PERFORATION SUMMARY REF LOG: SWS-BHCS- 3-28-82 INTERVAL OPEN/SQZ'D 9,980 - 10,030' 10,030 - 10,038' 10,052 - 10,069' 10,074 - 10,090' 10,090 - 10,110' SQZD/9-30-88 SQZD/6-2-95 OPEN/6-14-95 OPEN/6-14-95 SQZD/9-30-88 FISH 7/27/94: Tubing tail, "XN" Nipple with catcher sub and spear (in nipple). FISH (6/26/92): Three bowsprings, 25.5" x 0.5" PBTD 7", 26#/ft, L-80, IJ4S 11 n_4, n' I · %%%% % % % % I'REE: WELLHEAD: ACTUATOR: 6" CIW McEVOY OTIS D-17A Proposed Completi KB. ELEV = 78.93' BF. ELEV = 42.98' 13-3/8", 72#/ft, L-80, BTRS 12704'1 FOC KOP: 2900' MAX ANGLE: 40°/8600' 5-1/2", 17#/ft, L-80, AB BTRS TUBING (IPC) TUBING ID: 4.892" CAPACITY:.0232 BBL/FT BOT Packer has communication between tailpipe and liner. Plug in nipple will not provide tubing integrity 7" LINER 901 1' 9-5/8", 47#/ft, I L-80, BTRS 951 8' 2 7/8" Liner wi Top of Cement at approx. 9478' MD SSSV LANDING NIPPLE 11998' ( OTIS )( 4.562" ID) GAS LIFT MANDRELS Pocket f OTIS W/RA _ATCH~ pos- N~ MD(BKB) TVDss tion* 12 3001' 2921' 11 5082' 4745' 12:00 10 6273' 5687' 8:00 9 6427' 5811' 4:00 8 6991' 6273' 2:30 7 7146' 6403' 6:00 6 7541' 6742' 7:00 5 7697' 6878' 6:00 4 8021' 7166' 7:00 3 8168' 7298' 9:00 2 8598' 7654' 2:00 1 8748' 7771' 11:30 * 6:00 is Iow side of hole SLIDING SLEEVE [8860' OTIS "XA" (4.562" ID) TUBING SEAL ASSY. 18906' 9-5/8" PACKER I ( BOT ) (4,750"1D) 1 8926' 4 1/2", 12.6 #/ft, L-80 TAILPIPE 4 1/2 .... X" NIPPLE (OTIS) (3.813" ID) 19006' I 4 1/2" TAILPIPE STUB 19045' T: Proposed Whipstock = 9678' M Top squeeze cement = 9930' MD PERFORATION SUMMARY REF LOG: SWS - BHCS - 3-28-82 SIZE SPF INTERVAL OPEN/SQZ'D 3 1/8" 4 9,980- 10,030' SQZD/9-30-88 3 3/8" 4 10,030- 10,038' SQZD/6-2-95 3 3/8" 6 10,052- 10,069' OPEN/6-14-95 3 3/8" 6 10,074- 10,090' OPEN/6-14-95 3 1/8" 4 10,090 - 10,110' SQZD/9-30-88 FISH 7/27/94: Tubing tail, "XN" Nipple with catcher sub and spear (in nipple). FISH (6/26/92): Three bowsprings, 25.5" x 0.5" %%%% %''''%''''%'''' /' %/%/%/%/, //// %/%/%/%/' %%%% PBTD ~ 7", 26#/ft, L-80, IJ4S /%,,,,,'"/'%.,,%,/%/% % % % % % %"-- CTDM:2.3.2A ICoil Tubing BOPEI Blind/Shear Blind/Shear Pipe Rams Slip Rams I Pump-In Sub I BOP Stack Type A To be used for drilling wit h mud I S pacer Spools (as needed for Height) To Choke Manifold Mud Cross I Hydraulic Act uat ed ValveI Manual Valve I I Manual Swab Valve/ IManual ValveI Exist ing Flowline J I Hydraulic Act uat ed V~ I Manual Mast er Valve Manual Gas Cons. ~choraga Lift ~s In I (if applicable)l ," CT I~o,ooo psi Pack-Off Lubricator--~ I Blind/Shear Pipe Ram Slip Ram Pipe Ram D-17A CT Sidetrack BOP forCompletion Operations FEB 26 1996 Alas~ Oil & Gas Cons, Commission Anchorage 27/8" ~ 23/8" BP Exploration (Alaska) Coiled Tubing Drilling & Liner Running Proposed Wellhead/BOPE Configuration I -3,800 ;3,600 I -3,400 D-17 Plan View I -3,200 -3,000 X distance from Sfc Loc -2,800 -2,600 -2 -1,200 -1,400 -1,600 -1,800 -2,000 -2,200 -2,400 -2,600 IWellName D-17 CLOSURE Distance 3,652 ft I Az ~.42 deg NEW HOLE Kick Off TD State Plane E/W (X) -2,799 -3r220 650r251 Surface Loc 653,471 5,958,888 N/S <Y)I '2'104I -1:722I 5r957r1661 Az Ch¢ MD (ft) 12.0 150 15.0 282 3.0 200 0.0 140 0.0 450 0.0 I Curve 1 curve 2 Curve 3 Curve 4 curve 5 curve 6 1,223 Drawn: 2/1 9~96 20:45 Plan Name: Case I D-17 Vertical Section 8500 8520 8540 8560 0 200 400 I. I Angle @ K.O.