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186-113
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THE STA Alaska Oil and Gs ►'z—� � of K� Conservation Commissidn _ rill 1�j\ 333 West Seventh Avenue Anchorage, Alaska 99501-3572 lieZ GOVERNOR BILL WALKER\TR'r Main: 907.279.1433 °F ALAs'�1` Fax: 907.276.7 42 www.aogcc.alaska.gov Michael Hibbert WIM Wells Interventions Engineer x -,} BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y-24 Permit to Drill Number: 186-113 Sundry Number: 318-176 Dear Mr. Hibbert: Enclosed is thea roved application for sundry approval relating to the above referenced well. pp Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of May, 2018. 11\0,1 0% RECE1VErD ' STATE OF ALASKA ' • ALASKA OIL AND GAS CONSERVATION C SSION 5 11- (I Cs' APPLICATION FOR SUNDRY APPALS APR 19 2018 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 • Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Changd ApproverOrogram ❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other IA Cement Squeeze 01 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 186-113 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service 0' 6. API Number: 50-029-21608-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? -- Will planned perforations require a spacing exception? Yes 0 No 0 PBU Y-24 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028287&047471 • PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY t Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): it 13550 . 9207 13508 9175 None 13400,13410,13432,13434 Casing Length Size MD TVD Burst Collapse Structural Conductor 77 20" 43-120 43-120 Surface 3011 13-3/8" 42-3053 42-2672 5380 2670 Intermediate 13099 9-5/8" 40-13138 40-8889 6870 4760 Scab Liner 2629 7" 3171-5800 2743-4294 7240 5410 Liner 681 7" 12869-13550 8689-9207 7240/8160 5410/7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 13138-13364 8889-9063 3-1/2",9.3#x 3-1/2",9.2#x 2-7/8" L-80 38-12927 Packers and SSSV Type: 3-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and ND(ft): 12520/8433 3-1/2"TIW Packer 12795/8634 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service O 14.Estimated Date for Commencing Operations: May 15,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 • GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert,Michael be deviated from without prior written approval. Contact Email: Michael.Hibbert@BP.com Authorized Name: Hibbert,Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interventions Engineer Authorized Signature: \ \ Date: q//8/IP) COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 I Plug Integrity 0 BOP Test 0 Mechanical Integrity Test I/ Location Clearance 0 Other: o 6a M 1 4k d TI n.4 i TT" 4 5 11,-,.et k ca -al poStj ✓V1 T 1�FL cis-_ i� dIcA--h< ol Post Initial Injection MIT Req'd?/ Yes No 0 1.-- B I��� ' n i T 7- iviL rt / co 31- Spacing / Spacing Exception Required? Yes 0 No Pe Subsequent Form Required: I Q — 4 171- 46_0, 1" Y '• APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: 11-4 ile_„) C f}� VTI 572/ls /b raCJ'�� RBDMSMAY 0 8 2016 `�A� �� ORIGINAL v" ,Ala Submit Form and plicat Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Due bp S Well: Y-24 Y-24 IA Cement Job Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Travis Alatalo (907) 564-5351 History Y-24 is a produced water injector that has a tubing by inner annulus leak @ 10,106'. Multiple attempts have been made to patch the leak but have been unsuccessful. The proposed plan forward is to place cement into the IA to fix the tubing by inner annulus leak @ 10,106'. The proposed cement will be brought up -8000' MD to cover the tubing leak. Current Status ➢ The well is currently classified as "Not-Operable" by BP due to tubing by inner annulus leak. The well is currently shut-in until the leaks are repaired. The OA has no known integrity related issues. Surface Casing Shoe is at 3,053' MD and 2,670' TVD.. The Cretaceous stratigraphy in this well is 1944' TVD to 5775' TVD (2104' MD to 8553' MD). Top of UG4 is at 4000' TVD and 5475' MD. The new proposed TOC will be -2500' MD below the UG4 top and 2850' TVD below the surface casing shoe. Economics Well Y-24 was found to have a tubing leak at 10,106' MD and has been shut-in since 2016. By repairi g this well with an IA cement squeeze, it is estimated that an incremental 180 mbo can be produced over the next several years. Without an IA remedial squeeze, the well has no utility in the foreseeable futur;. LN cOd Cd• Ale yf�°.i/4' Objective This cement job is to repair a tubing by inner annulus leak © 10,106' MD and regain operability of the well. Cement will be circulated down CT and up the IA. The proposed cement top in the IA is @ 8000' MD and 5,538' TVD. Post-Job Evaluation ➢ MITIA and MITT to maximum anticipated injection pressure ➢ SCMT to confirm Top of Cement (TOC) ➢ Water Flow Log to verify no flow behind pipe Long-Term Integrity Monitoring ➢ Record WHPs and Injection rate daily ➢ 2-year (biennial) MITTs and MITIAs to maximum anticipated injection pressure. ➢ 2-year (biennial) waterflow log 1 ----, . S • Current Schematic TFEE= 3-147 MCEVOY I WELLI-E70- MCEVOY ACTLA I Y-24 ON MI SAFETY NOTES H2S REAM=AVERAGE 125 ppm 111434 'WELL REQUIRES A SSSV WHEN ON MI-"" IIOR- OM; • 0003.E3_131= 8885'; ) I ;TY(11/30701ABOVE }LIST 339FOR PI ( F111;_JOI 338JI4TS REMAIN). SSSVN 3F MEV= 51.35'I -1.--.-- MOM SEWN-OVERSHOT REfi_EDT GAL PER 1021157071 8.CP- 1059 k_cr CONDUCTOR - rn. LAST TD e 13434'WA ir OD CENTRAL1284-03427/ 0. 0 Ikkoz Ar raia= 58"1,,6009 I. ? ,Datum I.Ci= 13138 202r H 3-1,12'HES XDB SSSVN,C=2 77 'Datum TVD= 8,803 SS' •, -,,,-, -.-. '',',•• "•:,N't1,!..., 1' . :4'- 1 3o6,*-1' FP 04:r SCAB THR -I 3111" I 3174" --102-5,2"x 7"BXR ZXP TER 4 1-113R,D=8.31• e g r SCAB MR,28t*,L-80. 0383 bp'.ID=8.276' HIsar • Minimum ID = 111" 6 10083' -10120' 3-1/2"WFD ONE TRIP PATCH g a I a r mauls) 100133'-101201-3-1.2"WED SFECIAL CLEARANCE 1MDEPAK CAL-TRIP PA TO1 ID= - 1ESTPAA TED TOP OF 03,ENT(01/2901 0) - 12302" I ' !al i'?„4:1 , . ITUI317*PUNCH(02113110) I-I 12450'-12452'' WE 10•41 ---1 12466. . 13-142'FES X MP,ID=177 I 11 1 I 84 4.4 144 141 114 . 4.4 101 124921-..---PkR 1040 FUR ID=2.951 AP-I A1• '"11 12506' -0-548.X 3-112'BKR 5-3 FKR,ID=3.875* P,M4 PM f 3112-111G,9 2a,L an hiSCI, -12610' TO 1 * 43 1.$2°Its XN MP,MILLED Z14"OMAIM2102) 0087 big,ID=2 997 , L 2566. ,. , 13-112-1150 STUB(11/28101)1.-1 12623' I 12618' HUMQUE CUSTOM OVERSI-OT Ll?rfT SWAT/1(07128(10/H 12700"-12905'cimi %SI vis 17743- . 3-141'DIE SLOP SOL 10=2.MO* M1.4 II I ra VA 1,..A IAA 4 artw • Ili WO A.4 UK I Dili PALKA.41 M K 10M411 .4 Kli , 3-in.TEIG,9.947,L-80,.0087 bpf,ID=2.992' - 127W ,c,,,a. kr•-• '-,i 's--24'r l_fiTii i 2 I-tt:tiI3"i6:16-iisil re* 40'49 ••. '4'r:Ai 0 ' ' 12260 ••• ••••• ••• " 1-42-7/6'OTE X MR al r,2.313"1 **. lalte• ' 0,6•4„,* r•• ••• ••• r•• 4*. ••• ••• PIA A ' i.tiCit I.•'•,, , 12860" j--19 578.X r 1301,-1414 TER w 4 TIEBACK ID.:71 11.IV ir,„4.,, I le .:1;1•• rt 112893' -12 II4V OTE X MP,ID le 2 313' 12 Mr MG,13.440,L OD,.9058 hpf El•rn 2.441" H 12927' tilli• ow 09 X •• r* 9-5/9'CSG,VIC 1-94 WTI,fa=8.581" -1 13136' .40.- •, 1292r -1,7fir rdLEG,13 rr 2.441'i ..ir 12894j--1ELIA3 TT LOGGED ON XX/XXIXX FECG%TICE SMEARY , 144.I (X SAG 11142,ON 07717 ANGLE AT TOPE43;IF 47 0 13138' I Note:Wier to Producbor Co for hisborical pert data 13164' -I r MARKER Joifr SIZE SEE NTERVAL OpetSqz SHOT SOZ 6 13138-13153 0 0119E9 I 13400" FISH-MILLED FA SCITILL 044364101 1 7-1/8' 4 13252-13354 0 0941(4813 '7 I-LASH-WRP a EMENT t06417.137) 414378 1 rn t 2-I 1O X 0"runt-a.)4,BuLaiRE-1 • C_INTRAi 0.1-N 594G 4*LNR,208 L 89 LMS, 1338:1 trpl,1.)-6.2/6" -13433' . . X0 r I NR,294 13434' J---1_F_Ett 34'X 2-1,1r FERE GUN,&CCL TOP r pe---.T-ID __I 13508" 4.44.1.1.444 7"LNR,2 ,L-80 BTRS„ 0371 I:40.D.,,6184: -r 13660' - a•a r 4444 4 ...... DATE REV BY CONVENTS DATE REV BY CCASIENTS EIRUCIHDE BAY UNIT 8719186 AUDI 2 INITIAL COMPLETION 1737416 G.1137,184)FULLED FKR&PATCH(0,003716) %NULL. Y 24 1E04701 D-15 tRINO 71%16 SET WED 04E TRIP PA TM(0147571S1 PERMT F45'1861130 _ 0311E15 STRP,./C RLL PATCH ARM) 50 029,21608 00 03,31(15 8?M P ILEL FESTRICTION•1".12500' _ SEC 34,T11N,R13E 1349 E14-,83 FWL 0410615 JON P PA SET STRADDLE PATCH 0B,136t 15,ILS!WC SET WA)PACKER -@ 10085' BP Exploration(Alaska). ,.. 2 • • Post IA Cement Job III 1 TREE= 3-Vir MOEVOY WELLKAD- MCEVOY' Y-24 SAFETY NOTE&/42S READINGS AVERAGE 125 ppm W143S1 ON NII•"".WELL REQUIRES A SSSV WHEN OMNI**3-112- IAC11A101.1- OT51 OKB,ELEV= 8&86i IT , 1 momTALLY538vN(11/30101.ovuleitiof I &X MI ABOVE PBR PITRIO$LY 338 JOKES), WTHS BE ELEV= 5115' ..., LIST 339 ST FULLREFLED"TIIICASLSETWHEIIWER‘027188SVNOTI N I ADP- 1DWI, 120*CONDUCTOR LAST TDe 13434.WA zr op CENTRAL5LER-83127XXL Max ANN= 58"@ 6900"1 akillrfk WO= 131361 ,, 2.-- --027----17./1441.)13-02'I-ES XDB SSSVN,ID=2 76' 'Datum.TY D= sew ssi '13,,,mr, 77.,I 008TRS,ID,12 34r1--f 3053*M 2, ' r V41 TOP OF 7'SCAB LNR -I 3111* ! .-. 3171' -9-518'x 7"BKR ZXP WR 7 NCR,ID=6.31' .--Top ucil 1-0r/07-v79i 5-4 7--V--fry 0 ,r SCAB LNR,26#,L-80, 0343 bPT,D.=6276 I-I 6800' 8000071,60C in IA r3,- s -r-vv Minimum ID= 1.81"0 10083'-10120' 1 3-1/2-INF D ONE TRIP PATCH s loon..10120`1-3-112'WD SPECAL CLEARANCE INDEPAK _e , 4111V,Irr i..,. , . ,am-INF Pi%li3-1 I).1 ar piasnfii li b rES7TIVA1E0 It. OF CEMENT(02/29/10) H 12302-1 - ,1.-=?s •• • ETLIBNG PON)I 102/13110) - y460..124.5r ?en i ke, 12486* •.• a.. 1.14.41 ff 804 S* 00 , .•el Itt 12482' HBKR 80#40 FUR 0=2,95"1 itt? fir+ 1 12608' Ho-sia.x a-iir EIKR S-3 PKR,Li=3,875' 1 Tall 3,in-MG,9 2t/,L ao PEC 1 -12610' r 1260*' 1---3 Ti2*.isii iNia,,i.iiiniin 2 14.111140802) I 0087 bpf,II3=7 997" _ 13-i.,7"MO STUB(I Ii21 6,01) I 12623' 1 1 1281" , 1.114113UE CUSTOM OVERSHOT I [0.11 SrPATti(82,281101 h 12700"-12905'CTU 144-04,4i Vr4 46 izter 1....13-112"ORS SID&V.ID=2_15Cr %SI imri w I aim- -[I)RI A,!Mr INN'k UM.Pt FISK.] 101"..4 IC: 1 VA. 3-1/2'TBG,934,L-80, 0087_ bpi,D=2.992" H 12796' Z.124 4 12324' 3-1/2'X 2-1fir X0,V==2 38 t" CO 147, 406 tto ,i,2. _f2- 7i : i-4.u=2_31 3.1 ow* 0110 Ari *iv* •tsti OlVt, r–14i 1 i-v—H).sir x r poi uot ITGII iv/IBM MAI- .i 0,i# . •• •+I,. :r 12693' i-12 lir OTIS X MP,ID*.2 913- 12,7 'MG 141,L 80, 0058 bpf,0-*2 44, H 1 ze2r i I girii 0•401 9-818-("SG,4 tit,L-80 BUT 1,ID=8881" 13138' 1292T 1-1s2 718'WLEG,0-2 441 ,"i 12888' j--1(1113 Tr l mom ON XXIXXO0I PERFORATION SLAIIMARY ! IL 144-I.OCT SWS 684M ON Onl WHO ANCX_E AT TOP PRiF 43'ra 13138' I Nolo:Rear to Produsbor EX for historical porf dala 13184* !,Jr MARKER Jaw SIZE SW WIERVAL T OpfteSqz SI-OT SO2 12-VW 6 13138-131531 0 02J19189 I 13400' HFISH-MLLE()rAsefai(motve.) I , 1 ,2.1fi5 4 13262-13384 i 0 0911008 i H -AIRP ELBMENT im,7,07) I 13432' i In t 2-110"X 0"TUE cuvout.orcE , , . . ....„...... .... ,,., (39$11Vii,keto spieNG r LPI,28#L 80 LMS, 0383 brit,1.3-6.216" 'i.. 4. —33' 1 '&1110"416,r X0,IhR,AN 13rn34' -I FISft at X 2-1ff 1132F GUN&Ca_TOP I triff31-I 13608' 1 r LM1.29$,L-80 ERRS,0371 Ppi,D.18 184^ -- 13660, i WifinilegaVi r DATE REV BY 7 COMARTS BATE REV BY GOMPTENTSPRLC1110E DAY 1,4T 07t18/86 AUDI 2 WITIAL COMPLETION 1037116 OJEIOND RJLLED RIR&PATO-1101103116) ..I MIL 11 24 12104/01 0-15 TRWO 1 II SM SET WET)OW TRIP BATCH(01/25116) WHAT No'861 13O 03118/15 STFIR.IC PLC_PATCH All Nly. 531329 21508 00 03131/15 FON ReitALL RESTRICTION 4'2 12500' SEC 34,Tt1N,R13E 1349'FTC ea PM 04/04/1510.4/PIC SET STRADDLE PATON , 0We/15 ILS1 PIC bEi APD PACKER CD 10085' 1 BP Exploration(Alaska( 3 . • Proposed P&A • TREE= 3-lor mcEvoy WriTi:0:6- 44:FVOY Y-2 4 SAFETY NOTES,:62S REACINGS AVERAGE 125 itain WHEN i ON MI"WELL REQUIRES A SSV WHEN ON AO"^"'3-hr ACTLIA ION- OM 01 :• ,AL i...V 01,70101 I L1S If 3.01 Pia i .7•00,716 BETWEEN SSSVN 4,(13 ELEV= 8685' •• .0.0.4 .... ..:. .. 0•••••• &X fiF'.= VEPHR F1317014LY 3",A•JOINT'S). DEPTHS SF ELEV= 5135' ,,..•••/' iii4. -. ::jjj•. .j.-jj jtj • FROM --;- 11,1Cla- 11)5Cr 126 CONDUC1OR - ? j 11:1$ ....11111111Iijiji a,,., , Cement Plug#3 Tubing punch @ Mu Ataki= sr rr,6906 ff.J*J._71 I:::::: 1300' and circulate cement down Datum ND= 13138, 0 '13atura 1371.3.= 880ff SS ii.:11 ' 202r - tubing and up IA. [la 3/3.cso 724,t 0081R8 13=12 347 3063' TOPOF r seas L IC --I 3171" j'14.-1 _ _ sin'IjjCement Plug#2 OA downsqueeze r SCAB 1NR,284,1-80. 0383 bp7,0=8 2-78Th 5806 • Minimum ID= 1.81" 10083'-10120' 1.. 6 3412 WFD ONE TRIP PATCH 10093'.•10120'H 3-112'WED SPE041,CLEARANWI CE DEPK A CAT-TRW PA 10-1.0....1 ei•(01(25110) IMATTI)TOP OF CEfekfT(02/20110) H 12302' ' LILIBONS RANO 1(027167-10-31--F12466-12452 ;44h, 12466 .41 101111... 441 val 40 •aaa tej ,Fiji! 12492' I--13•EKR-90740 PE3R D=2 05"1 .171 jinn A"' -•• 1280' j-19-518*X 3-1?6KR 6-3 PILft,ID=3.875* L'Ill 0224 3-1/2*Tin,9.20,L-80 NSC1", .• -1261E7 ....... Cement Plug#1 Pumped FB or laid in with CT 13-irr TOG STUB(11726,01)1 1 12623. , 12818' -.."41ctui.c......k,t v41(.v tzt-cr4-40 [MT St-FATI1(3208110) 12700'-•12905"CTM st-04 It 12743' 1-3 Ilr 0115 SLD-S-"`V V--2 t50- eV, .•.. V V Pi 210,, ::•:.: v II ........ •••• ..-A' 1;g,iab- 9,eu R. t 4,, MN,111.11,51,,4 .......1 ••:•:•lig.all , ,„_,,, _,_,. [3-172'1DG 9.3#,L-80,.0087 WI.D=2.392 H 12796' 4;:,t 12824, - 3.112*7(2-+.8!"X0,10,2 38 T"i 4...4 .........yrl'i I r 12866 1--12-,id OIL,X NIE,13 .313 ••••••4 .:::::: ,,,.4 41;4,:: 12889' _Ili 54'X 7"001/ARBOR wri 11118 0( 11) " Al X Mi,I 12893' A'O18. ID= ir 1 ......:.:.:•.. - -1-i7 IL._......._ _ 2 3 12•743."MG.8.4$LEG .0058 NA,D.2.441" H 12927' :•::::..• ,1 ... -.......... al 9-816.CSG,47t L-80 BUTT,D=a.ear F-I 13138'' I 12927' 1-12 7/8'lALEG 13 ii 2441"J •.: 42914. -IR ND 1T LOGGED oNxx,xxrxx ............. PERROFIATIONMINAARY RFF LOG STAG-OHCS ON oirtztaa \ ..-..•:•:•:•:•:•:•• ANCIE AT TOP PBRF 43'ita 131377 . .....J....., NOW:Hafer to Production CB far historical part dale • •••••••••••••••••- :•:•:•:•:•............ 1316,4* Hr MARKER JOINT 1 ........................ -SIZE SFF IfIERVAL OptitSqz' 314D-r 90Z ••••••••::•:•:•• , ••••••••••••••••••••••••••••••••: 13400. .1—friSH-WILLED FASCHLL 104706710n 2-1/6" 6 13138-13153 0 02/19189 2-1/6" 4 13282-13384 0 09(1003 -.J...- i HASH-ARP ELEMENT{OW1707) •:: 11432' I 11Clt 2-1706 X WITTY CUNOULLNCLPE-- ..„._,„.....„,_ -, .. celookuzeasitlimo i r LNR,264,L80 u4s,0383 W,ID ii 6.276" •••=j 13433' X0 7"L ,29* 13434' HASH 34'X 2-1/4-PEFF GUIN,&COL"TOP PrrarlD -1 13608' I rorisw70,74 I 7"LNR,280,L-80 SIRS, 0371 W•D.6 11141" I [ 13660' Va94,44.4.44P4.4°. DATE REV BY c004/.8N15 Fit REA(BY - Comamr51433JUTIDE BAY UNIT 07118/86 AUDI 2-IMTIAL COMPLETION VON%G.TB4,10/141_,...ED ROI&141,-ra-i(oi.o3/16) i NIL Y.24 ,— S21045111 DJ15 'Aviu 7110i10 73-LVJA,40 SFT WED ONE TRIP PA T0-1(01725416) PERMIT143 5861130 — _„...... 01i18715 STE1111C'PLL1 PAT0-1 . A14146 53.029.7160&00 03/3615.117N P &NJ FESTRN ICTIO@ 12500' .il. ,--.--- _ SEC 34,T1144.R13E1349'Rt.,83"Evil. 04.104115 ION P SET STRADDLE PATCH 05038/15 1.67 RC SET W1)PACKER fi)10085' OP Exploiratiori tAlaskal 4 • • Chart 4200 i -- — aum 8 8 o S+ 3 a 3000 p r O 3 c1 o ' Q IA MOASP _ 2400 0 O 844,rim 0 8 1300 `� oo • Or.Mt • -41 ct • 1200 11/30/2013 5/31/2014 11130/2014 5/31/2015 11/30/2015 5/31/2016 600 Well Head Temperature -10-Tubing Pressure(psi) -E-IA Pressure(psi) a OA Pressure(psi) OOA Pressure(psi) 000A Pressure(psi) 1.0n-Line/Off-Line Job Notes • The tubing x IA LLR is -0.3 bpm @ 2400 psi - observed on 1/24/16. After pulling patch the LLR will be -1.5 bpm @ 2450 psi. • BHCT is estimated to be 185F. • BHST 205 deg F. • New TOC in the IA will be 8000' MD and 5,538' TVD. Cement Calculations Volume Cement 255 bbls Total cement to pump 255 bbls Key Parameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc (20-100 cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 8 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time,quality control, PJSM 0 Cement displacement 5 Cement contamination 1 Safety 1 Minimum required thickening time: 7 5 • • Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 120 2850 5:00 150 1900 7:00 150 1900 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 3-1/2" tbg 0 12,302 3-1/2" 9.3# 2.992" 0.0087 12,302 107 9-5/8" 47#x 3-1/2" x 9-5/8" annulus 0 12302 3-1/2" 9.3# 8.681" 0.0613 12,302 754 Slickline 1. Pull 3-1/2" WFD one trip patch from 10,083'. (AWGRS on 1/25/16 notes that to pull this patch a WFD OTS retrieval tool is required) 2. Drift to 12,400' w/2.70" drift. Eline w/ Fullbore bore , J " 1. Load tubing with 160 bbls crude @ max rate. Max pressure 3000 psi. 2. Set 3-1/2" composite bridge plug @ 12,150' (+/-to set in the middle of a joint). 