= 29 deg MD:9678 Path Distance (Feet) 600 800 1,000 1,200 1,400 I I I I I ,TSAD.~- ......... ~ ..........................---~.~,, 858O 8600 DL 1= 11 deg/lO0 862O 864O 8660 8680 8700 8720 8740 876O 14 de,3 DL 2= 31 deg/100 ,TopZ~ ..................... 878O 8800 8820 8840 8860 8880 8900 8920 --8,905 10901 TD Tot Drld:1223 ft Marker Depths @Orig Wellbore TSAD I 8,5161ft TVD TopZ3 TopZ2 J 8,7221ft TVD I 8,7841ft TVD s,9o51 e,e371ft TVD Kick Off J 8,550]ft TVD 9~678]ft MD Deprtr @ KO 3~ 516 f t MD KO Pt 9,678] MD New Hole 1223I I Total MD 10~9011 TVD TD 8=9051 Build Rt decjll O0 MD (ft) o.o 27.0 282 0,0 200 -4.0 1 40 0.1 450 0.1 I Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 Curve 6 1,223 Drawn: 2/1 9/96 20:45 Plan Name: Case I BPX D-17A Sidetrack Summary of Operations: Well D-17 is currently shut-in due to high TGOR. The well is being sidetracked to achieve lower GOR production. This sidetrack will be conducted in two phases. Phase 1: Cut Window: Planned for March 3 - 10, 1996. - The existing Ivishak perforations will be cement squeezed. - A whipstock will be set on ELine at approximately 9678' MD. - Utilizing a conventional coil tubing unit, a window will be cut in the 7" liner and 10 ft of formation will be ddlled. Phase 2: Drill Directional Hole: Planned for March 11 - 23, 1996. - Directional drilling coil tubing equipment will be dgged up and utilized to ddll the directional hole as per attached plan to planned TD of 10,350' MD (8,852' TVDss). Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 2 7/8", 6.16#, L-80, FL-4S liner will be run from TD to approx. 9025' MD and cemented with approx. 70 cu. ft. cement. The well will then be perforated with coil tubing conveyed guns. Well Control: See attachments. Phase 1, window milling, will utilize "Type B" BOP system shown in the attached diagram. Drilling operations will utilize the fully lubricated system shown in the attached diagram. -The production liner will be run using the 4-ram and annular preventer system shown in the attached diagram. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 9678' MD (8550' TVD ss) - TD: 10,350' MD (8,852' TVD ss) - Magnetic and inclin, ation surveys will be taken every 25 ft. No gyro will be run. LoAgging - Gamma Ray Icg will be run over all of the open hole section. - A Gamma Ray /Induction Icg is tentatively scheduled. i:t!',B ?. 9 ]996 STATE OF ALASKA .~ AL _,KA OIL AND GAS CONSERVATION COMMIS .... q ' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Operation 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. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2100' SNL, 1692' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval 1141'NSL, 762' EWL, SEC. 23, T11N, R13E, UPM At effective depth 983'NSL, 413'EWL, SEC. 23, T11N, R13E, UPM At total depth 963'NSL, 369'EWL, SEC. 23, T11N, R13E, UPM 12. Present well condition summary Total depth: 5. Type of Well: Development Exploratory Stratigraphic Service measured 10497 feet true vertical BKB 9335 feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 78.93 AMSL 7. Unit or Property name Prudhoe Bay Unit 8. Well number 0-17 9. Permit number 81-185 10. APl number 5O- O29-2O692 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 10398 feet true vertical BKB 9249 feet Junk (measured) fill at 10398' MD (11/88) Casing Length Size Structural -- Conductor 110 20x30 S u rfac e 2668 13 3/8 Intermediate 9483 9 5/8 Production -- Liner 1472 7 Perforation depth: measured 10052'- 10069', 10074'- 10090' Cemented 8 c.y. 3588 c.f. 303 c.f. 403 c.L Measured depth True vertical depth BKB 146 146 27O4 27O4 9518 8488 9011-10483 8062-9322 Sqz~ 9980510038~ 10090510110' true vertical 8875'-8908'ss (two intervals) Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8926' with 4 1/2" raj/pipe to 9045' FEB 26 1996 Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 8926'; 5 1/2" SSSVat 19~ Oil & Gas Cons. Commission Anchorage feet 13. A~achments Description summary of proposal X Detailed operations program BOP sketch _X.--- 14. Estimated date for commencing operation March 3, 1996 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~~./~¢~~ Title Coiled Tubing Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance__ Mechanical Integrity Test Subsequent. fo_.r.m reclu~ed 10- J¢:~7 -- Original ignea y David W. JohnSton Approved by order of the Commission / Approval No, ~?~. 0~0 Approved C,~py Returoed Commissioner Date ~/~'7/~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE : LL PERMIT CHECKLIST INIT CLASS ~2~¢-" /~7 GEOL AREA PROGRAM, exp [] dev~ UNIT# redrll~ serv [] well ON/OFF SHORE ('Sd ADMINISTRATION 1. 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 drlg unit boundary.. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drillin9 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 ....... ENGINEERING APPR DATE 14. Conductor strin9 provided ............... YtY \ N 15. Surface casing protects all known USDWs ......... .~~ N 16. CMT vol adequate to circulate on conductor & surf cs9. N 17. CMT vol adequate to tie-in long string to surf csg . . N 18. CMT will cover all known productive horizons ...... N 19. Casing designs adequate for C, T, B & permafrost .... N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved.~ N 22. Adequate wellbore separation proposed .......... O N 23. If diverter required, is it adequate ........... ~~ 24. Drillin9 fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... $ N 26. BOPE press rating adequate; test to psi9. Y N 27. Choke manifold complies w/API RP-53 (May 84) ...... ¢t~ N 28. Work will occur without operation shutdown ....... ~M~' N 29. Is presence of H2S gas probable ............ ~3 N REMARKS GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y Data presented on potential overpressure zones ..... Y 32.31. Seismic analysis of shallow gas zones .......... ~N · N / - '; ' 33 Seabed condition survey (if off-shore) ........ /Y N ' 34. Contact name/phone for weekly progress reports . . . // . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ JDN Comments/Instructions: HOW/Ijb- A:\FORMS\cheklist rev 11195 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . * · ALASKA COMPUTING CENTER * . * ****************************** . ............................ * · ....... SCHLUMBERGER ....... * · ............................ * ****************************** COMPANY NAME : BP EXPLORATION WELL NAME : D- 17A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20692-01 REFERENCE NO : 96236 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-AUG-1996 09:24 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/08/30 ORIGIN · FLIC REEL NAME : 96236 CONTINUATION # : PREVIOUS REEL : COf4MENT ' B.P. EXPLORATION, PRUDHOE BAY D-17A, API #50-029-20692-01 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE : 96/08/30 ORIGIN : FLIC TAPE NAME : 96236 CONTINUATION # : 1 PREVIOUS TAPE : COMFIEAUf : B.P. EXPLORATION, PRUDHOE BAY D-17A, API #50-029-20692-01 TAPE HEADER PRUDHOE BAY MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING D-17A 500292069201 BP EXPLORATION SCHLUMBERGER WELL SERVICES 29-AUG-96 BIT RUN 1 ......... 9623 6 TZVETCOFF MILVAN BIT RUN 2 BIT RUN 3 23 liN 13E 2100 1692 78.90 78.90 43. O0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 10483. LIS Tape ~=~fication Listing Schlumberger Alaska Computing Center 30-AUG-1996 09:24 3RD STRING PRODUCTION STRING REMARKS: SLIM1 GR data logged 27-MAY-96 to il-JUN-96 while using Coiled Tubing Drilling. Ail bit runs merged into one file in the field, so presented as one file. No depth shifts applied as per Greg Bernaski. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArOMBER: 1 EDITEDMERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREME2FT: 0.5000 FILE SO?4MARY LDWG TOOL CODE START DEPTH STOP DEPTH ~ 9683.0 11320.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: SLIM1 GR data logged while Coiled Tubing Drilling. No depth shifts were applied as per Greg Bernaski. GR and ROPE data interpolated at AK ICS. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD BIT RUN NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape P=~ification Listing Schlumberger Alaska Computing Center 30-AUG-1996 09:24 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT NA O0 000 O0 0 1 1 1 4 68 0000000000 GRRWMWD AAPI NA O0 000 O0 0 1 1 1 4 68 0000000000 GRIN MWD AAPI NA O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHRNA O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11320.000 GRRW. MWD -999.250 GRIN. MWD 0.213 ROP.MWD DEPT. 11250.000 GRRW. MWD 10.930 GRIN. MWD 10.930 ROP.MWD DEPT. 11000.000 GRRW.MWD 11.400 GRIN.MWD 11.400 ROP.MWD DEPT. 10750.000 GRRW. MWD -999.250 GRIN. MWD 14.646 ROP.MWD DEPT. 10500.000 GRRW. MWD 15.400 GRIN. MWD 15.400 ROP.MWD DEPT. 10250.000 GRRW. MWD 47.030 GRIN. MWD 47.030 ROP.MWD 42.100 28.400 43.300 34.800 46.900 34.700 DEPT. 10000.000 GRRW. MWD 13.780 GRIN.MWD 13.780 ROP.MWD 22.100 LIS Tape ~=rification Listing Schlumberger Alaska Computing Center DEPT. 9750.000 GRRW.MWD DEPT. 9683.000 GRRW.MWD 30-AUG-1996 09:24 -999.250 GRIN. MWD 38.840 GRIN.MWD 18.688 38.840 ROP. MWD ROP. MWD PAGE: 33.300 1603.700 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 9683.