3. Punch tubing w/ 5' tubing puncher across the first collar above the CBP. Reference attached tubing tally dated 11/30/01. Note indication of tubing punch in AWGRS (if evident). 4. CMIT TxIA to 2500 psi to verify plug set. 5. Verify circulation TxIA 6 • • Coil 1. Rig up a micromotion to IA returns. This will help monitor returns. 2. MU WFD 3-1/2" One-Trip cement retainer. RIH and tag CBP. PU 35' and set the retainer. 3. Establish diesel circulation down CT and up IA to tanks. Verify coil backside is SI. Pump the following fluid schedule. a. 754 bbls of heated diesel (160F) b. Minimal FW spacer (-2 bbls) c. 255 bbls cement per design d. CT volume of FW (unsting from retainer w/ last 1 bbls of cement in CT) 4. This should put the TOC in the IA @ -8000' MD. Keep track of returns from the IA to track the TOC in the IA. See Coil Contingency Procedure #1 below if cement locks up while pumping into the IA. Note that the CTxTBG backside is expected to pressure up -600 psi as cement in the IA rises above the tubing leak. Do not bleed off this pressure as it will only allow for more cement to enter the tubing from the IA via the tubing leak. 5. While maintaining Tubing x CT backside pressure (expected to be -600 psi but hold whatever pressure it settles out at), unsting from cement retainer w/ -1 bbl of cement still in the CT and lay remainder of cement in 1:1 on top of cement retainer. 6. With the same pressure (600 psi or more) trapped on the CT X TBG backside, POOH pumping only CT displacement down the CT (this can be 60/40 MEOH so the CT is mostly FP'd upon reaching surface). This can be achieved by POOH and pumping just enough down the CT to maintain whatever pressure the CT X TBG backside equalized at in the first place and verifying that for every 100' of CT pulled -0.3 bbls of fluid are pumped into the CT, but if there is any question err on the side of pumping more fluid down the CT, not less. Also verify upon reaching surface that -37 bbls of fluid total have been pumped down the CT since leaving bottom. Note that the fluid exiting the CT will be entirely FW. Leave the well with the trapped WHP to keep cement in the IA in place. This will leave all of the cement that was laid on top of the retainer to mill later, but will preserve the IA cement job. 7. Once CT is at surface, finish displacing the CT to 60/40 by pumping 60/40 down the CT and taking 1:1 returns from the CT x TBG backside, holding 600 psi as WHP. 8. Trap the 600 psi WHP on the well and shut in. 7 • • Coil Contingency Procedure Contingency #1: If at some point cement locks up and cannot be pumped into the IA then hold whatever CT x TBG backside pressure has been already established, cut cement at surface, pull out of the retainer and lay cement in the tubing 1:1 maintaining CT x TBG backside pressure. Swap to gel and contaminate/wash all cement out of tubing to surface maintaining CT x TBG backside pressure throughout. Trap the CT x TBG pressure on the well and shut in. Fullbore 1. Wait on Cement at least 5 days 2. MIT-IA to 4000 psi. Coil 1. MU 2.7"junk mill. RIH and tag TOC (expected -12,125'). 2. Mill through cement, retainer, cement and the CBP set @ -12,150' MD. 3. Mill/Push CBP down to the 3-1/2" x 2-7/8- XO @ 12,824' MD. Once a hard tag is seen in this vicinity POOH for smaller mill. 4. MU junk mill for 2-7/8" (-2.30"). Continue milling/pushing remnants of CBP through the 3-1/2" x 2-7/8" XO @ 12,824" and out through the tubing tail. POOH. SL w/ Fullbore 1. Load well as needed and set TTP in nipple @ 12,566'. 2. MIT-T to 4000 psi 3. Pull TTP. Fullbore/DHD 1. Assist SL with load, MIT-T EL ` 1. Perform waterflow log. fry' 2. Perform SCMT. � p e vf-c w t'r v 11 4-p 6- C Fullbore/DHD 1. AOGCC witnessed MIT-IA to 2500 psi after well is online and stable. 8 • . • S 171.104 SARY - - u11fu 1l l A . RIG OOVON IS pate 11,10'2041 WELL r DS Y-24. TUW74G 15' 1.-60 MSC' -.,_f 7813 WY. 1-28 4n in ON RACK 4C'. 1TS RAR _ __;y!OK8 TO 6' 13371,16 FT ON RACK 12.350 Fr RAN ITEM Oescnptioi.1aclud.c SIZE.TOPE.CONNECTION 1.173 Sal �_ , 10 00 : lENG7M Toy, 23OTT05% -. ..11t.QU „i1v701.1 QZstsiI::i 3.50331 1.257 7 32 12611 4;1 '2G 1911' P5.0 3011 7 21370 3.18' 9 41 12403.63 '241741. 1 .1011.' 1.-a::3 7 NSCI T!:U1'..:. 2-033f 3.94 _ )020LL. __... 17577.43 12632.63 PUP JQ!44T{3 17't.,14I1SCTI1 2.737, 306 1.61 12562 SS :2577.43 XM 64.12A.F i 2.75 3.911 1.13 12561 42 12142.35 ___ j074T 11 1:1,-I.3)`13011 2-937 3.94' 9,77 12551.65 12541 42 t JJGINI _-tl't i 113"N5:1 'Litre, 2 137 3 96 30 40 12571 25 17151 15, PIP JQ:rrT 13 i-r t 6a MSCT• 2.037 3.94 1.40 12511 31 1252' 25 -) '. N1/CO lir NSC 1 '1N1 2937 396 1.90 125.$61 1211131 9 5:0-5-3 PACKER 2.954.0 125 4.64 12504.5 :2569.45 -I X.O'3 lir NSC.T 90x r 4 1:2-riSCT PI7.1 2,037, 3.96 1.10 12503 OS 12504.36 l1 Y-f .' ' F Fox, . 12'7 2'- t.S T PIN,. 2.037' 376 1 70 12501 35 12901.05 r td.'1 81•44 FOR 311 S 13.61 12461.74 12191,30 1 1745774 12417 74 CIi JTS FLA:ASO" .t 4+J'Jtt IN S-3 4.53E 4&Y TALLY } 12467,7412417.74 12447.74 1741774 Sr_AL ASSET.BLY!SEAL JI.9 115 1.09.:41 # 29ST 4.S) ,37 { 17447 37 i 12467.74 x0 t 2.0371 3,94 1.16 ! 12415.41 _12r67.37 --., ,--... TIJB%IiC alto I 2.1374, 3-96 5 57 17479 SA 12415 41 X10 P-JI'tL-AL FO%BOX r 743Cr 1.12.113 311 •33 t 13470.21 12471.51 A.0 PUP IL-50 NSCT box 1 F C.R.sem) 2.902' 101 1.37 1 12460.14 12470.21 35'4 2 75-HES-x'tilts F!-E_wr HP A HCAt f 7751 3.41 1.00 I 1245544 12480.14 TUBING PuP 0,-10 NSCTy }I 2.902 3.113 0.71 12441.16 12431,14 11.9 J15,45E 3 1!1'NSC r ras11.G 1315 1 '1-00.1 J311 i 2167 3.961 10433 30 7014.54 124490$ x."0FCAROXFISCI ( .2.142! 191 1.23 2007.31 2016.56 'S 5' :75'HES•KIM"riPAC1iCfFF, 1 7:,-2'OIFC%elPt 2.751 4795 322 2004.09 290731 EQ PUP(L-7.0 F.$^.T t3OX r FOX P'\1 T 2.1112! 3.11 1.34 i 1194.53 2004 05 41 IT 7.80 7 lrr hscT TUjING( 75 340 T1*RIJ 4701 2.1117 114 1421.00 73 53 1 1914.53 SPACER P,PS 2 667 3.06 14.79 $8 74 73.53 37 i.8C 3 i?1•SCT 7U431'.G -T•11.11 2447• 3 16 32.03 2f,71 51,74 13 1,rriSCT PIN a4 T#2'NS.`::f acv, 2.44&? 1 I 90 24111 _r___24.11 4 1!r-SST PUP 3,03 4 b 1-30 23 51 l 2441 Ttuair-G NA!:C•FR 3.9S 4.1 .41 2270 1 23.51 OO C* 19 RK9 22.70 1 22.70 p __ - p. ._ j Correction --- From the PDS j I i • Caliper survey there are only 338 j ' • full pmts between tt e SSSVN - • and the X Nipple above the PBRj I 1 l i_ _ r i 1 . ----i--. • • t ...._ 11 E---- -..--. - 1 _ • It ' 9 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM! N APPLICATION FOR SUNDRY APPROVA S 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q - Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other IA Cement Squeeze Q - 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 186-113 - 3, Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development ❑ 1=1Service Q 6. API Number: 50-029-21608-00-00 99519-6612 Stratigraphic • 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No Q PBU Y-24 9. Property Designation(Lease Number): 10. Field/Pools: UC I 10 hitADL 0047471 - PRUDHOE BAY,PRUDHOE OIL• 11. PRESENT WELL CONDITION SUMMARY �,'�C Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD):/0 Junk(MD): 13550 . 9207 - 13508 9175 • See Attachment Casing Length Size MD TVD "urst Collapse Structural Conductor 80 20"Conductor 43-123 43-123 c9fST! Surface 3011 13-3/8"72#L-80 42-3053 42-2672 4930 2670 Intermediate 13099 9-5/8"47#L-80 40-13139 40-888 6870 4760 Production Liner See Attachment See Attachment See Attachment each . nt See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment / See Attachment See Attachment Packers and SSSV Type: See Attachment Packe And SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ❑ Wellbore Schematic Q ,_ .,- ass after proposed work: Detailed Operations Program Q BOP Sketch ',,.ply.tory ❑ Stratigraphic ❑ Development ❑ Service Q. 14.Estimated Date for Commencing Operations: N. ! �W: Status after proposed work: • 0 WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: `' ' GAS ❑ WAG Q. GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure .proved herein will not Contact Hibbert,Michael be deviated from without prior written approval. Email Michael.Hibbert@BP.com Printed Name Hibbert,Michael Title Well Interventions Engineer Signature \N � Phone +1 907 564 4351 Date `0`I O(t t COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number Integrity 3`Lk '-'62—C) Plug 9 y ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes CI No ❑ Spacing Exception Required? Yes❑ No ❑ Subsequent Form Required: /0 4".24-- Approved by: APPROVED BYTHE COMMISSIONER COMMISSION Date: ORIGINAL ,,,_ .,,, Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate s_) ..s • r to t • € . .. ity Well: Y-24 Y-24 IA Cement Job Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Travis Alatalo (907) 564-5351 History Y-24 is a produced water injector that has a tubing by inner annulus leak @ 10,106'. Multiple attempts have been made to patch the leak but have been unsuccessful. - The plan forward is to place cement into the IA to fix the tubing by inner annulus leak @ 10,106'. The cement will be brought up —8000' MD to cover the tubing leak.- Current Status The well is currently classified as "Non Operable" by BP due to tubing by inner annulus leak. The well is currently shut-in until the leaks are repaired. Economics An estimate of the pattern performance with and without the support provided from Y-24 suggests that the value of bringing Y-24 back into service is approximately 90 mbo. This was determined via forecasting the pattern production from a period of time when the injector was operating consistently and comparing that to a forecast from when the pattern had no injection support. The difference between the two cases was interpreted as the benefit. This result was then compared with the value of water method which supported the 90mbo estimate. There is additional upside potential if the well is placed on MI injection in the future. The proposed plan is economic and should restore the injector to operability. Objective This cement job is to repair a tubing by inner annulus leak @ 10,106' MD and regain operability of the well. Cement will be circulated down CT and up the IA. The new cement top in the IA will be @ —8000' MD. Post-Job Evaluation This well is an injector so an AA will be applied for to allow for WAG/MI with the following proposed evaluation criteria: ➢ MITIA and MITT to maximum anticipated injection pressure ➢ SCMT to confirm Top of Cement (TOC) ➢ Temperature Warmback Log & Water Flow Log to verify no flow behind pipe Long-Term Integrity Monitoring ➢ Record WHPs and Injection rate daily ➢ BPXA will submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report. ➢ 2-year (biennial) MITTs and MITIAs to maximum anticipated injection pressure. ➢ Maintain IA pressure below 2000 psi normal operating limit. • > The well will be immediately shut-in and the AOGCC notified if there is any change in the well's mechanical condition. > After the well is shut in due to a change in the well's mechanical condition, AOGCC approval shall be ➢ required to restart injection. Current Schematic MCEVOY YKLLf-EAD31B•&DEVOY j ■ -2 A SAFETY NOTEi:H2S F�AUNGSAVERAGE 125 ppm WI-EN AC'T1141U12- p'1>r•, it ON MI^ .4`WELL REQUIRESSSSV WHEN ON MI""11/2" CYO E3_EV s 8S BS TALLY(11f30/01)UST 339 FAL JOINTS BETWEEN SSSVN SF HEV= 51.35 &X N P ABOVE PBR MR(OFIL:Y 338 JOINTS). t7FPTHS FROM SSS1/N-OVERSHOT PER.ECT CALIPER 102J15•97)"' (OP_ 1050"Mau Angia= 58" -E900' 120-CX)PcucTCR ? LAST lila 13434'W A 2r 00CTRAL1ZER-03/27!00. , Ovum MD= 13138' CJalurnT4D= 8600 SS , 2027' H3-N2'HESNOBSSSVN,0=2.T5' L133/0'CSG.721 L 609iRS D-12 347" L 3063 ' TOP OF 7*SCAB LER I— 3171' ' _ 3171' —I0-518'x r BKR ZXPRLR/NCR D=6.31' J ...,-• g j 7"SCAB 1 NR 2H4,L-80,.0333 bM,D=f,27r I I €600• ' Minimum ID= 1,81"(® 10083'-10120' 3-112"WFD ONE TRIP PATCH si 1�'-10120 —3-1/2'%EDSPECIALCLEARANCFWOEPAK s QV-)lir PA 1L3-1 I1=I e1-(01)75110) 'ESTIMATED TOP OF(SFT(02120/10) 1230? ' �� 3 11941114 [TUBING POND I(02/13110)1---L124,50'-12452"` .On j --L 1248 ` I -1/?FES X IV.ID=2 7 1 .41 1.4 144 441 4111 iV o1.1 12492' BKl2 RO/s0 MR 0=2.95' O Atli M r1 I 12606' --10-5/1'X 3 1,2"SKR S3 Ii(J t) 3.8/5' I Pril ►awl 3.19T TBG 9 20,L BO MSCI, -I261(7 h. %N 1fT �. -�9 1/ O$ 0087 DPT,91=7 99T I.w 12665* 2HESImo',AR.lF3)TO (41n0?102� [3-1,r 7F)G 5Tl1R(I 1/76,')11 I 1 12623' 12618' I__J(.NQUECLGTO$AOVERSHOT 14:39?SFfATH(02.79 10)' 12700'-12905'CTM I vis Iii -..-----.-_---.-- 'KO •1)'3-1/2'OI IS SLL)SLv.U=2..T50' 9331 '7 12/1114', is u,, A 1 1,m' /nry snu 1<�rit 13-12"TBC,9 3N,L-80,.0067 Mg.D.2-992' 1-{ 1279r *J l'''.-4'r' 72824' -3 11'2'X'2 r,0•XU,U-2.16!"J j% ', 12860' I-12-110'OIL9X NV,U=231? I 4r� +•+4 14,-4 o4�.f .:ri+i i..!! 1288! 1-1!sir X7•BOTUSA VCRw MAO( 111 '] e ,-ow- 12883' 12/AV OTE)XNIP,D+2113" 2 7,0'119G,8.4N,L 80,.0068 Dpf,D*2441' H 12,27' I I`ill'ie II PO •. 1o'+I 19-515 CSG,414,L-8O BUTT 0=8.881" H 1313W ecfrol 1 12927• +7/8"Y.LL.G D---2 44 11 I 4 1 1259i' A 9 h T I oGnFn nN x x/X)I/XX FBr{)R1171C)N SIM.*,1ARY FF)_I O(3 SAG WKS ON 01112/88 A NII..E AT TOP PERE 43'©13118' Note:Rcfcr 10 Ptoducbor CB for h6brical peri data ' I 13164' Ir MARKER JOHT SEE SPFPfl IAL 1 Op1v'Sgz SHOT SQZ L 2-1r8' 6 13138-13153 O 02/19189 ' 13400'a HI ISH-VLLIi1 I ASUI8LL 004,'06/101 2.1/8' 4 13262-13364'' 0 09/1049H ? HASH-W8'EL134B4T(06/17/07) 1 r.l 13432" J Flat 2-1/0•x 6•rut C12J3ULLFEX r LW,268.L 80 U4S, 0383. Dpi,U-6 2/6- 13433' - T234IFtlILRER SPRING J xG 7.1 NR,2911 13434' H F1SIt 34'X 2.116'RTC GUN.6.00L TOP 1 PBTD -{ 13608' I ..', /-1-NR,20/,L-60 SIRS. 0371 W.0o-6 104" I-,F 16660' `A.N44.64eti CI;TLSREV BY (X),R4NTS CATE FEV BY COMMENTS PRUCEIOEBAY UNIT 0T1986 AIA 2 INTIAL COMPLETION 11/07/16 GIBLAD F><LL®RCR&PATCH(01003116) J Wal Y-24 12104001615 '17.90 ,1111107/10/16(1-C.MILISIT WEB our TRI'ñkTCI (01/25ry6) FR76ITI-bX1861130 03/1&15 STHPJCIPU_L PATCH APINb: 50..029..21608,00 03+31;15,= PJCjlull F ESTRIC110N,g 12500' SEC 34,T11N,RIX 1349'FNL,83'PM. 04104,15 JC9I PJC)SET STRADDLE PATCH 05.409715 JLS/PJC)SET WFC)PACKER-'.10065' BP ErlpForatior (Aloka) 2 . . lost IA Cement Job 4110________ ____._. .= 3-15W F4VOY VAIU-EAD- 14:EVOY Y- 24 SAFETY NOTES:ICS READINGS AVERAGE 125 ppm WI-EN ON MI''''WELL REQUIRES A SSV WHEN ON MS'"' ACTIA I OR OTIS MB.REV 88.85' I I , i FRORTALLIY555111:370v)UST 33:RILFIEFLL:11TcASIB.EPHEENffurooviSSSVuon N.... I &X PIP ABOVE PBR PKR MOLY 338 JOINTS). LIMNS BF EIEV= 51.35' KOP- 1050' 20'031,DUCTCR ? LAST The 13434'WA 2_2"OD CENTRALIZER-03/27500. Max Angle= 58',T,6905• °alum 143= 13138' 202T j-I3-1/7 I-ES XDE1SSSVN,ID=2 75' Datum TVD= 680C4 SS' 13 3/43'Cr.rD 774'1 00 BURS,11-12 34r i - I --i 3063' I 101'0'r SCAB LNR -13/1/1' , ,,„.,.. t,,---L3_19.1" -9-5/8'x 7•BKR ZXPRGR/1-IGR.0=6.31' Ir SCAB 1414,261 L-80. 0383 bp',V.t.276 H • 8000-TOC in IA Minimum ID= 1.81"a 10083'-10120' 10083'-101217J-3 1;2'AFD SF'ECIAL CLEARANCE WIDEPAK 3-1/2"WED ONE TRIP PATCH , II-41F f'At IC1-1 II- I II I'(01.17'.11114 a;-110:4-11ED TOP OF C043111(02r29010) J- 12302' 1P it i 01 4,,,,, , ITUBING PUN-51(02r13/10) I-1_12450'.12452' riN 4r,4: 12466* - 13-1,7 FES x 9.1r.14)=2 75"j 144 .441 41 I 4111 11• .4,4 '.. .41. .41 .11,,,..4 .. i44 12492 -16Na40049 FUR,13=2.95'1 !e/ 12606' _ . 9-5/8 X 3-1./Y BKR 5-3 PKR,0=3.875" i 9...11 3-152'rec.,9 21,L-80 PC I, -12610' • 12554* 1-13 502 I CS XN NP,1,1111010 2,Tr(1142102) , 0087 br,13=2 WAT I . _ 13-.-1- 150 ST1.18(11128/01) I I 12623' " I 12616' HU9101JE CUSTC4h4 0V8614-01 1-[shr....Tri(ovitselo) i now-12905"C.Til CIO; Fr• 'ow 4%. 1 2743" ; 3-1/2"ORS SLD SV I)=2 'SO •4.1 I I OA licivb- Il'un 4 J I.,' If0111-1111•14 11\1( , it.. I3-1/7"TBG.9.V,LOO,0087 Apr,0=2.9921-1 129.15" 1 -A •,.. "4'4 12824' "---73 /2"-1 X 2-/ti" 0./ .4 u-738 f i 174i% 4,4-4 ..4.:*, 12800 -12UNIP.u=2.313 ;- c, I 4,,A,„ •*44 121116 ]--I!6/8"x 1.wry!up Han r‘t TWA CI(,1)- •1 .!,:7 t: vI i 12162 -12 ORE X NI ,ID2 313" 12-7/8"TBG,844,L 90,.0058 bp,.Cl.2.441- H 1232T 1 .....i ..., A .4. 