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME) TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) STOP DEPTH 11320.0 11 -JUN-96 MEMORY 11320.0 9683.0 11320.0 0.0 LIS Tape ¥~ification Listing Schlumberger Alaska Computing Center 30-AUG-1996 09:24 PAGE: MINIMUM ANGLE: MAXIMUM ANGLE: 28.5 97.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SLIM1 GR $ TOOL NUMBER SLIM1-25 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 3. 750 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): FLO PRO 8.8 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: SLIM1 GR data obtained during Coiled Tubing Drilling. GR.INT and ROPS.INT data interpolated from field data at AK ICS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 LIS Tape ¥=~ification Listing Schlumberger Alaska Computing Center 30-AUG-1996 09:24 PAGE: 6 TYPE REPR CODE VALUE 6 73 7 65 8 68 O. 5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT NA O0 000 O0 0 2 1 1 4 68 0000000000 GR RAW CPS NA O0 000 O0 0 2 1 1 4 68 0000000000 GR MWD AAPI NA O0 000 O0 0 2 1 1 4 68 0000000000 GR INT AAPI NA O0 000 O0 0 2 1 1 4 68 0000000000 ROP MWD F/HR NA O0 000 O0 0 2 1 1 4 68 0000000000 ROP5MWD F/HRNA O0 000 O0 0 2 1 1 4 68 0000000000 ROP5 INT F/HR NA O0 000 O0 0 2 1 1 4 68 0000000000 VDEPMWD FT NA O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11320.000 GR.RAW -999.250 GR.MWD -999.250 GR.INT 0.213 ROP.MWD 108.400 ROPS.MWD 42.100 ROPS.INT 42.100 VDEP.MWD 8930.900 DEPT. 11250.000 GR.RAW ROP.MWD 36.000 ROPS.MWD 10.900 GR.MWD 28.400 ROPS.INT 10.930 GR.INT 10.930 28.400 VDEP.MWD 8905.100 DEPT. 11000.000 GR.RAW ROP.MWD 40.300 ROPS.MWD 11.400 GR.MWD 43.300 ROPS.INT 11.400 GR.INT 11.400 43.300 VDEP.MWD 8893.900 DEPT. ROP.MWD 10750.000 GR.RAW -999.250 GR.MWD -999.250 GR.INT 14.646 52.600 ROPS.MWD 34.800 ROPS.INT 34.800 VDEP.MWD 8892.801 DEPT. 10500.000 GR.RAW 11.400 GR.MWD ROP.MWD 63.400 ROP5.MWD 46.900 ROP5.INT 15.400 GR.INT 15.400 46.900 VDEP.MWD 8883.900 DEPT. 10250.000 GR.RAW ROP.MWD 59.300 ROPS.MWD 47.000 GR.MWD 34.700 ROPS.INT 47.030 GR.INT 47.030 34.700 VDEP.MWD 8850.000 LIS Tape 9=~ ,fication Listing Schlumberger Alaska Computing Center 30-AUG-1996 09:24 PAGE: DEPT. 10000.000 GR.RAW ROP.MWD 10.400 ROP5.MWD DEPT. 9750.000 GR.RAW ROP.MWD 30.300 ROPS.MWD DEPT. 9683.000 GR.RAW ROP.MWD 1597.000 ROPS.MWD 13.800 GR.MWD 22.100 ROPS.INT -999.250 GR.MWD 33.300 ROPS.INT 38.800 GR.MWD 1603.700 ROP5.INT 13.780 22.100 -999.250 33.300 38.840 1603.700 GR.INT VDEP.MWD GR.INT VDEP.MWD GR.INT VDEP.MWD 13.780 8793.701 18.688 8608.900 38.840 8554.100 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE · 96/08/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAM~ : EDIT DATE : 96/08/30 ORIGIN : FLIC TAPE NAME : 96236 CONTINUATION # : 1 PREVIOUS TAPE : COI~4ENT : B.P. EXPLORATION, PRUDHOE BAY D-17A, API #50-029-20692-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/08/30 ORIGIN : FLIC REEL NAME : 96236 CONTINUATION # : PREVIOUS REEL : COR~4ENT : B.P. EXPLORATION, PRUDHOE BAY D-17A, API #50-029-20692-01 PRUDHO'E ~ WE~ERN ATLAS Logging Services RECEIVED i dUL 1 9 1996 Alaska Oil & Gas Cons. Commission An~orage ~ubfile 2 'is typ.~-~ LIS ~--~, TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NU]MBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6702.00 BRAD ESARY SEE REMARKS REMARKS: OPEN HOLE D - 17A 500292069201 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 10-JUL-96 RUN 2 RUN 3 23 liN 13E 2101 1692 78.93 77.93 41.50 IEL/CN/GR. LOGS WITNESSED BY: RIC WHITLOW & MIKE MARTIN. LOGS TIED TO BHCS DATED 28-MAR-82. CIRC~TION STOPPED @ 13:00, il-JUNE-96. LOGS WERE COILED TUBING CONVEYED, DOWELL UNIT 1. CHLORIDES: 38000 MG/L. DRILLING REPORT SHOWS WINDOW CUT FROM 9672' TO 9678', RA TAG AT 9676', AND PILOT HOLE TO 9689'. COIL UNIT CIRCULATED 0.2 BBL/MIN WHILE LOGGING. REPEAT PASS SET DOWN AT 11192'. APPLIED 75% OF RECOMMENDED MAXI~ COMPRESSION WEIGHT ON TOOL STRING (1500 LBS) SEVERAL TIMES PRIOR TO LOGGING UP. MAIN PASS WENT TO TD AFTER APPLYING MAXIMUM COMPRESSION WEIGHT ON TOOL STRING (2000 LBS) AT 11192' SEVERAL TIMES. GAMMA RAY ABOVE 10097' READS HIGHER THAN REPEAT PASS. IT APPEARS GAMMA RAY IN-HOLE READINGS WERE AFFECTED BY CONDUCTOR LEAKAGE AT DOWELL/WESTERN ATLAS HEAD CONNECTION BEING INVADED BY FLO-PRO MUD SYSTEM. GAMMA RAY AFTERLOG VERIFICATIONS WERE PERFORMED AFTER COIL TUBING HEADSUB CONDUCTOR LEAKAGE WAS CLEARED UP. 7.000 9678.0 3.750 11320.0 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) NEUTRON ~G PARAMETERS: SANDSTONE tRiX, BOREHOLE CORRECTION = 3 750" · CHISM FILTERING OFF, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. RACHAEL MAYS (BP) CONFIRMED THAT THIS LOG IS DEPTH REFERENCE FOR THIS WELL VIA E-MAIL ON 08-JUL-96. .~E HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR IEL 2418 $ depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 9682.0 11302.0 9682.0 11327.0 9682.0 11310.0 GR (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA BASELINE DEPTH RT 9700.0 9700.5 9707.0 9707.0 9712.0 9711.5 9723.5 9723.5 9727.0 9727.0 9729.5 9729.5 9750.0 9750.0 9751.5 9752.0 9760.0 9759.5 9778.5 9779.0 9805.0 9805.0 9809.5 9810.0 9812.0 9812.5 9815.0 9815.5 9816.0 9816.0 9828.5 9828.5 9834.0 9833.5 9833.5 9838.0 9837.5 9865.0 9865.0 9876.5 9875.5 9877.0 9876.5 9886.0 9885.5 9890.0 9890.0 9893.0 9892.5 9917.5 9917.0 9917.0 9931.0 9931.0 9991.5 9991.5 9994.5 9994.5 9999.0 9998.0 9999.5 9999.0 10002.5 10002.0 10009.0 10009.0 10009.5 10010.5 10011.5 10014.5 10014.0 10051.5 10051.0 10057.5 10057.0 10075.5 10075.5 10075.0 10086.0 10086.0 10106.5 10106.5 10126.0 10125.0 10144.0 10144.0 all runs merged; EQUIVALENT UNSHIFTED DEPTH NPHI no case 10 10 10 10 10 10 10 107 107 110 111 111 111 112 $ ~52 10180 10192 10227 10262 10276 10276.5 10283.5 10284.0 10315.0 10344.0 10421.5 10428.0 10432.5 10435.5 10436.0 10438.5 10458.0 485.5 511.0 513.0 516.5 539.0 545.0 610.0 53.5 66.5 07.5 04.5 94.0 95.0 28.0 .5 ~ .0 10. 