4,I .4,t1 7/8" P I tot 2 , j 9-5M"GSG.478.1-1081171.1)13=8.681" 13139- ,t4,.! . 1292r 1-L743'INLEG13.2.441" _ 126e6' --1 EL I.0 Ti LOGGED ON XX/XX/XX I FEW-ORA-MN SUMPARY I4F LOG SAS EIIICS CON 07/12188 k ANGLE AT TOP PERF 43'@ 13138' I %Ia.Rorer to Reduction CB for historical peri data 1 13184' r 0,,vowm Joo-rr SEE SFF WTERVAL 77 OpraSqz SI-PT SOZ 2-1,5' 8 13138-13153 0 02/19/89 I 13400' H' 5<-1/LLEL)!AUDI-IL-1',14.06/10 1 2-1/8" 4 13262-13384 0 09/101811 9 HF161-1-VI47Paa4FAT 406,17,1)7;i . 1 13432' 7. FICA r 2-1/00X 8"fur cip.BuumocE - (2-NIKALvE4t 5F44n6 I-LNP.,261.L 80 WS,.0383 bpt,13-6.2/6" 131-433. 1 , ' XO r LW?,79a 13434' 1-1M1-1 34'X 2-141"FERF GLOL 8 CCL TOP rob _ 13608• , r I NR,NM,1-80511545 0171 opt,0 4 6 164' - 13660' redraa'arirei BY CCOAVENTS 1 DATE r4-)/0T F54E1-10E BAY UNIT 0718/86 ALEO 2 INITIAL COMPLETION ;0107,16 CLIDJMD C71..03 PIN&1ATC.1-1/01/03M6) 'WELL '24 i 12,0401 13-15 RNO ;07/10/16 01-0010=ET MD OFF TRIP PATCH(01/75/16) Four No 9861130 ..,_, 03118'15 STF.PJC FILL PA rai * ----------7- An Pio- 50 029 21E108-00 .13131/15 PEW Piell.l.RESTRL'IM a.12500' 1 SEC 34,T1114.R13E 1349'FiC,83'PM 04/04015-J041 PE SET STRAOIXE PATCH -- — 015 JLS'RE,SET'4WD PAO<B;@ 17095' BP Exploration lAlask a) 3 P1-21 Proposed P&A • 11 = 31/8 M(EVOY SAFETY NOTES:FRS READINGS AVERAGE 125 ppm Aff 1_-__ �WFiLF£A() 1410!VL>Y "� ON M1'^WELL REQUIRES SSSV WHEN ON NI 3-112" AC:u_ ION-: OTIS TALLY(11/30011 LIST 339 RLL JOINTS BETWEEN SSSVN C%tB.ELEV= 88.85' /I 4was �, &X NIP.=• E PBR PIR ONLY 338 JOINTS), D)EYTHS S_ELE4'= 51-35' I _ FROM _ eP 105Dr' I20- Cement Plug#3 Tubing punch @ �� 58"@G9O 34 ' t � 1000' and circulate cement down jtlalunt4D= 13138' .'' ..-.. 'Calm)TVD= aeou'ss II :::' + 24127' tubing and up IA. I.13-318'CSG.728,L eoetas i2 Li; gar' 3063— o o r 10110E 7'SCAB LNR -7.3.1-Ti; ' 31711P11111..-' — Cement Plug#2 OA downsqueeze r SCAB LNt,260,L-80. 0385 bp',Ea=#.278 J-1 6400' • Minimum ID= 1.$1"tai 10083'-10120' 112"WFD ONE TRIP PATCH 10083'-10120'�--a-1/2'WFDST IALCLEARANCEV DEPAK (Ai--11{8'l'A 107-11)c 1111-(01P.S.16) IESTNATEDTOP OFt 14ENT(0)29710) 12302` Fiume ptmia i.02113l1011-t12450"-12.452'; *�' I. #i 124s6� 122)2.F x N1P,19=2 75' I 40 oyir --16NR 8040 PBR,,D=2.95', -_.:31 � 12508' 9-518'X 3-1,2'BKR S-3 FER,1)=3.875' 3112'TUCK,9 29,L 80 N6Cr -12610' 008744,ID'--2 907. 1 L_12 _ Cement Plug#1 Pumped FB or laid in LL� with CT 3-1,7 O sTLES(1 1128'111)! 1 12623' ' I1 ` 12618' ---r eT..r it..48 ,/ti-torv1 SrFATH 02,9Stall=- 12700'.12905'CTM I 4111 ( 12743- 13-urOils sws-V U=2150zi ._> fir 1Y11P8- 1'WI R J If- INV+AAA'N'IVI u 1110 X 3.1,2"TBG,9130,L-80,.0087 bpf,CT=2.992" I--1 1279 1 +'41i l''#*4 12824' - *3-112'x r S xO,®_r 38r- 0; ::��,4. 12860' +--12-1/8'010:X NP,ID=2313' 1'414 ``*A: 1 2 a 49' j18-5111'- x r DOT r 1GF1 w TIEBACK,FD" '1. ► i# 2 778' No 120'3' -{jAI'OH XNJ',t=231r I T13C 84#,L-80,-0058 bpf,13=2.441' H 12827' f .�,,' ,6414 19-578'C23G,478.L-80 BUTT,b=8.681" -1 13130' I "4. 12927' 1-12 018'WLEG,13,244r 1 FrilF09 789,1 SUMMARY' 1.'1811 i' {L1 ion TT 1 tAt l5f 1 Xxl1(X'1tX 1 1 IOC,; SWS 1044 01N 07H2/88 A ANGLEATTOP FERF 43'010 13138 Note:Peer to Production CB for historical perf 4313Jaw-1$144 7'WAXER SSE SW 1YfBiVA1 ]CpotSqz SFiDT SC]Z t >.:.I 13400' Hr 6 H-Alt FASt7rA.1.(04/06/10)1 !Ziff 6 13138-13153 0 Df,J19f89 7.1/6' 4 13262-13364 0 09/10,8(} -z...„4 ? H FT6t1-%FP ELEPAF34T(06,17407) i 13432' �t 18) X 011131E Gt.:R1 831 LL*xE , :::: 1"LNR,2511..L 8C1 U43,.0383 W,ID=6.216' ^-1 13433' I 12'7+1ITiAi.,G;£18 SP1 ' X01 7"I.NB,as# 13434' H F13R 34'X 2-1/1`HERE Sint&CO_TOP i MID 1a60W r LNR,2941,L-80 BTRS,0371 9111,D,6 184" 18660' F►l l*t/lirl/+r+,Ri DATE REV BY COMMENTS LATE 1 V BY t%RAIEHTS FRIX110EBAY(141 07119106 AND/2 WTTALCOMPLETION 11.67'16GJBJM3Ft1_.[DFKCF28PATCH(01'073/1sj 'MIL- Y.24 '17404811-13.15 F8NO ' 7f;L16 111-St.IAl5�8FT MT)OW TRIPPATC91((}1/21)/19) MUT t4 '861130 0311515 STF.1PJC RLL PAIGI M1911) 50 029:21808 CA 03/31715 RR4W PJC MO-l STRIGi1ON @ 12507 SEC 34,T11t.R13E 1349'FM.,83"PM,, 04104115 JC&A'RE SET STRADDLE PATCH 05/03'15 JL5'PJC S't1 WFD PACKER @ 16085' BP Exploration(Alaska) 4 • • Chart 4200 8_ PI 3600 5 g N � � N Q 3000 1,-- 00 0 vii O IA MOASP 2400o ,11- •8 ry • O • , ? ir } • a o • OA MO1 __ r 1800 ria r1200 Gi �L_ • ? ■ .j' r 0 11130/2013 5/31/2014 11/30/2014 5031/2015 11130)2015 5131/2015 800 -a-Well Head Temperature ♦Tubing Pressure(psi) U IA Pressure(psi) -A OA Pressure(psi) -f-00A Pressure(psi) f 000.A Pressure(psi) •On-Line/Off-Line 0 i _ Job Notes • The tubing x IA LLR is —0.3 bpm @ 2400 psi - observed on 1/24/16. After pulling patch the LLR will be —1.5 bpm @ 2450 psi. • BHCT is estimated to be 185F. • BHST 205 deg F. • New TOC in the IA will be 8000'. Cement Calculations Volume Cement 255 bbls Total cement to pump 255 bbls Key Parameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-100cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 8 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time,quality control, PJSM 1 Cement displacement 5 Cement contamination 1 Safety 1 Minimum required thickening time: 8 5 • • • Cement Ramp for Blend _ Time Temp Pressure 0:00 90 0 1:00 120 6800 5:00 150 5000 8:00 150 5000 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 3-1/2"tbg 0 12,302 3-1/2" 9.3# 2.992" 0.0087 12,302 107 9-5/8"47#x 3-1/2"x 9-5/8" annulus 0 12302 3-1/2" 9.3# 8.681" 0.0613 12,302 754 Slickline 1. Pull 3-1/2" WFD one trip patch from 10,083'. (AWGRS on 1/25/16 notes that to pull this patch a WFD OTS retrieval tool is required) 2. Drift to 12,400' w/2.70" drift. Eline w/ Fullbore 1. Load tubing with 160 bbls crude @ max rate. Max pressure 3000 psi. 2. Set 3-1/2" composite bridge plug @ 12,150' (+/- to set in the middle of a joint). 3. Punch tubing w/ 5' tubing puncher across the first collar above the CBP. Reference attached tubing tally dated 11/30/01. Note indication of tubing punch in AWGRS (if evident). 4. CMIT TxIA to 2500 psi to verify plug set. 5. Verify circulation TxIA 6 • Coil 1. Rig up a micromotion to IA returns. This will help monitor returns. 2. MU WFD 3-1/2" One-Trip cement retainer. RIH and tag CBP. PU 35' and set the retainer. 3. Establish diesel circulation down CT and up IA to tanks. Verify coil backside is SI. Pump the following fluid schedule. a. 754 bbls of heated diesel (160F) b. Minimal FW spacer (-2 bbls) c. 255 bbls cement per design d. CT volume of FW (unsting from retainer w/ last 1 bbls of cement in CT) 4. This should put the TOC in the IA @ —8000' MD. Keep track of returns from the IA to track the TOC in the IA. See Coil Contingency Procedure#1 below if cement locks up while pumping into the IA. Note that the CTxTBG backside is expected to pressure up —600 psi as cement in the IA rises above the tubing leak. Do not bleed off this pressure as it will only allow for more cement to enter the tubing from the IA via the tubing leak. 5. While maintaining Tubing x CT backside pressure (expected to be —600 psi but hold whatever pressure it settles out at), unsting from cement retainer w/—1 bbl of cement still in the CT and lay remainder of cement in 1:1 on top of cement retainer. 6. With the same pressure (600 psi or more) trapped on the CT X TBG backside, POOH pumping only CT displacement down the CT (this can be 60/40 MEOH so the CT is mostly FP'd upon reaching surface). This can be achieved by POOH and pumping just enough down the CT to maintain whatever pressure the CT X TBG backside equalized at in the first place and verifying that for every 100' of CT pulled —0.3 bbls of fluid are pumped into the CT, but if there is any question err on the side of pumping more fluid down the CT, not less. Also verify upon reaching surface that—37 bbls of fluid total have been pumped down the CT since leaving bottom. Note that the fluid exiting the CT will be entirely FW. Leave the well with the trapped WHP to keep cement in the IA in place. This will leave all of the cement that was laid on top of the retainer to mill later, but will preserve the IA cement job. 7. Once CT is at surface, finish displacing the CT to 60/40 by pumping 60/40 down the CT and taking 1:1 returns from the CT x TBG backside, holding 600 psi as WHP. 8. Trap the 600 psi WHP on the well and shut in. 7 Coil Contingency Procedure Contingency#1: If at some point cement locks up and cannot be pumped into the IA then hold whatever CT x TBG backside pressure has been already established, cut cement at surface, pull out of the retainer and lay cement in the tubing 1:1 maintaining CT x TBG backside pressure. Swap to gel and contaminate/wash all cement out of tubing to surface maintaining CT x TBG backside pressure throughout. Trap the CT x TBG pressure on the well and shut in. FuElbore 1. Wait on Cement at least 5 days 2. MIT-IA to 4000 psi. Coil 1. MU 2.7" junk mill. RIH and tag TOC (expected —12,125'). 2. Mill through cement, retainer, cement and the CBP set @ —12,150' MD. 3. Mill/Push CBP down to the 3-1/2" x 2-7/8"" XO @ 12,824' MD. Once a hard tag is seen in this vicinity POOH for smaller mill. 4. MU junk mill for 2-7/8" (-2.30"). Continue milling/pushing remnants of CBP through the 3-1/2" x 2-7/8" XO @ 12,824" and out through the tubing tail. POOH. L w/ Fullbore 1. Load well as needed and set TTP in nipple @ 12,566'. 2. MIT-T to 3500 psi 3. Perform SCMT from TTP to surface 4. Pull TTP. ,.. Fullbore/DF D 1. Assist SL with load, MIT-T EL. 1. Perform waterflow log. 8 I _ . _... T1.101140 SUMMARY i1.r las` RIG 00.‘06411 pair tti)0'2001 �LK WD• DS Y-24� •_�--. TUNIELNG 3_S" 940 MSC' TBG YJT 1.1111 432 JTS OM RACY., 4;7__ITS RAH 7" .. 0610 TO Or 13370.11 FT ON RACK 12,019 ' Fr RAN 17E64 Oescn twn inctudsi S12E,TYPE, CONNEC11UN 1JrS 14) 10 00 : 1ENGTM_ TOP OOTTW51 . ,Cr_if CuSTOL1 ',-RS11.^.l 3.502$1 1,75: 7 32 T t112912.49 t _ pt,P JO)N' ' 21,7. 3.48' 9-111 _-4 12142.13 t36174} JOtt.7 1.-9::,3 1.7.-NSCf 1uutr,. 2_937• 3.9G 7020 12372.43 ; 1263263 a1JP JOINT c3 1:7640 NSCT 2-437 3.06 1.0/.it 12662 ss 12577.4;; X14 NFFP1F 1 2.75 396 113 1256142 13547.5, ' 17L3F JO NI 43 1.':C.ao ISCC J► 1111FEESEMECUMMEHMalli 12561 42 ]{7 10 12531 25 125 51 65 0 r' UI`,CUNT 1_3 1.7"l (11 N15CT. -- _ ., ��� .12311» t�5:' 25 i X'O,4 J;7^NSCT BuX It 3 Il:"N5CT P941 2.7.37 3961 t 90 125.31 At 12411 39 95.72'S-3 pACyCER 2.15'4.0 1.25 1 12504.15 :2599 is _ X.C'3 1.r NSCT BOX 4 4 1:2 NSCT 1,11.1 2.937, 3.96 1.10 12593.05 12504.1! FPO*a.'. t;z'NSCT PIN, ?1373961 7d . ' ? X.0 r.1 :...2-£l.# /2501 33 • 1251)3.05 • 1040 0991 3+ 5' 13.41 12417,74 1260113 I 11111111111111 12417.71 12417 71 GI J?a R:.te ABOVE .rlDVrh til S3 ItS5F135 Y TALLY ) I17447.711 12497.74 112417 74 124;7 74 SL,:L ASSEMBLY[SEAL JN.1 11 S'LOI:3i 2_95' 1.51 i aLO .37 12447 37 ; 12417.>4 t r' 37 3.1E 1.111 12415.41 12447.32 TU991G 0.ID 2 437: 3.46 117 1 12479 54 12415 41 X'O RJP 41•A(?FOX 90X r N,Scr r pus.) 2.1! 3.91 9 33 I 1 420.21 1 12479.542 7C0 PUP 1L-00 NS'CT BOX a FCX PIN) 2492' 3,9 : 4.57 i 12440.14 12474.21 3.5"Y 2 75'HES*X'N1PP E wi HP RI-1.7.-5,1 .74, 3.1 1.00 12431.14 12410.14 ruE5NG PUP tL-101,45CTI 2102, 311111LEMIIIINI=MMINI12451.14 l..JOS.-BE 2 1!7-NSCr ritimr tits 1 '1412U 1:59' 21171 311. 1. 33 •• I 014. _ 17449.46 _ X1.JP 1t T?P •RGFCx BOX;NSCT I'It.1 2.192' 3.91 1.23 2007.31 MEZEINI 15' ?75'NES-*DB'wPACi1OFF, 1 7y J0IFCX91a1 275' 479 , X,‘01111.1'(I'SC h$CT BOX w FZ'X P'76) IIIMENINEED 1 51.JT L•84: 7fr I5:SCT rusiNC(_TS 31D THRu 6301 2./97 3.04 1021.00 1 73.53 1114 13 SPACE>K P,..-PS 2 167 _ 3.14 58.74 73.53 1_,_ -, 3'C Sc ail-N$^i rUF0NG tJT M 4C 1 i _ l2.1r457� 3 11 32.03 U 71 X I 1 -14 - T - a 4 17'. .. . -•, -.. S t.90 24•T 26 71 4 7'7-..,SCT Pur:, 3.3,5 4 5 1.30 23 51 7411 Ttia:NG HA',C FR 3,95 4.3 41 2270 23-51 170y7jN 18 RICO EMINI72.70 1 22.70 111111..111.1=11111......111.1 • 11111111111=1I I Correction --- From the PDS 1 • Caliper survey there are only 338 full joints between the SSSVN and the X Nipple above the PBR INIMBINNIMmumminwos IIIIMMIIIMIIIIINMmmmm r � . 1 t 9 • • • Junk Attachment PBU Y-24 SW Name MD Date Comments Y-24 12453 11/14/2007 WRP Rubber Element Y-24 13400 04/06/2010 Milled FasDrill Y-24 13432 07/31/1986 8" Perf Gun Centralizer Spring Y-24 13434 07/31/1986 34' x 2-1/8" Perf Gun & CCL 40 0 00 0 0 co 0 0 0 LO R o o O c o N O M M O M M O le In v r O Y` V m O O O O O U o 0 0 0 0 0 0 0 0 0 0 0 i M r` V O M O m M Cfl Cfl O O) q0 N N � l � � � � tf') T O O O 0 0 cl 0 0 0 M N O) N N- Y` N m M CO LO N N- CO o 0 0 CO N M - LO M CO CO M C) N LO O r` N CO d' O O CO M CO CO M O 0 1 1 1 1 1 1 1 1 1 1 1 1 1 H CO C O LO CO N- CO O CO M LO "Cr 'Cr V r` CO r- M 'Cr V V LO CO N CO O) CO CO CO CO CO I. 0 M O M M O CO NY M N N- M M M �O O N M N N LoLommcom M co Lo M m N N N N N N C) p EIIIIIIIIIIIII 4.1 M O M O CO CO CO cY D) NI- M N M N N N N N � r f- a 09 o O (0 0 0 0 0 '� CO J c CO CO CO CO 0 U J CO CO CO -1 -1 J J J -0 N * J J J Ce Np N N m N M v O *k *k mom ,_ MM O• (� O) O) CO U CO N N N _ N O mm C7 M CI O 0) �+ d7 O M N- O CO M N COO p OM (om r N CO . CO O N w C C O W P •NUUw U O c 00000 Z Z Z Z rYW W W W m m m m m m m O D I— Z_ _Z Z_ D J D J J J 0 • a) as m v rn CO Ln t N I� o) N O p_ O 1- r 00 Cp CO a) O O) v- M � cc o O) O) O co O O 0 0 0 0 0 0 0 I- a O I- LU I- — O CO LO t o) 0) I"- 0) N O Id' CC) M C 'Cr CO C.0 0 co CO o) .- M v- W 0 co 0) o) O O O > CO CO CO o) o) o) 0 I- w w cc 0 ❑ ❑ z Ili w ° w ❑ d I- F- -J a W y 5 5 Y U ° > Ca 0 0 a Y Y ° ix,L )0 r--CN c) () (N CV Ccp J J J d < u) a C ZMM0 J OUa MMC) M 0 < W W -I JJ ❑ JAW .- .- l. Z _ _ OJ o � aE as d o a = _ = Z -C * 00 0 W I- ❑ z V 2 2 2 O c~n co «a o ccnn z Tr 4.aN a < >"' 0 F- _ = .0 CO N N N N N M a CO CD l'•- O CO W CO CO ++ ... O M ) M M M CO av as L a) rY u) Y 0 0 co [C 2 O co coca u) co aw a a) 0 0 C O LL LL LL LL LL LL � IZa. aCLalZ a 0 t a) a a> F- ca o) CO CO CO O) o) 0 :9 00 0 CO CO CO CO CO 00 0 j j c o) o) o) o) O CS) W J Z 1 1 < 00 0 W 11 O 1J W N LL J ❑ w a Ili 0 W W <L W O. N O o) O N N QZ ❑ J F- J J J D O' Q O CO ❑ 1D1 W J J Q O W W < < 330- 33 (/) LL L.T. LL cn a CC m E ca z ';? - •cr y N N N N N N Li.. a u) 0 W N J W a } } } } }' >- Q Cl- m m u_ EL:LL cO cn a • • Packers and SSV's Attachment PBU Y-24 SW Name Type MD TVD Depscription Y-24 PACKER 3183.41 2750.89 7" Baker ZXP Top Packer Y-24 TBG PACKER 12521.74 8434.54 4-1/2" Baker S-3 Perm Packer Y-24 TBG PACKER 12795.36 8634.09 3-1/2"TIW Packer S • r Carlisle, Samantha J (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday, March 08, 2018 2:11 PM To: Carlisle, Samantha J (DOA) Subject: FW: Please withdraw 3 sundries Sam, Please handle. I have placed these 3 unapproved sundries in your confidential box. Thanx, Victoria From: Lastufka,Joseph N [mailto:Joseph.Lastufka@bp.com] Sent:Thursday, March 08, 2018 1:32 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Worthington,Aras J <Aras.Worthington@bp.com> Subject: Please withdraw 3 sundries Victoria, Please withdraw the following unapproved IA Squeeze sundries: G-11B(PTD#208-027) 15-48C(PTD#211-030) Y-24(PTD#186-113) If you have any questions or need additional information please let me know. Thank you, Joe Lastufka SIM Specialist Cell: (907) 227-8496 I Office: (907) 564-4091 _g , m ,,% .Subsurface&W JIs BP Exploration Alaska 1900 E. Benson Blvd. I Room: 778C I Anchorage, AK 1 • oR 2 2 201° WELL LOG TRANSMITTAL#903059582 AOGOG To: Alaska Oil and Gas Conservation Comm. March 11, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 3 h.5i2oic ren.K.BENDER RE: Leak Detect Log: Y-24 Run Date: 1/15/2016 and 1/24/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 Y-24 Digital Log Image filesSCANNED '° I 1 CD Rom 50-029-21608-00 Leak Detection Log 1 Color Log-each 50-029-21608-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MAAlza-oza-4) 6—eoteeet • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, February 18, 2016 1:45 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers,Jessica; Dickerman, Eric; AK, OPS PCC Ops Lead; Morrison, Spencer; Regg, James B (DOA) Subject: NOT OPERABLE: WAG Injector Y-24 (PTD#1861130)Inner Annulus