3.0 .0 .0 .5 .0 10276.5 10283.0 10315.0 10344.5 10428.5 10436.0 10458.0 10510.5 10516.0 10539.0 11008.0 11104.5 11195.0 11228.0 MERGED DATA SOURCE PBU TOOL CODE GR IEL 2418 $ REMARKS: 10152.0 10192.0 10227.0 10262.5 10277.0 10284.5 10421.5 10428.5 10433.0 10436.5 10439.0 10485.5 10512.5 10545.5 10610.0 10754.0 10766.5 11194.0 RIINNO. PASS NO. MERGE TOP 1 7 9682.0 1 7 9682.0 1 7 9682.0 OPEN HOLE portion of MAIN PASS. SN, SP, TEND, & TENS WERE SHIFTED WITH RT. FUCT & NUCT WERE SHIFTED WITH NPHI. MERGE BASE 11302.0 11327.0 11310.0 /? ?MATCH1. OUT / ? ? MATCH2. OUT $ (IN : BP EXPLORATION WN : D-17A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME (ALASKA) depth ID: ·F ,~ -- 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR IEL 68 1 GAPI 4 2 RT IEL 68 1 OHMM 4 3 SN IEL 68 1 OHMM 4 4 SP IEL 68 1 MV 4 5 TEND IEL 68 1 LB 4 6 TENS IEL 68 1 LB 4 7 NPHI 2418 68 1 PU-S 4 8 FUCT 2418 68 1 CPS 4 9 NUCT 2418 68 1 CPS 4 4 05 310 01 1 4 05 995 99 1 4 05 995 99 1 4 05 995 99 1 4 05 995 99 1 4 05 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 132 Tape File Start Depth = 11330.000000 Tape File End Depth = 9682.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 32971 datums Tape Subfile: 2 315 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes ~pe Subfile 3 is type: IS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casin9. PASS NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 9500.0 2418 9500.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9535.0 9542.5 9557.5 9573.0 9576.5 9600.5 9615.0 9616.5 9629.0 9630.5 9634.5 9637.0 9653.0 9672.0 $ REMARKS: NPHI 9535.0 9541.5 9557.5 9573.0 9576.5 9600.5 9614.5 9616.5 9629.0 9631.0 9635.0 9637.5 9653.0 9672.0 STOP DEPTH 9682.0 9682.0 EQUIVALENT UNSHIFTED DEPTH CASED HOLE portion of MAIN PASS. FUCT, NUCT, TEND, & TENS WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH3. OUT $ : BP EXPLORATION (ALASKA) : D-17A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API LoG Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 6~ 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 5 TEND 2418 68 1 LB 4 6 TENS 2418 68 1 LB 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 11 42 310 01 4 42 995 99 4 42 995 99 4 42 995 99 4 42 995 99 4 42 995 99 24 Tape File Start Depth = 9682.000000 Tape File End Depth = 9490.000000 Tape File Level Spacin9 = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2696 datums Tape Subfile: 3 55 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes ~ape Subfile 4 is type: IS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass toOl strings per run. RUN ~ER: 1 1 7 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9500 . 0 11302 . 5 IEL 9676 . 0 11327.0 2418 9500 . 0 11310 . 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIR~TION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT CORR KNJT GR KNJT IEL $ CABLEHEAD TENSION CORRELATION SUB DOUBLE KNUCKLE JOINT GAMMA RAY COMPENSATED NEUTRON DOUBLE KNUCKLE JOINT INDUCTION ELECTROLOG 13-JUN-96 FSYS REV. J001 VER. 1.1 1300 il-JUN-96 304 13-JUN-96 11320.0 11333.0 9500.0 11327.0 2100.0 TOOL NUMBER 3977XB 3965XA 1310XA 2418XA 811XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : 3.750 9678.0 9682.0 