repressurization post Patch set Attachments: Y-24 Wellbore Schematic 1-29-16.pdf All, WAG Injector Y-24 (PTD#1861130) had a patch set over the interval 10,087-10,117'MD to mitigate tubing by inner annulus communication on Jan 24, 2015. A subsequent passing MIT—IA to 2,500 was performed on January 25, 2016. However the Inner Annulus is still showing signs of Tubing x Inner Annulus communication. The well is reclassified as Not Operable unit tubing integrity can be restored. Please call if you have any questions or concerns. Thank you, Kevin Parks SCANNED JUL 2 7 2016 (Alternate' Whitney Pettus BP Alaska -Well Integrity Coordinator Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, January 29, 2016 9:51 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan-.AK,C D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr;..K, RES GPB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wal lace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK,, D& ojects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'Regg, James B (DOA)'; Morrison, Spencer - Subject: UNDER EVALUATION: WAG Injector Y-24 (PTD #1861130) A Witnessed MIT-IA Post Patch Set All, WAG Injector Y-24 (PTD#1861130) had a patch set over the interval 10,087-10,117'MD to mitigate tubing by inner annulus communication on Jan 24, 2015. A subsequent passing MIT—IA to 2,500 was performed on Januar:M2016, demonstrating the presence of two competent barriers downhole. At this time the well has been reclassified as Under 1 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well Iv! Re-enter Susp Well ❑ Other:Pull/Set Patch m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 186-113 3. Address: P.O.Box 196612 Anchorage, Development 12 Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service ® 6. API Number: 50-029-21608-00-00 7. Property Designation(Lease Number): ADL 0047471 8. Well Name and Number: PBU Y-24 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13550 feet Plugs measured feet RECEIVE D true vertical 9207 feet Junk measured See Attachment feet 16 2016 Effective Depth: measured 13508 feet Packer measured See Attachment feet FEBCC true vertical 9175 feet Packer true vertical See Attachment feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 43-123 43-123 0 0 Surface 3011 13-3/8"72#L-80 42-3053 42-2672 4930 2670 Intermediate 13099 9-5/8"47#L-80 40-13139 40-8889 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 13138-13153 feet 13138-13153 feet 13262-13272 feet 13272-13302 feet 13302-13332 feet 13342-13364 13332-13342 feet 13342-13364 feet True vertical depth: 8889-8900 feet 8889-8900 feet 8984-8992 feet 8992-9015 feet 9015-9038 feet 9046-9063 9038-9046 feet 9046-9063 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 2246 1160 1442 Subsequent to operation: 2770 1292 440 14.Attachments:(required per 20 AAc 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development ❑ Service ® Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG El GINJ 0 SUSP ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-721 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature CAS Phone +1 907 564 4424 Date 2/12/16 Form 10-404 Revised 5/2015 17T-L-- ..i I `l/JL RBDMS LL FEB 16 2016 Submit Original Only 4e� ‘ • Junk Attachment PBU Y-24 SW Name MD Date Comments Y-24 12453 11/14/2007 WRP Rubber Element Y-24 13400`04/06/2010 Milled FasDrill Y-24 13432 07/31/1986 8" Perf Gun Centralizer Spring Y-24 13434 07/31/1986 34'x 2-1/8" Perf Gun &CCL • Packers and SSV's Attachment PBU Y-24 SW Name Type _ MD TVD _ Depscription Y-24 PACKER 3183.41 2750.89 7" Baker ZXP Top Packer Y-24 TBG PACKER 12521.74 8434.54 4-1/2" Baker S-3 Perm Packer Y-24 TBG PACKER 12795.36 8634.09 3-1/2"TIW Packer • • w N 0 0 0 0 U) es COO O 0 N L Lo N �t U) :Tr � r 0 0 0 0 — 0 ; o0 oOco e Nr co cnco (ID � al• 01 CD N- � OD CO 0 •Cr 0 0 0 M N CD N Is Ns N CA CO CO Un N N- OO O r 0 0 M N M r In CON UD OO M r N T' Tr V T' Lo CD N r N CO �t CO C D CO CO OO CO 00 CO V-. CD Is CD N CO N- to M N O 'n CO r CO 0 r M M r to • Tr CO r CO ct d' Tt Tt CO N OO CO CO OO CO CO CO a.+ C 4) MO) M M 0 CO Tr Co N- r- M Lo cn M Cn 0 r r N M N N cq CO CO T... 0 M CO 0/ 0/ N N N N N N M r r r . . . . . . Q N MNOOMD ~0m0O0CnCNICOCND Ca›- j N CM N N N N N .Q a 1- c 0 0 0 0 0 0 0 0 U J J 000 co 00 OO CO CO OD co J J J J J J J J CNM NCIDN N 4-N •N in O - up (000) 0• ) 0) O Ri U !!„-c; UaoN !NI _ _ (V fV (V N T)3p In N- N- N N es N• v- N- N F O '' CO C'7 ' CY) CY) CV r r n) O O) 0)0 r C� N M N- N O CO M C 00 O O 0 Cn r N c OD r OO O J M M N In r N r r r r r W ihi< ( Z Z Z Z Z Z) WWWZ W W W W F' ZZZ DoonDDD � m m m 00 m to m OO f/) Z J J J I— • . • * m o E0 ui : iff, co 0 J J NN C 0 U COa J c t'a) W N 0 O U a z E fn +Oa re 1 a o • W u)= U U � � (i)Cn Y a - 0 o co U a ce a O N o o < Cl) - ? , 0 m o • Q w 0 •- E ' o _ c I- a c Y . O a p o 0U' CC aci ab•o a i:., Inc - < 0 E `- N C 0 a) ` 0I- c i * O -0 C 0 > Cl) II X II f- .�. 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N W Y W ? 7 F- p 0 O * O 2 p - Op (n D4_ pQa Qwzz F- w46 ._ a ZLL � Cl '" Z � a) O c �Zwap 0Q Wa (0 7) a OQ2Pal-Lo0 Zc � 2 3 zwi_ ? 22z g .co- � rn UJHwreetOO o00Jp aOUaaUcOw OU o : "_ _ow o � � naHa � O � � LJ � Ow � � � 0 JO o - - a) m -) Z � w w w � � o QQ m -) 2 H a a U � 0 -) -) o c v co -e * pW ct W * * a) LLM * W w0 O * * LA c a) a) : a' (n5Ja dv * O : a' QQa0Ce F- : : N2 co 02 0 co 0 co r O O O 0 y N N N N N I o N N N in N in N m N r r r 1F4-t= 3-1/8'MCEVOY WE LFEAD= PA. VOY� • Y�2 4 ON SAFETY WELL REQUIRES NDTEB:MS A SS31/WHEN ON MI"AVERAGE 125 ppm W3�1/4T AA ____...... OTIS 1_._..-_ TALLY(11/30101)UST 339 RLL JOINTS BETWEEN SSSVN OKE.ELEV= 88.85' I &X NP ABOVE PBR PKii(OILY 338 JOINTS). DEPTHS BF.ELEV= 51.35' --- —- ISM SSSVN-OVERSHOT i� LI -C- REFLECT CAPER(02/15107)"" ' 6900' 20'COPDIx'rOR ® • LAST TD @ 13434'W A 2.2"OD CENTRALIZER-03127100. xAngle- 5E3 Angle.. .............5.____.....0_ Datum kV= 13138' Datum TVD-=- 8800'SS ) 2027' H3-1/2'FES XDB SSSVN,D=2.75' 13-38"CSG,72#,L-80 BTRS,D=12.347' 3053' TOP OF r SCAB UR -I 3171' 3171' H9-5/8"x 7'BKR ZXP PKR/HGF,D=6.31' ►. i r SCAB LHR,26#,L-80,.0383 bpf,D=6276" - 6800' • • Minimum ID = 1.81" @ 10083' -10120' 10083'-10120' 3-12"WFD SPECIAL CL AK 3-1/2" WF D ONE TRIP PATCH OPE TRP PATCI D 1.81"(01/25/16) ESTMATED TOP OF Ca 47'(02/29/10) H 12302 .•.4. MENG PUNCH(02/13/10) H 12450'-12452' 74';`• .•4 12488' -I3-1/2"FE5 X143,13=2 75' /•/•• 1.•$• ,•••1 •• •t A 12492' }--I BKR 80140 PBA;D=2.95' 11 `t�=i :'v. 12506' I--9-58'X 3-1/2'BKR S-3 FKR,D=3.875' lea 3-1/2'TBG,9.2#,L-80 NSCT, --12610 ' I 12566' 1-3-1/2"HES XN NP,kt.LED TO 2.74'(01/02/02) .0087 bpf,D=2.992' 3-1/2"TBG STUB(11/26/01) -I 12623' 1-1 12618' H UNQIJE CUSTOM OVERSHOT CMT SHEATH(02/28/10) -I 12700'-12806'CTM •.'Sf( 444 12743' H3-1/2"OTIS SLD SLV,D=2.750" ,�'1( I I '1��� 12795' H9-5/8'X 3-1/2'TNV I-BBP-R PKR 3-1/2"TBG,9.31/,L-80,.0087 bpi,D=2.99T -I 12795' WW1. '� 12824' H3-1t2"X 2-7/8'X0,D=2.38r ►�•�• ►� t ►♦• r 12860' --12-718"OTIS X NP,D=2.313' ►•••i r•• �1 ♦•• ♦♦ R•i ► I 12868' H9-5/8"X 7'BOT LNR HGR w/TI A CK,D=_' ►moi ►�. •,412893' H2-7/8"OTIS X NP,D=2.313' 2-7/8'TBG,6.4#,L-80,.0058 bpi,I)=2.441' -I 1292T Ig►..i •V 9-5/8'CSG,47#,L-80 BUTT,D=8.681 -I 13138' • �_���'1 & 12927' 2-7/8'WLEG,D=2.441' 12896' --113.M)TT LOGGED ON XX/XX/XX J FERFORATION SUMMARY REF LOG: STAG-BI-OM ON 07/12/86 IL ANGLE AT TOP PERF: 43"@ 13138' ' Note:Refer to Reduction DB for historical perf data 13164' 1Hr MARKER.JONT SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-1/8' 6 13138-13153 0 02/19/89 I 13400' H FISH-MLLES FASDRILL(04/06/10) 2-1/8" 4 13262-13364 0 09/10/88 ? --I FISH-WRP ELEMENT 4T(06/17/07) 1 . 13432' -ASH 2-1/8'X 8'FEW GU'YBU-LNOSE 7'LW,26#,L-80 U4S,.0383 bpf,D=6.276" H 13433' — 91104. RALIZER SPF XO 7"UNI,29# - 13434' H FIST t 34'X 2-1/8'PERF GUN,&CCL TOP Pe-ro -3 13508' 1.1..1114 7"LHR,29#,L-80 BTRS,.0371 bpf,D=6.184' H 13660' F•.•.•.•.•.•.•.•a DATE REV BY CONSENTS DATE_REV BY COMMITS PR UDHOE BAY SNRT 07/18186 AUDI INTIALCOMPLETION 01/07/16GJB1JA)FILLS)R(RBPATCH(01/03/16) WELL Y-24 12/04101 D-15 fil1VO 02/10/16 OHS/JM)SET WFD ONE TRP PATCH(01/25/16) PERNI T No:'1861130 03/18/15 STF/PJC RLL PATCH AR Pb: 50-029-21608-00 03/31/15 RRW/PJC M1 RESTRICTION @ 12500' SEC 34,T11N,R13E 1349'FTC,83'FV& 04/04/15 JCM'PJC SET STRADDLE PATCH 05/08/15 .LS/PJC SET WFD PACKER.@ 10085' BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, January 29, 2016 9:51 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M IL;AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA); Morrison, Spencer Subject: UNDER EVALUATION: WAG Injector Y-24 (PTD #1861130) AOGCC Witnessed MIT-IA Post Patch Set Attachments: Y-24 Wellbore Schematic 1-29-16.pdf All, WAG Injector Y-24 (PTD#1861130) had a patch set over the interval 10,087-10,117'MD to mitigate tubing by inner annulus communication on Jan 24, 2015. A subsequent passing MIT—IA to 2,500 was performed on January 25, 2016, demonstrating the presence of two competent barriers downhole.At this time the well has been reclassified as Under Evaluation to facilitate regulatory compliance testing.The annuli are fluid packed, and will be susceptible to thermal expansion. Plan forward: 1. Operations: Put the well on water injection SCAT NEL) JUL 2 5 2016 2. DHD: Perform AOGCC witnessed MIT-IA A copy of the revised wellbore schematic has been included for reference. Thank you, Laurie Climer (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator r± .x111h1e,'.s, t7 Organizat;on WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 • • OF!Tye THE STATE Alaska Oil and Gas LI/%ins A Conservation Commission 333 West Seventh Avenue = _ �- Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907.279.1433 04t,1„��,i��1:` Fax: 907.276.7542 ALAS�� www.aogcc.alaska.gov Kristine Odom suMED AN. 9 r( 3113 Production Engineer P & Y Pad vc (40 4 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool,PBU Y-24 Sundry Number: 315-721 Dear Ms. Odom: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Qt4- Daniel T. Seamount, Jr. Commissioner DATED this 7 day of December, 2015 Encl. JC RBDMS DEC 0 91015 STATE OF ALASKA IIIALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROV 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 • Repair Well Q Re-enter Susp Well 0 Other µb. P Tlk i 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 186-113 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service Q 6. API Number: 50-029-21608-00-00 , 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? - Will planned perforations require a spacing exception? Yes 0 No Q PBU Y-24 9. Property Designation(Lease Number): 10. Field/Pools: 2 4 7019 ADL 0047471 s PRUDHOE BAY,PRUDHOE OIL ' NOV'V 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(h): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13550 • 9207 13508 . 9175 - See Attachment• Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 39-119 40-120 0 0 Surface 3013 13-3/8"72#L-80 40-3053 40-2672 4930 2670 Intermediate 13101 9-5/8"47#L-80 38-13139 38-8889 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment , See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment , No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program Q Exploratory 0 Stratigraphic 0 Development 0 Service Q 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG Q , Abandoned ❑ Commission Representative: Op Shutdown ❑ GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Odom,Kristine Email Kristine.Odom@bp.com Printed Name Odom, Kristine ///7 Title Production Engineer P&Y Pad /?..7/v) Signature --.1 .02 .4../....---a4._ �C -•�s���^ -- Phone (907)564-5365 Date 1, t — COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 315 — 72k Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 1V �LocationClearance ❑ Other: �L Wr ne ,.7e K /A t T2,4 ��I S'1-11.411 i(.*L e. ( 1 . Spacing Exception Required? Yes 0 No 0 Subsequent Form Required: /O - Li Oil Approved by42,-..--- APPROVED BYTHE COMMISSIONER COMMISSION Date: 12 (7l/3 lith 400T" 0 3Z /2-1—/s." 2 -f ORIGINAL A ��� /�� -,���``� ( RBDMS` Det, 0 91015 Submit Form and Attachments in Duplicate Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. 0 0 Junk Attachment PBU Y-24 SW Name MD Date Comments Y-24 12453 11/14/2007 WRP Rubber Element Y-24 13400 04/06/2010 Milled FasDrill Y-24 13432 07/31/1986 8" Perf Gun Centralizer Spring Y-24 13434 07/31/1986 34' x 2-1/8" Perf Gun & CCL • • m w 2 p, O O O O O O o M o M O O M O M CO 18 CO f ° O L0 L0 r 0 N d' 0 ,0r 0 0 0 0 r T T r r r U +r o 0 0 o c0 L 000000 Moo omocococo 3 d1 M N N r T T r r to m M r- M M 0 0 0 0 0 0 T T r r T O N O) N f- f� N M O W LO N 1� 00 O T O 00 cM N M T In M CO M M r N M d' Nr M M I� r N 00 t O) O) CO 00 00 COMM PIIIIIIIIIIIII H r O) O1 N M ti O O O CO M M r M W T M M r In CO) 00 00 00 00 00 O) MO O d O O) M M M M t!) r T N M N N 2 `- d' M Co to o 0o m T MO M M M N N N N N N Sr r r r r r r r r O p ne 4.1 •Fo d' < 01i C) OaoOMOOov ` M MMM M N' M M N M M M N N N N N r r co IL I-- LSO 0000000 o 00000 COW COMM 0'I U J J O O 00 J J J J J J J •y (• n - CO CO O) r O O T O O CO U -00 co N N N _ _ U NN NNao N M 711 M M M N C 000 O O CNO N co co O a, M M N In r N T T T r w • W a 7500 o• p Q 00000 Z Z Z Z Z Z Z W W W W W m m m m m m m ODIZZZZDDDDDDD _ IQzJJJF- HHHHHH • d • U, C0 v0) aoI-0 v- N N O x- p, O 00 CO M a) 00) M • co a 0) 0) 0 0 0 0 a CO O) O) O) 0) O) 9 H C2 0 I) f- r 6) a) IC) « O) O) N- 6) N O Cs M M V' 00 O 0 d co O co d' W a M O O O O O 00 00 CO 0 0 0 0 I- W 0 0 0 cn W W ° W 0 F- 1- --I a W gg Y " ° o 00 w Y Y g J U U W W a' IC) t- O M O J J J d d U) Z d CM M M M M M 0 0 0 J W o o a a g 0 0 0 w qa z ~p z LU LU CL 2 O ui cn can J) c RS TrQ ti a. N O t 00 N N N.N N = O p CO CO N- O M ct O J a) '- NNMCOel a CO CO M CO M M caca y0 co cc J = 0 0 d J a AL 2 2 2 O cn cn Cn En cn W a 0 0 c u. u_ It u. u. LL ;oQ- o- aaQ- a < a 0 C) m a m 0 0 co co co 0 0 0 OO O 00 00 OO 00 0 j D c O O O CO 6) O Z I.L 1 < W W N u_0 0 0 0 0 0 W 0 LI J O W Z a J' W 9 0 W W u O N N a 0 0 ° J J J a s 0 0D 0 E 7 E W --IJ a O W W < ama. mcn IL IL a co a s a) E R z N N Nu_ a U) 0 LL N a N N N N N N J › > >- >' > > a s m m u cn cn d cc 0 I Packers and SSV's Attachment I ADL0047471 SW Name Type MD TVD Depscription Y-24 PACKER 3183.41 2750.89 7" Baker ZXP Top Packer Y-24 TBG PACKER 12521.74 8434.54 4-1/2" Baker S-3 Perm Packer Y-24 TBG PACKER 12795.36 8634.09 3-1/2"TIW Packer TREE= 3-1/8"MCB/OY WELLHEAD F. MCEVOY • -2 SAFETON MI*lf�ELL REQUIRES A SSSYWHENS AVERAGE I25 ppm ON MI WHEN 3-1/2" ACTUATOR= OT8S TALLY(11130/01)UST 339 LL JOINTS BETWEEN SSSVN 01(B.Bill= 88.85' I I M FU &X NIP ABOVE P13R PKDEPTHS (ONLY 338 JOINTS). THS BF Bill= 51.35'1 / SSSVN-OVERSHOT REFLECT CAUPB2(02115/07)'*' KOP= 1050' --- Max Angie= 58'@ 6904' 1 20"CONDUCTOR H ? ® LAST TD @ 13434'W A 2.2"OD CENTRALIZER-03/27100. Datum MD= 13138' Datum 1VD-_.. 8800'SS L 2027' -H3-1/2"HES XDB SSSVN,D=2 75" 13-3/8"CSG,724,L-80 BTRS,D=12.347" H 3053' / s CoNO'''. TOP OF r SCAB LM -I 3171' lt_ r 3171' H9-5/8"x 7"BKR ZXP PKR I HGR,D=6 31" r SCAB LNR 264,1-80, 0383. bpf,D=6276" -I 5800' ►i L6a``I Vt Minimum ID 1/4" @ 10085 T 3-1/2" WFD STRADDLE PATCH 10085'-100971 WW 3-113 FD t t PKRD, =1.74"(05/08/15) 10092"-10119'i-3-1/2"WM)WIDE PAK,ONE-TRF,S1RDL I PATCH,OAL=27.D=1 785"'(04/04/15) ESTIMATED TOP OF CBWENT(02/29/10) -I 12302' t•4# tAtl 11 TUBING PUNCH(02/13/10) - 12450'-12462' 11*1 /11 12466' H3 112"F#S X NP.D=2.75^ SA 111. 1111 111*11 111 12492' BKR 80/40 PBR,D=2.95' i0i='1 12506 -29-5/8"X 3-1/2"BKR S-3 FKR,D=3.875" I Igwzill 3-1/2"TBG,9.24,L-80 NSCT, - -12610' f2566' H3-112"FES XN NP,MIL®TO 2.74"(01/02102) f.0087 bpf,D=2.992" 3-1/2"TBG STUB(11/26/01) I- 12623' 1_ 12618' -UNDUE CUSTOM OV BRSHOT I st-EATH(02/28/10) -112700'-12905'CIM i1i1ii 1 12743' H3-1/2"OTIS SLD SLV,D=2.750" OA I I 1/1 12796' 1_9-5/8"x 3-1/r Ttw H BBP-R PKR ►MI Z 3-1/2"TBG,9.34,L-80,.0087 bpf,D=2.992- 1- 12795' ' •-i-4 4 12824'22--3-112'X 2-7/8"X0,11)=2.387" ►•i•i 1,ii�4 ►••••, ►+a A 12860` I-2-7/8"OTIS X M?D=2.313` •♦• ►•'r' ►•#•• ►*4i*1 ♦•, ♦♦ •••••, ►•x•44 •••# • 'i� &, 12869' 9.5/8"X 7"BOT LNR HGR w!TIEBACK,D= " • #• •� �� 12893' --�2-7/8'OILS X M' D=2.313" 2-7/8"TBG,6.44,L-80,.0058 bpf,D=2.441" -{ 12927' 1►•: ►••4 0,41 t9-5/8"CSG,47#,L-80 BUTT,ID=8.681" H 13138'\ .4 ,�� 12927' 2-718"WLEG,D=2.441" 12896' —ELMD TT LOGGED ON XX/XX/XX PERFORATION StM4 RY REF LOG: SWS-BHCS ON 07/12186 , ANGLE AT TOP FERE 43"@ 13138' ' Nate:Refer to Production DB for historical pert data 13164' H7"MARCB2 JOINT SIZE I SPF t41B /AL OpriSgz SHOT SQZ 2-1/8" 6 13138-13153 0 02/19/89 I 13400' HASH-MLLE)FASDRILL(04/06/10) 2-1/8" 4 13262-13364 0 09/10/88 ? __HIRSH-WRP ELB 1T(06117/07) 13432'j---FISH 2-1/8"X 8^FERF GUN/BULLNOSE 7"LNNP,26#,1-80 U4S,.0383 bpf,D=6.276" H 13433' — API. CENTRALIZER SPRNVG XO 7"LNR,29# 13434' I--IMR 34'X 2-1/8"PERF GUN,&CCL TOP 1-1:76:1-151-1 13508' )1111�111111f11.4 7"LNR,294,1-80 SIRS,.0371 bpf,D=6.184" --I 13550' •�� 4 DATE REV BY COMMENTS DATE REV BY CONSENTS PRJDHOEBAY 1H1 07/18/86 AUDI 2 INITIAL COMPLETION 02/10/15 TJMJMD PATCH CORRECTION WELL. Y-24 12/04101- D-15 RWO 03/18/15 SIF/PJC FILL PATCH PERMT No: 1861130 02/08/14_JM PJC PULL MR RESTRICTION 03/31/15 f fl PJC PLL RESTRICTION @ 12500' API No: 50-029-21608-00 09/17/14 JM) MNNDR EDITS PER TALLES 04/04/15 JCM PJC SET STRADDLE PATCH SEC 34,T11N,R13E 1349'FPI,83'FML 10/18/14 CJS/PJC SET STRADDLE PATCH 05/08/15 JLS/PJC SET WFD PACKER @ 10085' 01/27/15 PJC PATCH CORRECTION BP Exploration(Alaska) • , • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: Y-24 Well Type: WAG Injection Well API Number: 50-029-21608-00 Well Activity Classification: Conventional 4 Activity Description: Patch Set Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR,bopd: Job T Estimated Cost, Ype: Mech-Patch $K: AWGRS Job Scope: PATCH TUBING/LINER Other regulatory None requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Yes Primary Required? Secondary ► ► Engineer: Kristine Odom Contact numbers: (907)564-5365 (907)460-6776 Well Intervention ► ► Engineer: Ryan Thompson Contact numbers: (907)564-4535 (907)301-1240 F IF Lead Engineer: Brian Glasheen Contact numbers: (907)564-5905 (907)545-1 144 Date Created: November 18,2015 Revisions(date,who,what changed): Current Well Status Information Water Rate Gas Rate or or Inj Rate FTP or Injection Date Oil Rate Gas Injection GOR Gas Lift Rate Choke Setting Pressure (bopd) (bwpd) Rate (scf/stbo) (Mscf/Day) Water Cut (psi) (°7°) (Mscf/Day) 11/17/2015 0 0 59 Current Status: Not Operable Shut In Inclination>70°at Depth(ft) N/A Recentppm) NA 0 Maximum Deviation(Angle and H2S (date, ppm Depth) 58° 6,900'MD Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and N/A Depth) Reservoir pressure(date, 1.74"@10,085'3-1/2"WFD Repair prig) 5/3/2015 3,326 psi Minimum ID and Depth Packer Reservoir Temp,F 205°F Shut-in Wellhead Pressure (� Known mech.integrity MIT-IA to 2500 psi extendedmonitoring, i passes but fails under continues to repressurize 136 psi/day .. problems(specifics) V� Last downhole operation operation) 5/8/2015 3-1/2"Weatherford Repair Packer set at 10,085'MD Most recent TD tag(date,depth, 5/2/2015 13,321'SLM 5'x 1-1/4"STEM, 1.73"CENT, 1-1/2"S-Bailer toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Equipment Checklist. Comments,well history, Y-24 is a troubled well that has had multiple down hole interventions to restore its integrity over its life.Diagnostics have background information, been attempted since August 2013 and the well still remains shut in.On October 19,2014 the well passed a MIT-IA to etc: 2500 psi after setting a patch over the hole at 10,106' MD. Unfortunately,while returning the well to injection the well 4' had no infectivity. It was determined that the cement stringers from a 2010 packer squeeze were bridged off with schmoo at 12,500'MD preventing infectivity.A coil tubing milling and SBG procedure was developed to clean up the well and establish communication. On March 30,2015 coil was able to establish an injectivity of 3.4 bpm at 1550 psi after jetting SBG and milling with a 2.74"turbo mill. Disappointedly,the well failed a MIT-IA to 2500 psi with a LLR of 1.5 bpm after the patch was reset from 10,096'-10,116' MD. It was noted that when slickline pulled the patch pre CT milling,they had to stop at the SSSV nipple at 2,027'MD and wait for the packer elements to relax-all elements and \•,‘,.(:).1slips were accounted for when brought to surface.When E-Line went in on April 4 to reset the patch they had to work past the SSSVN with 300 lb overpull. It was suspected that one of the packer elements were damaged while running through the SSSVN and not creating a full seal over the hole at 10,106'MD causing the well to fail the post patch integrity test when it initially passed in October. On May 7 a LDL was performed and determined the top of the patch to be leaking along with a small temperature anomaly at 600'MD.While on the job SL spent several hours cleaning up the Z� SSSVN to allow for a smooth patch run and stung in a repair packer patch into the top of the original WFD patch and the ik0well failed an MIT-IA again.SL determined that the LTP was not fully stung in and was pulled and reset,the well then lV3passed an MIT-IA to 2500 psi.With 2 barriers established,the well was put on water injection on May 25 and the IA ( exhibited reoress urination on water while under eval On.lune 4.the well nassed an MIT-IA hut failed on extended • • Well Intervention Details Suspected Well Proble : Slow TxIA communication due to patch not holding or multiple leaks Specific Intervention o - O..- tiv- : 1 Restore integrity and return well to operable status. 2 3 Key risks,critical issues: Mitigation plan: Turn down elements on 3-1/2"patch for special 1 2.75"ID SSSVN historically providing issues when clearance and creep in slowly when running patch pulling and running the patch. through the SSSVN(SL mentioned this did the trick last time)If issues occur,mill out SSSVN. 2 Depth control,LDL collars are difficult to correlate. Run spinner pass on E-line and flag line at leak depth. 3 54%wall penetration at 10,106'MD.Everything else< Derated tubing burst is 4674 psi and collapse is 4848 13%from 9/9/2014 caliper psi Summary Service Line Activity Step# 1 S D&T at WSL discretion(recently tagged TD in May), Pull two run WFD patch. 2 E Spinner pass,Contingent SSSVN mill,Set single run patch,contingent LDL. • 3 F Assist E-Line with spinner pass,post patch MIT-IA to 2500 psi,and contingent LDL if fail. Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production BOPD: MMSCFD: BWPD: Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Leave SI until integrity is restored. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies, Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: Slickline • • 1. Drift and tag at WSL discretion, TD was recently tagged in May. 2. Pull 2 run straddle assembly, inspect patch and note any damage in the WSR. e.,(oots • ) 3. RDMO. E-Line 1. RIH with spinner and CCL to identify 1.5 bpm tubing leak at 10,106' MD for depth control. i) RIH at 90 fpm or max speed and stop at 10,250' MD. ii) Have LRS pump on the IA while pulling up pass. iii) Flag line at depth of leak. POOH. 2. RIH with 3-1/2" Special Clearance Patch, if issues arise at the SSSVN first try to creep in slowly (SL WSL noted this helped when trouble shooting the SSSVN previously). i) If unable to RIH smoothly through the SSSVN, pick up left hand motor and mill to open the 2.75" ID to 2.875"to allow for ease of deployment of patch through nipple. ii) Set patch with leak at mid element depth and avoid collars. Have LRS pump post patch MIT-IA to 2500 psi call PE if fail. 3. If post patch MIT-IA fails perform Tandem Archer LDL if LLR is <.25 bpm, perform STP LDL if >.25 bpm. i) RU LDL assembly and GR and CCL for depth control (GR is necessary because of difficult collar readings from previous LDL). Run LDL while pumping down the IA and taking returns to formation. ii) Before pumping any fluids, run baseline pass with LDL toolstring to the XN nipple at 12,566' MD. iii) After baseline pass is complete have FB begin pumping down the IA at a max rate but no more than 2500 psi with diesel, taking returns to formation. iv) Once the IA reaches 2500 psi at max rate, drop to a rate appropriate for logging and begin logging up pass at 30 fpm. Perform a station stops at the top and bottom of patch, at 600' MD and over any anomalies. Pay special attention to the packer squeeze interval from 12,506' MD to 12,302' MD v) Tie into tubing tally. RDMO. Fullbore Assist With patch pulled fluid levels should drop from surface to — 1,200 ft and reach equilibrium with the reservoir. If necessary, contact DHD to determine the FL on the IA after the patch is removed to order enough diesel for job. 1. Assist E-Line with spinner pass to flag leak depth. After E-Line reaches 10,250' MD come online with diesel down the IA as an overflush to activate leak path. 2. Pump post patch MIT-IA to 2500 psi. Load IA at max rate until pressure reaches 2700 psi, perform MIT- IA. Call PE if fail. 3. If MIT-IA fails assist E-Line with LDL. RDMO. • • Well Y-24 H2S Value 0 MIT#1 H2S Date 1/0/1900 Test Type MIT-IA Work Desc Target Pressure 2500 AFE APBINJEC Clear Data Max Applied Pressure 2700 Date 11/18/15 Test Fluid Diesel Engineer Kristine Odom Integrity Limits Confirmed ❑� Phone 9075645365 Hydrostatic calculations confirm derated tubing due to the 54%penetration at 10,106' Job Objectiw MD can withstand 2700 psi of diesel applied to the IA without holding pressure on other The goal of this procedure is to replace the current 2 run patch with a single run to allow clearance strings. for logging tools and confirm integrity by passing a MIT-IA to 2500 psi.ft is required to do a short spinner pass from 10,250' MD to leak depth of 10,106'MD to identify and flag leak entry because of poor collar signatures from LDL. MIT#2 Test Type Pump Schedule Target Pressure Stage Fluid Type Pump Into Volume(bbls) Rate(bpm) Max Pressure Max Applied Pressure 1 Over-Flush Diesel IA 25 1.5 2500 Test Fluid 2 Load Diesel IA 100 max 2500 Integrity Limits Confirmed 3 MIT#1 4 Over-Flush Diesel IA 150 max 2500 5 6 7 Detailed Procedure MIT#3 Assist E-Line with spinner pass,post patch MIT-IA to 2500 psi,and contingent LDL if MIT-IA fails. Test Type See attached procedure for details. Target Pressure Max Applied Pressure Test Fluid Integrity Limits Confirmed Directions When filling out the pumping template,please note the following: If"MIT' is selected as a stage,the corresponding MIT section must be filled out. The boxes are defined as follows: Test Type:Type of test to be performed (MIT-T, MIT-IA, MIT-OA, etc) Target Pressure: This is the requested MIt test pressure(ie MIT-T to 2500 psi) Max Applied Pressure: This is the max pressure that can be applied in order to achiee a passing MIT of the target test pressure, typically 10%greater than target pressure. BP practice 100218 (10-45)requires that the test pressure must remain aboee or equal to the target pressure during the entire test ewluation period. This pressure must not exceed the lowest rated working pressure(taking into account corrosion, erosion, etc) of any well barrier element in the well barrier en elope. Test Fluid: The fluid to be used for the test. Integrity Limits Confirmed: By checking this box,you haee confirmed that the"Max Applied Pressure"requested is within the limits of the wells"Well Barrier Envelope". • Fullbore Pumping Design Template 1/0/1900 0 ppm H2S(date/ppm) 2700 Max Pumping Pressure (psi) Diesel Main Fluid Type 100 Main Fluid Volume (bbls) Diesel Freeze Protect Type 5 Freeze Protect Volume (bbls) Surface 06/06/2015 Recent Tbg Fluid Level(ft) Surface 06/06/2015 Recent IA Fluid Level(ft) N/A Recent OA Fluid Level(ft) 5 Expected Tbg Fill Up Volume (bbls) 25 Expected IA Fill Up Volume(bbls) N/A Expected OA Fill Up Volume(bbls) 120 bbls Wellbore Volume to Perfs(bbls) 3326 Anticipated Bottom Hole Pressure (psi) Yes Tubing/Casing within Pressure Limits? Size Burst/Collapse 80%Burst/Collapse Tubing Burst(psi) 3.5 10160 8128 Tubing Collapse (psi) 3.5 10530 8424 Casing Burst(psi) 9.625 6870 5496 Casing Collapse (psi) 9.625 4760 3808 Select Input Depth Integrity Issues? Select 10,106'MD Select Yes-derate Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition Yes Production Packer within Pressure Limits? Rated Packer dp Max Anticipated dp at Packer Not Necessary Hold Pressure on Other Strings? Tubing(psi) IA(psi) OA(psi) TREE= 31/8"MCEVOY I _ _ _ W73LHEAD= MCEVOY Y-24 091MII-WELL REQUIRS AASSSVWHENNGS AVGEI25 ONMppmW sin- ACTUATOR= OTIS OICB.ELEV= 88 85, I ( TALLY(11/30101)UST 339 RLL JOINTS BETWEEN SSSVN &XMPABOVE PBR PKR(OILY 338JOINTS). STNS BF.EL.EV= 51.35' FROM SSSVN-OVERSHOT FERECT CALIPER(02/15/07)"" KOP= 1050' 20'CONDUCTOR ? LAST TD@ 13434'W A 2T OD CENTRALIZER-03127100. I43x Angle= 58'@ 6900' Datum MD= 13138'TV Datum ND= 8800 SS ,' 2-15071--i3-1/2"HES XDB SSSVN,D=2.75' 13-3/8'CSG,72#,L-80 BTRS,0=12.347' - 3053' / TOP OF 7"SCAB UV 3171'] r_. 3171' -9-5/8"x 7'BKR ZXP PKR/HGR,D=6.31' 7'SCAB LMS,268,1-80,.0383 bpf,D=6.276' - 5800• ! ►• Minimum ID= 1.74"@ 10085 i'3-12" WFD STRADDLE PATCH 10085'-10092'-I3-1/3WFD ERPKR,13=1.74"(05/o8/15) I 10092'-10119'I-3-1/2"WRD WOE PAK,ONE-TRP,STRDL PATCH,OA =27,D=1 785-(04/04/15) ESTIMATED TOP OF CEMENT(02/29/10) - 12302' 111 1.���� -mm (02/13/10) 12460'-12462' ,�"m 1•. 12466' 3-1/2'HES X NP,D=275', / • 111* 1111 NI 11 ;144 .• 12492' H BKR 80/40 PBR,D=2.95'I ',• &'d ..7••• 12506' H9-5/8"X 3-1/2'BKR S-3 PKR 0=3.875' ►M/ 3-1/2'TBG,5'28,180 NSCT. -12610' 1 ' 12566' -3-1/2'HES XN NP,MILLED TO 2.74'(01/02/02) .0087 bpf,D=2.992" 3-1/2'TBG STUB(11/26/01) - 12623' 1 12618' -U OUE CUSTOM OVERSHOT CMT SFEATH(02I21Ii10)l-F12700'-,12906'CTM 3 vifi 44�# I 12743' H3112"ITIS SLD SUV,D=2.750' tit 11.1( 111 12795' -9-5/8"X 3-1/2'TIN HBBRR PKR ►Mt ♦♦ 13112'TBG,9.3#,L-80,.0067 bpi,D=2.992' H 12795' 12824' -13-1/2"X 2-7/8'XO,D=2.387' a • r,/:•••1:1 12860' -2-7/8'OTIS X NP,D=2.313' 1k•• ��-w 6.`#$ Pt ; 12869' ,-9-5/8'X 7'BOT LNR HGR w/TRACK,ID= " ) I:: .00 esU 12693' H2-718'OTIS X NP,D=2.313'1 2-78'TBG,6.4#,1-80,.0058 bpf,D=2.441' 12927' OS• f. ►�• 9-5/8'CSG,478,1-80 BUTT,D=8.661' EIZIEMI ��� ,� MM.-2-718"MEG,D=2.441' 12896' -ELMD TT LOGGED ON XX/XX/XX I PEZF`ORATON S&M4ARY RIF LOG: SWS-BI-CS ON 07/12/86 ANGLE AT TOP PERF: 43'@ 13138 ' Note:Refer to Production(B for historical pert data SIZE SFF NTERVAL Opn/Sqz SI-OT SOZ 13164' �-7'MARKER JCXNT 2-1/8' 6 13138-13153 0 02/19/89 ' 13406' -FISH-MLLED FASORLL(04/06/10)1 2-1/8' 4 13262-13364 0 09/10/88 ? -FISH-WRP ELEMENT(06/17/07) • NMI -F15/t 2-1/8"X 8'FEW GU NSU_LNOSE CENTRALIZER SPRNG 7'LNR 260,1-80 U4S,.0383 bpf,D=6.276' H 13433' — XO 7'UST,290 I 13434' HFISII 34'X 2-1/8'FERE GUN,&OCL TOP MID 1 "---1- 1..11111, 7'LNR,29#,L-80 BTRS,.0371 bpi,D=6.184" H 13550' 1111111/1 DATE REV BY COMM1BNT'S DATE `REV BY COMMENTS R3AMOEBAY UNIT 07/18/86 AUDI 2 INITIAL COMPLETION 02/10/15 TJMYJMD PATO-I CORRECTION WELL: Y-24 12104101 D-15 RWO 03/18/15 STF/PJC PULL PATCH PBRMT No: 1861130 02/08/14 JM PJC RILL W1RPY RESTRICTION 03/31/15*WI PJC PLL RESTRICTION @ 12500' AR No: 50-029-21608-00 09/17/14 JAM MNNDR EDITS PER TALLES IFS '04/04/15 JQ4 PJC SET STRADDLE PATCH SEC 34,T11N,R13E 1349'FNL,83'FWL 10/18/14 CJS/PJC SET STRADDLE PATCH 05/08/15 IS/PJC SET WFD PACKER @ 10085' 01/27/15 PJC PATCH CORRECTION BP Exploration(Alaska) • II_ , 1 TUDING SUMMARY „_,.... RIG DOYON 18 DAV 110,J,; , ( BPI AL , WEL.• DS Y.241 TUBING 35' 130 Kw _ TOG INT 1120 432 JT8 04 RACK 4(1 JT$RA 4 7" ,J 01ç13 TO 171 -... 13379.86 FT ON RACK 12316.1 FT RAN ITilt4 0•4enptior incluces 6128,TYPE COMNETIC1,1 1.JTS LI) 10 1 00 i.ENGTh ; TOP I. 80 T1OAt • LINIGUE CUSTOM OVERSHOT 15625 1.25 7 3: 12611.49 t '2519s' RP JOINT mg; 194 0 11 . 12807 13 t 2417 is, 1 JOINT itu.;:1,7 NSCT MING 2.937 3.96 3023 1257i 13 1243143 otA Ju31 (3 1c4"L"40 P15CI1 2137 1.96 Oil 12567 55 12572.13 Xli hi PP",F 2 75 01111311111.11111EMMI 1242 55 PUF JONT 6 17140 NSC/1 1E12111111113M1111111111MIN 12541 42 I JUIN1 1.-61.; J 141 NS_1 'UtlIN11-; ming.0 3043 12521 25 17131 65 P P orNIT(i 1 V PC.:11 1111131111111KM11 12611 39 1732' ii'.