BORE~{OLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OPIMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MI/D AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT MT: FLO-PRO 8.85 10.0 9.0 5.1 .0 .156 .000 .000 72.4 .0 .0 MUD FiLTRaTE f .... BHT: MUD CAKE AT M'~ MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : D-17A : PRUDHOE BAY : NORTH SLOPE : ALASKA 000 .000 .000 THERMAL SANDSTONE .00 3.750 .0 .0 ,0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR IEL 68 1 GAPI 4 2 RTLG IEL 68 1 OHMM 4 3 SNLG IEL 68 1 OHMM 4 4 COND IEL 68 1 MMHO 4 5 SP IEL 68 1 MV 4 6 CHT IEL 68 1 LB 4 7 TTEN IEL 68 1 LB 4 8 TEN IEL 68 1 LB 4 9 SPD IEL 68 1 F/MN 4 10 CNC 2418 68 1 PU-S 4 11 CN 2418 68 1 PU-L 4 12 LSN 2418 68 1 CPS 4 13 SSN 2418 68 1 CPS 4 4 05 310 01 1 4 05 120 46 1 4 05 040 16 1 4 05 110 46 1 4 05 010 01 1 4 05 635 99 1 4 05 635 99 1 4 05 635 99 1 4 05 636 99 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 409 Tape File Start Depth = 11330.000000 Tape File End Depth = 9490.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** ~IS representation code ~ecoding summary: Rep Code: 68 136026 datums Tape Subfile: 4 485 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes · ape Subfile 5 is type. -,IS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 5 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9500 . 0 11161.5 IEL 9673 . 0 11186 . 0 2418 9500.0 11170.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 13-JUN-96 FSYS REV. J001 VER. 1.1 1300 il-JUN-96 131 13-JUN-96 11320.0 11333.0 9500.0 11327.0 2100.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT CORR KNJT GR CN KNJT IEL $ CABLEHEAD TENSION CORRELATION SUB DOUBLE KNUCKLE JOINT GAMMA RAY COMPENSATED NEUTRON DOUBLE KNUCKLE JOINT INDUCTION ELECTROLOG TOOL NUMBER 3977XB 3965XA 1310XA 2418XA 811XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 3.750 9678.0 9682.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: FLO - PRO 8.85 10.0 9.0 5.1 .0 .156 .000 .000 .000 .000 72.4 .0 .0 .0 .0 MUD CAKE AT P'"~': .... 000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : D-17A : PRUDHOE BAY : NORTH SLOPE : ALASKA THERMAL SANDSTONE .00 3.750 .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR IEL 68 1 GAPI 4 2 RTLG IEL 68 1 OHMM 4 3 SNLG IEL 68 1 OHMM 4 4 COND IEL 68 1 MMHO 4 5 SP IEL 68 1 MV 4 6 CHT IEL 68 1 LB 4 7 TTEN IEL 68 1 LB 4 8 TEN IEL 68 1 LB 4 9 SPD IEL 68 1 F/MN 4 10 CNC 2418 68 1 PU-S 4 11 CN 2418 68 1 PU-L 4 12 LSN 2418 68 1 CPS 4 13 SSN 2418 68 1 CPS 4 4 05 310 01 1 4 05 120 46 1 4 05 040 16 1 4 05 110 46 1 4 05 010 01 1 4 05 635 99 1 4 05 635 99 1 4 05 635 99 1 4 05 636 99 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 377 Tape File Start Depth = 11189.000000 Tape File End Depth = 9493.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: ~ep Code: 68 97~, datums Tape Subfile: 5 451 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes l~ape Subfile 6 is type..,IS 96/ 7/10 01 **** REEL TRAILER **** 96/ 7/10 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 10 JLY 96 3:09p Elapsed execution time = 3.62 seconds. SYSTEM RETURN CODE = 0