- Jig);.4 1/2"NSCT ficx II 3 1r 4SCT Ply, =am 1.90 12501 49 12511 39 9:AO'3-3 PAC'ER 2S5A.0 MEM= 1250480 11509,49 /VC!3 lir NSCT BOX it 4 IT NSCT PIN, WM/WM 1.10 12503 05 12584 33 gio e3 pi-Eru ROX ii VT 1.6(7 PIN, 2137396 1 10 12501 35 1 12503,05 8040 POR alliellillemano 124174 12501.35 • MIIIIIIIIIIIMMI 1243774 1247./1 (2'i ITS:NM ABOVE Si4OWN IN S-3 ASSEMBLY TkLY 111111111Mm. 11420 74 I 1247.74 1111111111.1.1=1.1 12487 74 1247 74 SEAL ASSEMa.Y(SEA.U11,1 11 5'..0153 215 IMEIMEN 124$'37 1247,74 x.,0 2137 a!II = 12435.41 r 12487 37 ruar4CPur iffaggrognin 12472,54 --1 2/MT-- X:0 PUP il.-80 FOX BOX ir NSCT PIN 2 992 3.98 NM 11470.21 12479,54 X'O PUP IL-80 NSCT BOX x FOX PIN 2192 3.98 Maial 1246044 12470.21 7 Pr rFS'x NIPPY E W:PIP RHC-M 2 70 Illen 1.00 111031111111 12430.64 TUBING PUP(1,40 NSCT I 2 992 memonia. 1244166 12459.64 - Be.11%L•ao ill NSCT TUBING(J1S 1 71111U1191 isitymEn 10433)0 20-15.55 -11449,86 Xf)PUP tl,.40 FOX 80X•NSCT PIN 111.11Mall 323 2007 31 2016.44 - 3 5" 2 75'HFS'XOF w:PACKOFF. 1 75" D(FOX BiP1 IMEGMED 322 200409 200731 K.:0 PUP 1L-80 N5CT BOX x FOX PIN; 1 992 IlErn 9.56 , 199453 2004 01 61 JT L.863 1!?NSCT TUBING LITS 340 THRU 400) Ilingillan 1121 CO 7)33 1934.63 PACER PUPS 11/1211EINEMII 68.74 7343 IIMIESIME43111113 32.03 2611 51.14 41111FMEMIUMNIMINEINIFE33INIV 1 30 74 It 21 71 4 IT NSCT PUP 34 ..5 4.5 1.30 23 St 24,51 ._ TUBING MANCatI4 3.95 46 .81 22.70 23.51 DOYON 16 RK8 ME an . 22.70 1111.11111111111111111111.111.1111111 • IIIIIIIIIIIIIIIIIIIIIII ummil. Correction --- From the FDS MEM 1111inimmoommi Caliper survey there are only 338 m • M full joints between the SSSVN IN IIIIIIIII and the X Nipple above the PBR. Elmo IE , NMI ' IMINIIIIIIImml 1111111111111111110.1.11111111111 . • • Current Patch in Hole Client:BP Well No:Y-24 Job Type: Packer Weatherford Client Rep:n/a Rig:n/a Date:May 6,2016 Contact:n/a Field:West Operating Area Location:Prudhoe Bay Prepared By:William Gainey/Igor Smimov Contact: ALL TOOLS DRIFTED IN SHOP BY n/a BHA Description OD ID Connection Length S/N (in) (in) (ft) Top of Packer 10087.10' 1)ER Packer 2.72 1.81 2.87 BP350007 Setting force 7x3175=22225 lb Release force I 8x700=5600 lb Setting Depth 2.27' Center of Element 10089.4' to TOP of Packer 2)Spacer Pipe 2.375 1.992 2 3/8 10 rd NU box 1.02 3)Anchor 2.72 1.74 2 3/8 10 rd NU box 2.47 BPS3500 Swapped from CP to BP Release force 6x925=5550 lb 4)WidePak One-Trip Straddle Packer System 4.1)Upper Wide Pak Packer 2.72 1.785 Special Profile 5.43 BP350038 Release force 4x1200=4800 lb 1.35' Center of Element to BOP of Packer 4.2)Spacer Pipe 2.375 1.975 2 3/8"ACME 9.07 $./.‘+ 4.3)Coupling 2.71 1.975 2 3/8"ACME 0.93 4.4)Spacer Pipe 2.375 1.975 2 3/8"ACME 7.06 Q 0/ 4.5)Lower Wide Pak Packer 2.72 1.785 2 3/8"ACME 4.8 BP350039 Release force Ui 4x1200-4800 lb 3.05' Center of Element to BOP of Packer I Comments: For release WidePak One-Trip Straddle system you need to use spetial tool Max O.D. & Min.I.D. = 2.72 1.74 Total BHA Length. 33.65 Please note that all OD's&ID's are approximate,and are given as guidance only TRADE SECRET AND CONFIDENTIAL Copyright©%ea[herford Inc. WELL SERVICE REPT WELL DATE JOB SCOPE DAY SUPV Y-24 6/4/2015 ANN-COMM MOORE-RYAN AFE CODE DAILY WSR COSTS DAILY WORK NIGHT SUPV APBWEINROT $915 AC-MITIA HOLT MIN ID DEPTH TTL SIZE KEY PERSON UNIT 0" 0 FT 0" CH2-WOMAC KEVIN NONE DAILY SUMMARY T/I/O= 1550/284/210. Temp= 125°. MIT-IA to 2500 psi FAILED on extended monitor. (Eval TxIA). On PWI. IA FL© surface. Pumped 8.9 bbls diesel to increase IAP to 2500 psi. OAP increased to 388 psi. IA lost 45 psi in 1st 15 min& 19 psi in 2nd 15 min for a total loss of 64 psi in 30 min. Extended monitor period an additional 1 hr 30 min for fall off rate, losses of:45 min= 14 psi. 60 min = 11 psi. 75 min =9 psi. 90 min = 10 psi. 105 min= 9 psi. 120 min = 11 psi. Bled IAP from 2367 psi to 280 psi (8.4 bbls). OAP decreased to 175 psi. Hung tags on wing valve chain& IA casing valve handle. Monitored IA BUR for 2 hrs. IAP increased 103 psi &OAP decreased 15 psi. Final WHPs= 1540/383/160. SV= C.WV, SSV, MV=O. IA&OA=OTG. 16:40 LOG ENTRIES !nit Tbg, IA,OA-> 1,550 284 210 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 09:33 Road to location w/triplex from J-Pad. 09:58 Arrive on location, spot equipment. 10:04 Site control/Job walk down/PTSP update. 10:16 RAP w/Pad Op/PJSM 10:26 1550 285 210 WHPs& IA FL @ surface. 10:31 " " " Rig up 10:59 Fluid pack surface lines&begin pressure tests 11:19 Surface line tests passed. 11:24 Diesel Amb 1555 284 207 Start pumping down IA. 12:02 8.9 " 1563 2500 388 SD pump, begin monitor 12:17 1560 2455 382 15 min into test. IA lost 45 psi. 12:32 1556 2436 375 30 min into test. IA lost 19 psi.Contact WIE. 12:47 1555 2422 369 45 min into test. IA lost 14 psi.Will run test out an additional 30 min for fall off rate. 13:02 1564 2411 363 60 min into test. IA lost 11 psi. 13:17 1565 2402 358 75 min into test. IA lost 9 psi. 13:32 1571 2392 352 90 min into test. IA lost 10 psi. 13:47 1568 2383 345 105 min into test. IA lost 9 psi. 14:02 1568 2372 338 120 min into test. IA lost 11 psi. 14:07 1565 2367 336 Start IA bleed to slop tank. 14:36 1570 280 175 SI IA bleed, begin monitor& rig down 15:06 1570 339 150 30 min into post bleed monitor. 15:36 1560 363 150 1 hr into post bleed monitor. 16:06 1550 379 160 1 hr 30 min into post bleed monitor 16:36 1540 383 160 2 hrs into post bleed monitor. Final Tbg, IA, OA->115401 383 160 MIT TEST WELL TYPE PWI TEST#1 REQUIRED TEST TEST TYPE FLUIDS USED TO TEST PRESSURE MIT-IA DIESEL 2,500 START TIME: 12:02 PRE TEST INITIAL 15 MINUTE 30 MINUTE PASS OR PRESSURES PRESSURES PRESSURES PRESSURES FAIL TUBING 1,550 1,563 1,560 1,556 IA 284 2,500 2,455 2,436 FAIL OA 207 388 382 375 COMMENTS Ran test out an additional 1 hr 30 min for fall off rate per WIE request. Losses:45 min= 14 psi.60 min= 11 psi.75 min=9 psi. 90 min = 10 psi. 105 min=9 psi. 120 min= 11 psi. • APT WELL SERVICE REP WELL DATE JOB SCOPE DAY SUPV Y-24 5/4/2015 LEAK DETECTION LOG KERKVLIET AFE CODE DAILY WSR COSTS DAILY WORK NIGHT SUPV APBWEINRSL $13,771 LOG-LEAK DETECTION SAUVAGEAU MIN ID DEPTH TTL SIZE KEY PERSON UNIT 0" 0 FT 0" SWCP-COPE SWCP 4522 DAILY SUMMARY ***COTINUE FROM WSR 5/3/15*** RUN HES DPU&WEATHERFORD 10'x 3-1/2"ER PATCH S/D @ 2020'SLM, LRS ASSIST WHILE JARRING, UNABLE TO PASS RUN 5'x 2.72"DUMMY DRIFT, 5'x 1-7/8"STEM&2.74"SWEDGE S/D BUT FALLS THRU @ 2020'SLM. RAN 10'x 2.74"DMY WHIPSTOCK,2.72"DMY PACKER DRIFT 5'1-7/8"STEM,2.74"SWEDGE(total drift=oal 314")TO SSSV NIPPLE @ 2,013'SLM/2,027'MD(see log for details). RAN 20'x 2.74"DMY WHIPSTOCK,7' 1-7/8"STEM,2.74"SWEDGE(oal 32')TO SSSV NIPPLE @ 2,013'SLM/2,027'MD(see log for details). RAN 2.84"NO-CENT TO SSSV NIPPLE @ 2,013'SLM/2,027'MD. RAN 2.85"CENT TO SSSV NIPPLE @ 2,013'SLM/2,027'MD. RAN 20'x 2.74"DMY WHIPSTOCK TO 2,026'SLM(unable to pass,see log). RUN 10'x 2.74"DMY WHIPSTOCK,3' 1-7/8,2.72"CENT. PASS THROUGH SSSV NIP @ 2,013'SLM 5 TIMES(no issues) ***CONTINUE ON WSR 5-5-15*** LOG ENTRIES Init Tbg, IA,OA-> 150 200 [ Q[ TIME COMMENTS 00:01 CONTINUE FROM WSR 4-3-15 00:02 CON'T STANDBY FOR WEATHERFORD 00:25 LRS ON LOCATION, HOLD JSA AND PJSM****IN HOLE- PRIMARY: STUFF BOX/LUBE/LRS CHECK, SECONDARY: SSV/SWAB/WLV,***, LRS R/U TEST HOSE 01:15 WEATHERFORD BACK ON LOCATION, GET TOOLS READY 01:41 P/T QTS, RIH W/HES DPU,WEATHERFORD 10'x 3-1/2" ER PATCH S/D @ 2020'SLM,WORK TOOLS BY HAND, TOOLS NOT FALLING, LRS COME ON LINE 8.7 BBLS AWAY CATCH PRESSURE, MAKE SEVERAL MORE ATTEMPTS TO JAR PAST SSS NIPPLE, SAME SPOT, LRS INCREASE TO 2 BPM, USE UNIT ATTEMPT TO JAR PAST DEPTH, SAME SPOT, LRS DOWN ON PUMPS, 02:53 OOH DVI, SIBD,WEATHERFORD INSPECTING TOOLS. 03:28 STANDBY WEATHERFORD TAKING TOOLS BACK TO PRUDHOE 04:00 WSL CALLED WANTS TO RERUN DRIFT. 04:28 PT/QTS, RIH W/QC, 5'x 2.72" DUMMY DRIFT, 5'x 1-7/8"STEM&2.74"SWEDGE S/D BUT FALLS THRU @ 2020' SLM, CONTACT WSL, POOH, HOT SHOT TO WLB FOR TOOLS. 05:30 OOH DVI, SIBD, 05:50 ATTEMPT TO REACH WSL ABOUT NEXT RUN. 06:35 C/O FROM COPE TO OFFENHEISER, INSPECT LOC, PJSM. 07:34 PT QTS. RIH W/K.JT, 3-1/2"GR, 10'x 2.74" DMY WHIPSTOCK(DS-2741),2.72" DMY PACKER DRIFT(oal 69"), 5' 1-7/8" STEM, 2.74" SWEDGE (total drift=oal 314"). BOBBLE THROUGH SSSV NIP @-2,020' SLM/2,027'MD., PUH THROUGH NIP WI—400#OVER PUW, REPEAT MULTIPLE TIMES...POOH. 08:32 OOH, TOOLS CLEAN, M/U NEXT RUN. 09:32 PT QTS. RIH W/K.JT, 3-1/2"GR, 20'x 2.74" DMY WHIPSTOCK, 7' 1-7/8"STEM, 2.74"SWEDGE (oal 32'). MAKE 6 CLEAN PASSES THROUGH SSSV NIP @ 2,013' SLM, ON 7TH PASS WHILE PUH THROUGH NIP HANG UP @ 2,036'SLM (3 taps down &fall back through sssv nip), PUH & HANG UP AGAIN @ 2,036' SLM (jar up for 10mins w/no movement),TAP DOWN 3 TIMES& FALL BACK THROUGH NIP, PUH THROUGH NIPPLE W/VARYING SPEEDS& PASS THROUGH CLEAN,ATTEMPT TO RIH&S/D @ 2,036'SLM, PULL —400#'s OVER PUW TO COME FREE...POOH. 10:38 OOH, SMALL FAINT HALF RING MARKS ON TOP&BTM OF SWEDGE. 11:30 PT QTS. RIH W/2' 1-7/8"STEM, 2.84" NO-GO CENT, B.N., S/D ON SSSV NIP ©2,013' SLM/2,027'SLM (no issues)...POOH. 11:55 OOH, SLIGHT METAL MARKS ON OUTER EDGE OF CENT. 12:41 PT QTS. RIH W/2' 1-7/8"STEM, 2.85" CENT, B.N., S/D ON SSSV NIP @ 2,013' SLM . 2,027'SLM (no issues)...POOH. 12:57 OOH, 2.80"o.d. RING ON CENT(indicating s/d on —key profile of sssv nip). 13:40 PT QTS. RIH W/K.JT, 3-1/2"GR, 20'x 2.74" DMY WHIPSTOCK. S/D @ 2,026' SLM (unable to pass) PICK OFF CLEAN, JAR DOWN 6 TIMES W/NO MOVEMENT, JAR 5 TIMES&COME FREE, HAVE LRS COME ONLINE W/DIESEL A—1.5BBLS A MIN, LRS CATCHS PRESSURE AFTER—15BBLS AWAY, RIH&S/D A 2,026' SLM, HAVE LRS SHUT DOWN, JAR UP FOR 10mins&COME FREE...POOH. 15:02 OOH, LRS PUMPED TOTAL OF 22BBLS OF DIESEL DOWN TBG. (horizontal scrap marks–13'from btm of whipstock, looks like from the sssv nip). 15:59 PT QTS. RIH W/K.JT, 3-1/2"GR, 10'x 2.74" DMY WHIPSTOCK, 3' 1-7/8, 2.72" CENT. PASS THROUGH SSSV NIP @ 2,013' SLM 5 TIMES (no issues), RIH TO 2,050'SLM...POOH. 16 27 OOH, TOOLS CLEAN, HES&WFD ON LOC, M/U TOOLS. ***REMOVE OJS*** 17:50 C/O TO COPE, INSPECT LOCATION, HOLD JSA AND PJSM, 18:00 WEATHERFORD TAKING TOOLS TO PRUDHOE SHOP FOR INSPECTION 23:37 CONTINUE WAITING ON WEATHERFORD 23:59 ****CONTINUE ON WSR 5-5-15**** Final Tbg, IA, OA->J1— 200 0 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, July 30, 2015 1:19 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA); Morrison, Spencer Subject: NOT OPERABLE:Injector Y-24 (PTD #1861130)Inner Annulus Repressurization Attachments: Injector Y-24 (PTD #1861130) TIO Plot.docx All, Injector Y-24 (PTD#1861130) was placed on injection for further diagnostic work for Inner annulus repressurization.The inner annulus build up rate was 136 psi/day.The well in reclassified as Not Operable and will be added to the Quarterly Not Operable injector report. Plan Forward: 1. APE: Evaluate for repair/secure options. A copy of the TIO plot have been included for reference. Thank you, Kevin Parks ,nprr QED JUL 3 12015 BP Alaska-Well Integrity Coordinator GvkiGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDC\\WellIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, July 14, 2015 8:20 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, R PB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; A , D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'Regg, James B (DOA)'; Pettus, Whitney; Morrison, Spencer Subject: UNDER EVALUATION: Injector Y-24 (PTD #1861f30)-4dy to be Placed on Injection All, 1 • Injector Y-24(PTD#1861130)TIO Plot 1,4 �ry R f �Y (5.10..5 Rf.n 061•1f sx RA)! ROOS 00l16 RY.6 l7•BN 01 1! Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, July 14, 2015 8:20 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad VP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA); Pettus, Whitney; Morrison, Spencer Subject: UNDER EVALUATION:Injector Y-24 (PTD #1861130) Ready to be Placed on Injection Attachments: image001.jpg; image002.png; image003.png All, Injector Y-24 (PTD#1861130) is ready to be placed on injection for further evaluation. The well is reclassified as Under Evaluation to facilitate further diagnostics before initiating wireline interventions. Please use caution when placing the well on injection as the annuli are fluid packed. Plan Forward: 1. Operations: Place well on injection 2. Downhole Diagnostics: Bleed Inner Annulus pressure and monitor for buildup rate 3. Production Engineer: Evaluate for Slickline intervention as needed 4. Slickline Pending: Set plug on top of patch & pressure test TBG. If fails, perform a leak detection log. If passes, pull and reset patch. Thank you, Whitney Pettus (Alternate: Kevin Parks) JUL 1 5 2015 BP Alaska -Well Integrity Coordinator GWOganuat+or� WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C '- Integrity Coordinator Sent: Saturday, June I., 015 9:46 AM To: AK, OPS GC1 OSM; AK, •• .GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C WelServices Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East WellsO\gr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integ` oordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: NOT OPERABLE: Injector Y-24 (PTD #1861130) IA repressurization post tubing patch All, 1 tvo- t13 2zo k6 WELL LOG TRANSMITTAL DATA LOGGED PROACTIVE DIACINOSTIC SERVICES, INC. 7/16/2015 K BENDER To: AOGCC ED Makana Bender'�'° 333 W. 7th Ave Suite 100 JUL. © C u 1.) Anchorage,Alaska 99501 .�+ (907) 793-1225 Ai_,)la /1r RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. SCANNED -• Anchorage,AK 99508 gancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 03-May-15 Y-24 BL/ CD 50-029-21867-01 2] MAL-0?Signed : 1P) 640,czatDate : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEaMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archives\MasterTemplateFtles\Templates\Dtstnbunon\TransmittalSheets\BP_Transmit docx Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, June 06, 2015 9:46 AM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad YP; Odom, Kristine; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA) Subject: NOT OPERABLE:Injector Y-24 (PTD #1861130) IA repressurization post tubing patch Attachments: image001jpg; image002.png; image003.png;Injector Y-24 (PTD #1861130) TIO plot 06-06-05.docx All, Injector Y-24 (PTD#1861130) passed an AOGCC MIT-IA to 2500 psi on 05/31/15 verifying two competent barriers and a subsequent non witnessed MIT-IA passed on 06/04/15. However, the well is showing signs of increased IA repressurization post tubing patch. The well is reclassified as Not Operable and needs to be shut in and freeze protected until further diagnostics can be completed. The well will be added to the Quarterly Not Operable injector Report. Plan Forward: 1. Slickline: Set plug on top of patch and pressure test TBG, if fails perform a Leak detection log. If MIT-T passes pull and reset patch. A copy of the TIO plots have been included for reference. Please call with any questions. Thank you, SCANNED JUN 3 02015 Kevin Parks (Alternate. Whitney Pettus) BP Alaska-Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: AK, D&C Well Integr�Coordinator Sent: Tuesday, June 02, 2015-3:08 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;,..ALK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' 1 • Injector Y-24(PTD #1861130)TIO plot 06-06-05 y�/� +n5 ■ • :a - a OEM - OCIOAOsox or. 01095 03133is 031015 tar 15 O%[1'1S 011015 5l'17n5 0y4,5 Met IS 01:3^. 03 5 5 0s711s xi:Y•'. 050/15 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, June 02, 2015 3:08 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA) Subject: UNDER EVALUATION: Injector Y-24 (PTD #1861130) IA repressurization post tubing patch Attachments: image001jpg; image002.png; image003.png All, Injector Y-24 (PTD#1861130) passed an AOGCC MIT-IA to 2500 psi on 05/31/15 verifying two competent barriers. However, the well is showing signs of increased IA repressurization post tubing patch. The well is already classified as Under Evaluation and will remain on the 28 day clock. Plan Forward: 1. DHD: MIT-IA and record Build up rate (BUR) 2. APE: Evaluate plan forward for restoring tubing integrity or secure Thank you, Kevin Parks SCANNED JUN 0 9 2015 (Alternate. Whitney Pettus: BP Alaska -Well Integrity Coordinator Gv�Y y Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From ;.D&C Well Integrity Coordinator Sent: Sunday, May 24, 2015 11:38 AM To: AK, OPS GC1 OSM; AK, QPPPS GC1 Field O&M IL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East—Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrityyoordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; Pettus, Whitney; Worthington, Aras J; Sayers, Jessica; Weiss, Troy D Subject: UNDER EVALUATION: Injector Y-24 (PTD# 1861130) Place on Injection for Regulatory Compliance Testing All, 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 01,2015 TO: Jim Regg 'f 51!S P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC Y-24 FROM: Matt Herrera PRUDHOE BAY UNIT Y-24 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv1 - NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Y-24 API Well Number 50-029-21608-00-00 Inspector Name: Matt Herrera Permit Number: 186-113-0 Inspection Date: 5/30/2015 Insp Num: mitMFHI50531154157 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well'l Y-24 Type Inj W-TVD 8423 Tubing 1490 1490. 1484 -',1 1485 PTD 1861130 ' Type Testi SPT Test psi 2106 - IA 1514 - 2499 , I 2459 - j 2447 - Interval iI4YRTST PAF P /� OA 277 360 362—�_ 361 -- — 1 Notes: I SCANNED 1,1 `' ZU15 JUL� t Monday,June 01,2015 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday, May 24, 2015 11:38 AM To: AK, OPS GC1 OSM;AK, OPS GC1 Field O&M IL;AK, OPS GC1 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad YP; Odom, Kristine;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg,James B (DOA); Pettus, Whitney;Worthington,Aras J; Sayers,Jessica;Weiss, Troy D Subject: UNDER EVALUATION:Injector Y-24 (PTD# 1861130) Place on Injection for Regulatory Compliance Testing Attachments: image001 jpg; image002.png; image003.png All, Injector Y-24(PTD# 1861130) is ready to be placed on injection to perform an AOGCC witnessed MIT-IA. An attempt was made in November of 2014 to place the well on injection for compliance testing but an obstruction prevented injection from being established. A patch previously set in the well to repair tubing by inner annulus communication was pulled in order to facilitate wellwork to re-establish injectivity. A patch was reset on May 8th, 2015 and a subsequently passing MIT-IA on the same day confirms two competent barriers in the wellbore. At this time the well is reclassified as Under Evaluation to facilitate compliance testing. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1. Operations: Place well on injection 2. Downhole Diagnostics: Once thermally stable, perform AOGCC witnessed MIT-IA Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator G0'9}'i,:41 O'I WIC Office: 907.659.5102 SCANNED MAY" 2 7 2015 WIC Email: AKDCWellIntegritvCoordinator@BP.com From: , - - Integrity Coordinator Sent: Friday, November , s ' 9:13 AM To: AK, OPS GC1 OSM; AK, OPS GC1 - : •: M IL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Ope . s Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Enc , AKLOPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' ice\ L/Azer- Ek3 2.515.Z3 WELL LOG TRANSMITTAL RECEIVED II MAY 1 5 2015 PROACTIVE DIACINOSTIC SERVICES, INC. AOGCC To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage,Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. %AIMED Lu Anchorage,AK 99508 gancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) LeakPointTl'^Survey 07-May-15 Y-24 BL/ CD 50-029-21867-01 2) Signed : Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D Wrchrves\MasterTemplateFJes\Templates\DIstnbutwn\TransmittalSheets\BP_Transmit docx • STATE OF ALASKA , 3KA OIL AND GAS CONSERVATION COM, 3ION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon E Repair Well 0 Plug Perforations ❑ Perforate❑ Other 0 Mill Obstruction Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program❑ Operat.Shutdown D Stimulate-Other ❑ Re-enter Suspended W❑ 2 Operator 4 Well Class Before Work 5 Permit to Drill Number Name. BP Exploration(Alaska),Inc Development ❑ Exploratory El 186-113-0 3 Address P O Box 196612 Stratigraphic ❑ Serviced 6.API Number Anchorage,AK 99519-6612 50-029-21608-00-00 7 Property Designation(Lease Number) 8.Well Name and Number ADL0047471 PBU Y-24 9 Logs(List logs and submit electronic and printed data per 20AAC25 071): 10.Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary qECEiVED Total Depth measured 13550 feet Plugs measured None feet true vertical 9207 2 feet Junk measured See Attachment feet k AY 0 d 2015 Effective Depth measured 13508 feet Packer measured See Attachment feet A OG CC true vertical 9174 67 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 39 37-119 37 39.37-119 37 0 0 Surface 3013 46 13-3/8"72#L-80 39.87-3053 33 39 87-2672.24 4930 2670 Intermediate 13101 18 9-5/8"47#L-80 37.5-13138 68 37 5-8889 46 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 13138-13153 feet 13262-13272 feet 13272-13302 feet 13302-13332 feet 13332-13342 feet 13342-13364 feet True Vertical depth 8888.95-8900.24 feet 8.983.97-8991 71 feet 8991 71 -9014.99 feet 9014 99-9038 28 feet 9038.28-9046.05 feet 9046 05-9063 11 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary Intervals treated(measured) SCANNED MAY I 8 2015 Treatment descriptions including volumes used and final pressure: RJ 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 3405 1560 1446 Subsequent to operation Well Shut-In 260 1660 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt. 315-090 Contact Garry Catron Email Garrv.CatronaBP.Com Printed Name Garry Catron Title PDC PE Signature /6°1#1°'1 CIV-----)---- Phone 564-4424 Date 4/30/2015 vT'- 5711115- RBDMSJ MAY - 6 2015 .dot 7A4- II, Form 10-404 Revised 10/2012 Submit Original Orly ,i i 11 Y-24 186-113-0 Junk Attachment SW Name MD Date Description Y-24 12453 11/14/2007 WRP Rubber Element Y-24 13400 4/6/2010 Milled FasDrill Y-24 13432 7/31/1986 8" Perf Gun Centralizer Spring Y-24 13434 7/31/1986 34' x 2-1/8" Perf Gun & CCL ti �6 Packers and SSV's Attachment ADL0047471 SW Name Type MD TVD Depscription Y-24 PACKER 3183.41 2750.89 7" Baker ZXP Top Packer Y-24 PACKER 12521.74 8434.54 4-1/2" Baker S-3 Perm Packer Y-24 PACKER 12795.36 8634.09 3-1/2" TIW Packer t m N O O O O O O o O O O u) • co � TNr� O ,M ,Mococo tiLoin noo `n00 � — Lo in U 00 ooco L r- Trvccococococ0co (c) (.0 • 00 N N 0 0 0 0 0 0 CO CO N- 00 Tr 00 M r r co co O Tr N N N o Tr O co V (NI N O co • O O N O N 00 cd a) 00 O O M N M LU CO CO N CO CO V V oO 000 00 V O O N 00 00 co co 121 H • f" C N N- 10 co O co O O O •M O O O • CO N M O lf) 00 O 1� co co M r- CO co M co N CO O 00 M M alad = O co CO O co 00 Cr (C) V I� CD O CO CO LO V In Oco In ) LO CO CO O) a- CO CO CO O M N N N N N N I I •W M O CO O 00 (O CO �f ti M Qin N M co" ti O 00 M V O ma) O O O O M M M N co N N N CN ‘- la la• Q � J cpCO � OOo Q � O i O O O 00 00 co ' U Jco co co CO CO00 CO00 J J J J • N -p J J J N co* N N N CO Cr CO (0 _ C\ O \ O (fl Cl)• 0• N O N N N 00 N N N N N N 00 C) N OM CO CO CON t 1 O O co r- M OO O co co C �- co (fl N tTr co co O d CO N N J N- UJ H c OQ H w w UoCCCCcWZZZZZZZ Z W W W W CC CO CO 00 CO CO 03 00 O H Z Z Z_ D D D D D D D p C.) 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W chW 02 � _ = oN W a 2 0 < w O .O L+ Q < I— D Q OW a N W w < 0 4 a � � �= Z � � � z i ,.- _1 X 0 CO 00 co OwCC Lu W Z U) I U) D ° I- 2 Z w E Q"� co = c CC w a 0 O Z P w E w w- d I- v o °' c 0 J = Z O Z a H O F- W = z 2 ZI O N 0 � ° N 0 F- wo = ZUQ DU ° ooo ow � aim o � cO > CLpm I Qd ° �QCOO1- 2O t Z ago E - C (1U - : (J) UU) aE2 : 1= U Oco (i) (7 10 t) L0 O O O - ,- rn N N N N 00 N N co in m ,- N co 1 1 1T =- 3-1/8"MCEVOY Y SAFE )TES:H2S READINGS AVERAGE 125 ppm WHENWHIFEAD= MCEVO ACTUATOR= OTY-2 4 ON ML WELL REQUIRES A SSSV WHEN ON ML 3-1/2" ACT = 88.85' , TALLY(1113W01)LIST 339 FULL JOINTS BETWEEN SSSVN BF.H EV= 51.35' &X NMRP ABOVE R Plat(ONLY 338 JOINTS). DEPTHS KOP- 1050 FROM SSSVN-OVERSHOT REFLECT CALIPER(02/15/07). 20"CONDUCTOR ? REPAIR SQZ 12700'-12905. HOLE DRLD ID=2.28".LAST Max Angle= 58"@ 6900' rM\ TD@ 13434'W A 2.2"OD CENTRALIZER-03/27100. Dation MD= 13138' Datum ND= 8800'SS ., 2027' H3-1/2"HES XDB SSSVN,D=2.75" 13-3/8"CSG,72#,L-80 BTRS,D=12.347" H 3053' C 3171' H9-5/8"x 7"BKR ZXP PKR/HGR,D=6.31" 7"LHR-CMT'd,26#,L-80,.0383 bpf,D=6.276" —{ 5800' (- Minimum ID = 1.785" @ 10092' 7 10092'-10119'H 3-1/2"WRD WDEPAK,01€-TRP,SII' JL 3-1/2" WFD STRADDLE PATCH PATCH,OAL=27,D=1.785" (04/04/15) TUBNG PUNCH(02/13/10) H 12450'-12452' .'/`� .• 12302' H CEMENT TOP(02/28/10) 4. 1 t l• 12466' —13-1/7'1-ES X NP,D=2.75" '••• •,•, - 111 •�'�' 12492' BKR 80/40 PBR,D=2.95" lir, 11 H 111• 1111 .1.1 � 12506' H9-5/8"X 3-1/2'BKR S-3 NKR,D=3.875' 3-1/2"TBG,9.2#,L-80 NSCT, —i —12610' ' 12566' 1--- MILED .3-1/2"HES XN NP, LTO 2.74"(01/02/02) .0087 bpf,D=2.992" 3-1/7 TBG STUB(11/26/01) --1 12623' 12618' H UNIQUE CUSTOM OVERSHOT 14141 .1.1. 12743' H3-1/2"OTIS SLD SLV,D=2.750" 1�11 I �1�1� 3-1/2"TBG,9.3#,L-80,.0087 bpf,D=2.992" H 12795' 1:1 �� 12795'9-5/8"X 3-1/2'TIW HBBP-R PKR ►•�•4 C�•• 12824' 3-1/2"X 2-7/8'XO,D=2.387 J ►•�••• , •••.• 12860' —12-7/8"OTIS X143,D=2.313' ►••••• ►�••• ►••�• ►� •••• •S. *'•--I 12869' H9-5/8"X 7"BOT LNR HGR w/TIEBACK,D=_" BTM OF CMT SHEATH(02/28/10) 12905'ctm A V 12893' H2-7/8"OTIS X NP,D=2.313' ♦• ♦1 411 2-718"TBG 6.4#,L-80,.0058 bpf,D=2.441" —i 12927' P•• •1 lk&," 11• 12927 H2-7/8"WLEG,D=2.441" 9-5/8"CSG,47#,L-80 BUTT,D=8.681" —{ 13138' I12896' --1 ELN)TT LOGO ON XX/XX/XX PERFORATION SUMMARY REF LOG: SWS-BHCS ON 07/12/86 I ANGLE AT TOP PERF: 43" 13138' Note:Refer to Roduction DB for historical pert data 1 13164' —i7"MARKER JOINT SEE SPF INTERVAL Opn/Sgz SHOT SOZ 2-1/8" 6 13138-13153 0 02/19/89 13400' —{FISH-NLLED FASDRiLL(04/06/10) 2-1/8" 4 13262-13364 0 09/10/88 ? —FISH-WRP ELEMENT(06/17/07) • 13432' FISH 2-1/8"X 8"FERE G&HBULLNOSE 7"LNR,26#,L-80 U4S,.0383 bpf,D=6.276' H 13433' — 41111C- CENTRALIZER SPRING XO 7'LHR,29# AL". 13434' H FIST t 34'X 2-1/8"PERF GUN,&OCL TOP PBTD 13508' 7"LNR,29#,L-80 BTRS,.0371 bpf,D=6.184" —I 13550' ••••••••4 DATE REV BY COMMENTS DATE ,1 REV BY COMMENTS PRUDHOE BAY UNIT 07/18/86 AUDI 2 INTIAL COMPLETION 02/10/15 TJMJMD PATCH CORRECTION VVB1: Y-24 12/04/01 D-15 RWO 03/18/15 STF/PJC MI PATCH PERMT No:'1861130 02/08/14 JM PJC PULL WRPR RESTRICTION 03/31/15 RRW/PJC KILL RESTRICTION @ 12500' AR No: 50-029-21608-00 09/17/14 JMD MINOR®RTS PER TALLES 04/04/15 JON PJC SET STRADDLE PATCH SEC 34,T11 R R13E 1349'FTL,83'FWL 10/18/14 CJS/PJC SET STRADDLE PATCH 01/27/15 PJCATCH CORRECTION p BP Exploration(Alaska) i i ("OF Ty, I�jr THE STATE Alaska Oil and Gas „ ofA T /\ c J( /` Conservation Commission t = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 OF ALAS� Fax 907 276 7542 www.aogcc alaska.gov Kristine Odom - 211'3 Production Engineer SGp►�`1m 4 13 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y-24 Sundry Number: 315-090 Dear Mr. Odom: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this day of February, 2015 Encl. [RECEIVED .0. FEB 1 7 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION g�O�'+^l�L!C APPLICATION FOR SUNDRY APPROVALS �! 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well yr o,`,c Change Approved Program Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Z IS Time Extension Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casmg❑ Other. Pull/ReSet Patch 0• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number vn,VI LJ BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 186-113-0 • a fifiv‘r-t,,, 3.Address: Stratigraphic 1=1 Service 2 • 6.API Number P O.Box 196612,Anchorage,AK 99519-6612 50-029-21608-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU Y-24 . Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047471 • PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13550 • 9207 • 13508 9175 None See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 39.37-119.37 39.37-119.37 Surface 3013 13-3/8"72#L-80 39.87-3053.33 39.87-2672.24 4930 2670 Intermediate 13101 9-5/8"47#L-80 37 5-13138.68 37.5-8889.46 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 2 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: • Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 . GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Kristine Odom Email Kristine.Odom@BP.Com Printed Name Kristine Odom Title Production Engineer SignaturePhone 564-5365 �G�% Date Z/l'I'/io S Prepared by Garry Catron 564-4424 COMMISSION USE ONLY c� Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 17 - C) t G Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test V Location Clearance ❑ Other { i /}�-JC L✓ ,7-,,,i r5 ,C/ /I.'/ !7 - /A rl4 [i1e- rC./ a1 C b1-Ca 5IL a. 6, /,' r-GI Ir,Jr,Cf,,,, Spacing Exception Required? Yes ❑ No h0 Subsequent Form Required: / _ lc / APPROVED BY 1 Approved by: I COMMISSIONER THE COMMISSION Date:Z— 2.49-/5 v9: (3G,'5ORIGINAL - f,c /31&2-ew-ls Form 10-403 Revised 10/2012 Approved application is valid for 12 months from t date of approval. Submit Form and Attachments in Duplicate RBDM FEB 2 3 2015 _1_) . i9, i_C--- Perforation Attachment ADL0047471 Well Date Perf Code MD Top MD Base TVD Top TVD Base Y-24 2/19/89 APF 13138 13153 8889 8900 Y-24 9/10/88 RPF 13262 13272 8984 8992 Y-24 9/10/88 RPF 13272 13302 8992 9015 Y-24 9/10/88 RPF 13302 13332 9015 9038 Y-24 r 2/19/89 RPF 13332 13342 9038 9046 Y-24 2/19/89 RPF 13342 13364 9046 9063 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF a) o 0 0 0 o O O O O O O O 17_3OD00CO � � � � � � ao I L I 1 I I I I 1 I I J J J O CO J J J J J J J J CD a) Cl) 01 00• O O O C3 UD CD O O CO O M CD 01 O CORS T T (NI I� Ln O CO 111 CO O Ns V LO O O O T 1.00 0 0 CO p I- N T I� U 01 Oc0 cNor 000 0 0 0 0 0 o CFD_ QmLflap a0 N N 0 0 0 0 0 cr m M r CO V T a0 T T Ct a) U) • cn N I- C` T N Lo N o0 co N CA 00 CO O T O N C— Ln co co T M N CO 00 M T N OD CO QD Ns .q LC) co T a0 d' O O) co N Lb co co CO co o0 I— C1 o T O) I— M C� Ln N OD CD ~ O) op Lf) aD T O O T Ln M M CO T Ln Q M M f— Q0 T OD V Ln CO V V M d' CO > N OD CA QD OD OD CO (A OD I I- 03 r E N (1) O M O N- V N- O Ns OD V C CA M M Lf) T 10 N CV N M T ' 00 m T Ln T op O In CO LO Ln ////��� Q T co M M O 2 N N N N N N M 1/, O T T T T T T T T T 0 C• J 11 (1) p CO O M O CO 'Cr OD CO CD (6 Q H O co CpCM O)O O CO M N T M M T M In N Ln Cco`7 LO n Ln C`7 U M N M O N N N N N T T T T T T T T L O U- 0 0 0 CD 0 0 0 CD O Mi O O O C▪D Cb o0 J CO a0 00 J U J o0 a0 OD CL J J J J J J -p *k J J J 4t 4t a) in N M 4t (0 N N N 66 N O V O (fl C _ O Cfl N CA CA CA N U • NN N 00 - - _ - - - _ _ __ _ _ _ N bp N N N N N O CO N M T T T T N 6 i T- N CO) CO COCCO ' CO Nr L p) Cp O N M f- CO"-- OD M O OD V c00 = QD T ODCOT- N Nn T LN O C7N J .,— Ill W 0F- e, • H 0 Ill W U CU U p CC CC Et CtU u_ Z Z Z Z Z Z Z Z W W W W H CC m m CO m m m m p I— z_ z z_ Q D D D D D D D D 0 Z J J J d OD I— I— I— I-- F- I— I— JUNK SUMMARY ADL0312828 SW NAME MEAS DEPTH MEAS_METHOD_CODE RUN DATE TVD Y-24 12453 JUNK 11/14/2007 8385 Y-24 13400 JUNK 4/6/2010 9091 Y-24 13432 JUNK 7/31/1986 9116 Y-24 13434 JUNK 7/31/1986 9117 ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.8,DBR,LHD,EAZ 09/18/14) General Information Well Name: Y-24 Well Type: WAG Injection Well API Number: 50-029-21608-00 Well Activity Conventional 4 Classification: Activity Description: Mill Restriction/FCO Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE MSHAK 12 Month Avg IOR, 50 bopd: Job Type: Milling Estimated Cost, $300M SM: AWGRS Job Scope: MILL/UNDERREAM Other regulatory None requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Kristine Odom Contact numbers: (907)564-5365 (907)460-6776 Well Intervention P Travis Montgomery Contact numbers: (907)564-4127 (918)281-9663 Engineer: Lead Engineer: Dan Robertson Contact numbers: 1907)564-5546 (907)529-5818 Date Created: February 9,2015 Revisions(date,who,what changed): Current Well Status Information Gas Rate or Water Rate or FTP or Injection Oil Rate Gas Injection GOR Gas Lift Rate Date (bopd) Injection Rate Rate (scf/stbo) Choke Setting (Mscf/Day) Pressure (bwpd) (Mscf/Day) (psi) 10/27/2014 0 0 0 Current Status: Not Operable If not operable or under No Infectivity evaluation, why? _ Recent H2S (date,ppm) • NA • 0 ppm Maximum Deviation(angle and 58° 6,900'MD depth) _ Datum depth,ft TVDss 8,800'TVDss Minimum ID and Depth 1.70'Cement Sheath Restriction @12,500'MD Reservoir pressure(date, 8/19/1999 3,512 psi Reservoir temperature,F 209°F psig) Known mechanical integrity Shut in wellhead pressure None problems(specifics) Last downhole operation(date, 12/7/2014 SL Drift&Tag to 12,489'SLM operation) Most recent TD tag(date,depth, 12/7/2014 12,489'SLM 5'x1-1/2'STEM,1-1/2'Sample Bailer toolstring OD) Comments,well history, Y-24 is a troubled well that has had multiple down hole interventions to restore its integrity.Most recently background information, on October 18,2014 a 3-125x20'patch was set from 10,090'to 10,117'(OAL=27.29',MIN ID=1.785', etc: MAX OD=2.72')with element to element at 10,094'MD-10,114'MD,after the patch was set the well passed a MIT-IA to 2500 psi.The well was classified from not operable to under eval to facilitate AOGCC witnessed testing.While bringing the well on injection on October 25 it was reported that the well was not able to take fluid while pumping at 2500 psi.A slickline drift on December 7 was performed to determine the restriction preventing injectivity.The attached WSR states the sample bailer was full of ice and silty paraffin and were unable to work pass 12,489'SLM.Lab analysis of the sample determined the restriction to be schmoo and cement.The objective of this program is to mill the restriction and ✓ establish injectivity. *2/92014 Well Service Report states while in hole with 3'1-12'STEM,1.70'G-RING S/D at 12,500' SLM tried to work through restriction for 10 minutes and took 1200 lbf to come free.* 1 Well Intervention Details Suspected Well Problem: Schmoo&cement restriction preventing injectivity. Specific Intervention or Well Objectives: 1 Mill the restriction that is preventing the well from injecting fluid. 2 Establish injectivity into the reservoir. 3 Reset patch and pass a MIT-IA to 2500 psi. Key risks,critical issues: Mitigation plan: 1 Well has TxIA at 10,104'MD with a LLR of 2 bbl/min. Liquid pack IA during CT intervention based on IA FL. 2 Coil stuck during fluff and stuff. Establish good injectivity before fluffing and stuffing. 3 Avoid setting the slips in the same location. Reset patch elements at 10,096'MD-10,116'MD. 4 Possible high H2S on injectors. Monitor for H2S and discuss risks in the PJSM. Summary Step# Service Line Activity 1 S Pull patch at 10,090'MD,save and redress patch for post CTU intervention. 2 D DHD to get a FL shot down the A-3 days after patch is pulled to determine TxIA significance. 3 C Mill with 2.72'bit from 12,500'MD to the 3-1/2'x 2-7/8'X0 @ 12,824'MD.Perform injectivity test. 4 S Set 1.75'nipple reducer at HES XN Nipple @12,466'MD 5 E Reset patch at 10,096'-10,116'MD to avoid collars and resetting slips in same location,with the middle of the 20'element to element patch at-10,106'MD. Tie into PDS LDL-April 26,2014. 6 F Post patch set MIT-IA to 2500 psi.If fail,establish LLR. Detailed work scope(Follow RP and attached procedure): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production BOPD: MMSCFD: BWPD: Rates: FTP(psi): Choke setting: Post job POP instructions: If job is successful,contact WIC to approve POI and request AOGCC witnessed MIT-A testing. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies, Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: 2 1, To: GPB Well Ops Team Leaders bp From: Travis Montgomery Matt Brown Well Interventions Engr. Kristine Odom P &Y Pad Production Engineer Date: February 9, 2015 IOR: 50 BOPD Estimated Cost: $300K AFE: APBINJEC Subject: Y-24 Mill Restriction / FCO / Pull & Reset Patch Step Unit Operation 1 S Pull patch. 2 D DHD to get a FL shot down the IA. 3 C Mill restriction; injectivity test; FCO. 4 S Set nipple reducer. 5 E Set patch. 6 F Post patch MIT-IA. Not Operable: needs AOGCC-witnessed MIT-IA with well on 58° F C� Current Status 6,900' MD injection. Well has no injectivity. Max Deviation 58° F @ 6,900' MD Min ID <1 .5" restriction @ 12489' SLM Last Ops 12/7/2014 SL Drift &Tag to 12,489' SLM with 1.5" toolstring SBHP/T @ 8800'SS 8/19/1999 3512 psi /209° F Tie-in Log PDS XTU, CCL, TEMP, LP dated 4/26/14 Objectives: 1. Establish injectivity into the reservoir by milling restriction and removing fill. 2. Reset patch and pass a MIT-IA to 2500 psi. 3 Background: Y-24 is a troubled well that has had multiple down hole interventions to restore its integrity. Most recently on October 18, 2014 a 3-1/2"x20' One Trip Straddle Patch was set from 10,090' to 10,117' (OAL=27.29', MIN ID=1.785", MAX OD=2.72") with elements at 10,094' MD — 10,114' MD, after the patch was set the well passed a MIT-IA to 2500 psi. The well was reclassified from not operable to under eval to facilitate AOGCC witnessed testing. While bringing the well on injection on October 25, it was reported that the well was not able to take fluid while pumping at 2500 psi. The well was reclassified from under eval to not operable. A slickline drift on December 7, recovered schmoo & possibly some scale and was unable to work past 12,489' SLM. *2/9/2014 WSR states while in hole with 3' 1-1/2" STEM, 1.70" G-RING S/D at 12,500' SLM tried to work through restriction for 10 minutes and took 1200 lbf to come free.* *Cement stringers were milled 12,393'-12,780' with 2.68" bit on 4/5/10 after 2/27/10 packer squeeze.* *Top of cement sheath, milled out to 2.28" ID, is at 12,844' MD in 2-7/8" tail pipe from 5/19/06 cement packer squeeze.* 4 • Slickline: 1. MIRU SL. 2. RIH and pull 3-1/2" patch at 10,090' MD. 3. Drift and tag with sample bailer. 4. RDMO. DHD: get a FL shot down the IA —3 days after patch is pulled to determine TxIA significance. • If IA FL > 500', liquid pack IA just prior to RIH with CT by pumping down tubing and taking returns from IA until liquid packed. Coiled tubing milling and injectivity test: 1. MIRU coiled tubing. 2. Make up milling BHA with 2.72" bit. 3. Dry tag restriction. Previous tags at 12,490' SLM. 4. Open the backside to allow returns to ASRC/tanks. Come online with 2% KCI down coil. 5. Closely monitor returns to watch 1:1 returns. 6. Begin milling from tag with 2% KCI and periodically pumping 10 bbl Powervis sweeps. Losses will likely occur upon break through and lead us to perform fluff & stuff. 7. Mill down to just above XO at 12,824' MD. 8. If motor work is seen near XO, POOH. MU milling assembly to mill in the 2- 7/8" tailpipe. RIH & mill to tubing tail. Note that min ID of 2-7/8" tubing tail is 2.28" @ 12,844' cement sheath from packer squeeze of 5/19/96. 9. Continue milling until no motor work is seen or if losses are 50% or more. Drift/cleanout to 13,380' MD, just below bottom pert— NOTE: fish @ 13,400' MD. 10. Pump a large (+20 bbls Powervis sweep) and chase returns OOH. 11. At surface, perform injectivity test as follows: a. Line up to bullhead fluids down tubing. b. Pump small 60/40 spear followed by —50 bbls 1°/0 KCI. Pump at max rate with max WHP 2200 psi. 5 c. Based on the injectivity, continue as below: i. Injectivity >1.5 bpm at 2000 psi 1. Drift/cleanout to bottom perf. FP well. RDMO Coil. ii. Injectivity < 1.5 bpm at 2000 psi, 1. Perform FCO/fluff n stuff. Drift to bottom perf. FCO / fluff n stuff: 12. Pick up 2" JSN. 13. RIH jetting Schmoo-B-Gone from surface, taking returns to tanks. 14. Once near deepest depth reached milling, swap to slick KCI down CT. 15. Park coil and circ bottoms up. 16. SD pumps. RIH & dry tag. 17. PUH -50'. Swap to Powervis down CT. 18. With Powervis at nozzle, jet into fill/schmoo & fluff up. Attempt to frac fluffed up fill into perfs. 19. If successful in stuffing fill, continue with fluff n stuff, otherwise perform FCO the long way. 20. Once perfs are clear, POOH chasing last Powervis sweep. 21. At surface, bullhead 60/40 to FP well to 2500 ft at a max WHP of 2200 psi. Note injectivity and TD on WSR. Slickline: Set 1.75" nipple reducer at HES XN Nipple @ 12,466' MD. E-Line: Reset 3-1/2" patch at 10,096' - 10,116' MD to avoid collars and setting the slips in the same location, with the middle of the 20' element to element patch at -10,106' MD. Tie into PDS LDL- April 26, 2014. Fullbore: Post patch set MIT-IA to 2500 psi. If fail, establish LLR. 6 WSR showing 1200 lbf was used to pull out of restriction: WELL SERVICE REPORT WELL DATE JOB SCOPE DAY SUPV Y-24 2/9/2014 LEAK DETECTION LOG CARLSON AFE CODE DAILY WSR COSTS DAILY WORK NIGHT SUPV AP5WE __ ,_ 2? _ ',MORPH''-JOSH MIN ID DEPTH TTL SIZE KE Y PE R SOIL UNIT 2.28 12844 FT _ SwCP#11 DAILY SUMMARY "'CONT FROM 218/14 WSR•"(leak detection log) RAN 5'1-7/8-STEM, 1314"S-BAILER TO 12,500'SLM (unable to pass.recovered 1 cup ofsthmoo). RAN 1.70'GAUGE RING TO 12,500'SLM (unable to pass). "'JOB COMPLETE WELL LEFTS/ION DEPARTURE*" LOG ENTRIES !nit Tb IA,OA->Il 60011 400 01 TIPS COMMENTS 00 00 BEGIN TICKET.CURRENTLY BLEEDING OFF W/2.35'0-RING. 00 15 PT QTS,RIH W/KIT,5' 1-7/8W STEM, 1-3/4`"S-BAILER. S1D 12,500'SLM WORK FOR 10 MIN MAKES NO HOLE,HIT 1200#LICKS TO COME FREE...POOH. 01 50 OOH TOOLS,RECOVERED 1 CUP OF SCHI,IOO. 02 05 PT OTS,RIH WI KIT,3'1-1/2"STEM, 1.70"G-RING.SID 12,500'SLM.WORK FOR 10 MIN, MAKE NO HOLE, HIT 12008'LICKS TO COME FRE E.,,POOH. 03 40 OOH Wt TOOLS. 03 50 BEGIN RID,INSTALL& PT TREE CAP.RETURN TREE VALVES TO NORMAL ?; S-IONS 04 59 RID COMPLETE. MOVE OVER TO Y-32 END TICKET Final Tbg IA,OA--ll 6000 4001 0 1 ' JOB COSTS SERVICE COMPAINY- SERVICE DAILY 4'.ISR COST CUMULTOTAL SCHLUMBERGER 51,873 S23,226 SCHLUMBERGER PLUS 17 PERCENT 5318 53.948 CH2MHILL SO 54,170 HALLIBURTON SO S9,733 LITTLE RED SO 56,555 LITTLE RED PLUS 10 PE RCE FIT SO 565E NORTHE RN SOLUTIONS SO 51,500 vv AR E H O U SE - 56.964 WEATHERFORD c; 515,474 WSDISPATCHEC S3 $1,040 TOTAL FIELD E STIMATE: 1=' 57326` 7 p Schmoo (iron sulfide) and maybe some scale recovered 12/7/2014: PBU Laboratory Sample Report 907-659-5654 SAMPLE PD06029 Facility Date/Time 12/712014 Sample Point 12,49'SLM Sample Desc BLACK AMORPHOUS SOLID Well '(-24 Sample Type SOLIDS Test&Units Results Aluminum Wt% 0.47 Barium'Nt% 0.68 Calcium Wt% 9.96 Carbonate PoslNeg Pas Cadmium Wt% C.C8 Chlorine Wt% G. c Chromium Wt% C.C5 Capper Y'v't% C.C3 Iron ','v't% 15.6 Mercury Wt% 0.08, Potassium Wt% 0.14 Magnesium Wt% 0.3E Manganese Wt% 0.11 Molybdenum Wt% 0.02 Sodium Wt% 0.12 Nickel Wt% 0.02 NORM <570 micrcrem"hr Pass.Tail Pass Phosphorus',A% 0.14 Lead Wt% 0.01 Sulfur Vv't% 7.19 Silicon 'Ait% 2.52 Sc lub ilit,/ Slurries Strontium Wt% 0.05 Sulfide PosfNeg Pos Titanium Wt% 0.05 Zinc Wt% 0.14 Sample slurries in solvents (toluene (best) diesel or water) Some of the sample decomposes in 18% HCI water with production of sulfide gas 8 , . $ $ la V -4 - *W 4 . 4P%, itio. ,* , • % 1 t .9, . .1 . ..,. . , 44IE lir • i ,. • 4„. ,4-..., • I 411 ... 10 V 4 1.... . . , I k. f aka - * 0 - _ 4 * V 4 14. * ,a • * , , . • , 3 . hair4 - . . ..,„ It * ! * • t ,t, 4 _ t 9 Stringers were milled 12,393'-12,780' with 2.68" bit after 2/27/10 pkr sqz: WELL SERVICE REPORT WELL DATE JOB SCOPE DAY SUPV Y-24 4/5/2010 CEMENT SQUEEZE DISBROW AFE CODE DAILY WSR COSTS DAILY WORK NIGHT SUPV APBYPDWL24 529,803 MILL IGTANLOC MIN ID DEPTH TTL SIZE KEY PERSON UNIT 2.28" 12844 FT 3" DS-APPLEHANS CTU#9 DAILY SUMMARY CTU#9 1.75"CT Job Scope:Mill Fasdrill Plug.Continue from WSR 4/4/10.MIRU CTU.MU BTT Milling BHA w/2.30"3-Blade Junk Mill and RIH. Sit down at 12393'.Mill cement from 12393'to 12461'ctmd with 6 hard stalls.POOH to change BHA.RIH with 2.13"motor and 2.68"Pirahnah Mill.Milled to 12798'ctmd and had several hard stalls.POOH for smaller mill for composite plug...Job continued on WSR 4/6/10... LOG ENTRIES Inst Tbg,IA.OA 0 0 0 TIME DEPTH TBG CTP BPM BBLs COMMENTS 00:00 0 Continue WO DSO to sign permit 00:10 0 WWTF signed RU 02:20 0 BTT on location 02:25 0 PJSM to MU MHA&BHA 02:40 0_ MU Dimple connector 03:10 0 Pull test CTC to 15k and MU Milling BHA 03:15 0 Line up to PT MI-IA 03:17 0 435 LPT 03:21 0 3981 HPT 03:25 0 MU Milling BHA 03:29 0 take injector to the well 03:39 0 Stabbed on well,line up to fluid pack 03:50 0 248 700 LPT 03:57 0 3691 4099 HPT 04:05 0 Bleed off the coil pressure to test check valves 04:07 0 Good test.-"AWGRS Crashed.Time Line recovered from SLB time log from midnight until now"" 04:08 0 Open swab and RIH w/milling BHA:1.85"x 0.29'dimple connector.1.69"x 1.51'Dual checks,1.69"x 6.18'Bowen Jars,1.69"x 1.36'Disconn(1/2"ball to disco).1.69"x 0.93 dual circ sub(3/8"ball to open),1.69"x 7.63'extreme mud motor,0.93"x 0.49'XO,2.30"x 1.10'3 bladed junk mill.OAL=19.49'. 05:12 6000 0 57 0 WT CK 11.5k online with KCL 06:22 12395 3 383 0.3 44 Tag.PU and try RIH again.Tag again 06:27 12392 3 220 0 44 Tag again 06:30 12370 3 1266 1.0 Free spin 06:32 12393 3 1708 1.0 46 Begin milling what could be cement stringers. 06:42 12420 3 2000 1.0 58 Stall#1 and 2 06:53 12420 3 1272 1.0 65 Stall#3 06:58 12408 3 1311 1.0 70g Swap to Geovis. 07:06 12416 3 1984 1.0 80k Swap to water. 07:19 12420 3 529 1.0 91 Wt Check:27.5k 07:36 12428 3 1865 1.0 106 Seeing some motor work. 07:40 12431 3 1763 1.0 109 Geo at nozzle 07:48 12440 3 1456 1.0 1188 Swap to Geo. 07:49 12441 3 1507 1.0 119 Water at nozzle 07:52 12450 3 1888 1.0 123k Swap to water.RIH Wt=8.5k at 2.70 fpm. 07:56 12461 3 2300 1.0 128 Stall#4.PU Wt=28.5k. 08:07 12461 3 2200 1.0 137 Stall#5.PU Wt=30.5k,then broke over to 28k. 08:16 12461 3 2200 1.0 144 Stall#6.PU Wt=30.5k-getting sticky.Stalled at 0.3 fpm.Stalls are very hard and immediate.Concern that we are putting too much stress on the bha,decide to POOH and pick up a 2.125"bha and larger mill. 08:22 12440 3 1590 1.0 146 POOH to change BHA. 08:32 11237 3 1419 1.0 157 Geo at nozzle. 08:37 10654 3 1393 1.0 183 Water at nozzle 08:51 9421 3 1421 1.0 178 Sweep#1 at tanks. 10 WSR-Y-24-4'5/2010 Page 2 of 3 TIME DEPTH TBG CTP BPM BBLs COMMENTS 09:29 5274 3 936 1.0 219m Swap to meth.IAP=650 psi.OAP=0. 10:19 1613 3 868 0.5 258 Meth at nozzle.Reduce rate. 10:27 0 3 231 0 268 Tag up.Offline with pumps.Close swab 23.5 turns. 10:40 0 POP off well.Breakdown BHA. 11:02 0 Baker on location.MU new bha. 11:30 0 Pull test external connector to 20k.Continue making up BHA. 11:47 0 Om Fluid pack for MHA PT. 11:50 0 1 PT MHA low and high to 3500 psi.Continue to MU remaining BHA. 12:17 0 1 Flood iron for PT 12:19 0 3 PT low/high 400/4000 12:33 0 Bleed off coil pressure and test check valves-good. 12:42 0 211 131 Open well and RIHw/BHA#2:2.25"x 1.36'CTC.2.13"x 1.38'Dual Checks.2.13"x 6.03' Bowen Oil Jar,2.13"x 1.56'Hyd Disconn(5/8"ball to disco).2.13"x 1.01'Dual Circ(1/2" ball to open),2.13"x 8.17'Extreme Mud Motor,2.68"x 1.07'Pirahnah Mill w/cutite 2.68" No-Go,2.69"Go.OAL= _ 13:10 2400 5 876 0.5 Ok Online with 1%XS KCL down coil to displace McOH. 13:38 5000 45 858 0.5 15 Wt Check:10k,RIW=4k. 14:25 9500 34 580 0.5 39 Wt Check:18k,RIW=8k. 14:31 9800 11 100 0 42 McOH displaced.Pumps offline. 14:51 12000 0 14 0 42 Wt Check:24k,RIW=8k. 14:59 12419 0 13 0 42 Did not tag,but started to sit down at 12401',decided to pull up so we didn't get wedged. PU to 30k.break over to 28k.PUH to establish free spin. 15:02 12394 5 1620 1.5 42 Free spin=1620.RIH to mill. 15:10 12422 0 1602 1.5 56 Stall#1.PU off stall=31.5k, 15:24 12413 5 1789 1.5 68g Swap to Geovis. 15:27 12419 5 1960 1.5 73k Swap to water. 15:44 12426 0 194 0 95 Pumps offline for dry tag.PU wt=28k.RIW=9.8k. 15:46 12429 17 1580 1.5 95 Dry tag.Pumps back online.Mill online. 15:52 12437 17 1606 1.5 107 Geovis at nozzle 15:56 12439 17 1590 1.5 112 Water at nozzle.Mill ahead 0.6 fpm. 16:28 12448 17 1785 1.5 155g Swap to Geovis 16:30 12448 13 1921 1.5 160k Swap to water.Not seeing any motor work. 16:43 12454 0 154 0 180 Doan on pumps.PU Wt=27k.Dry drift down.Tag with 2k down at 12454'. 16:50_ 12445 12 1824 1.5 180 PUH.Pumps online.RBIH to mill. 16:58 12461 7 1912 1.5 194 Geovis at nozzle.Milling at 1.5 fpm. 17:05 12472 8 1685 1.5 199 Water at nozzle.Milling at 1.5 fpm. 17:09 12476 8 1838 1.5 207g Swap to Geovis. 17:11 12480 7 2190 1.5 212k Swap to water 17:35 12525, 15 2209 1.5 246 Geovis at nozzle. 17:39 12530 12 2263 1.5 251 Water at nozzle.Milling at 1.5 fpm.RIW=7k. 17:45 12543 13 2301 1.5 265 Geovis returns at tank verified. 17:51 12554 12 2330 1.5 273g Swap to Geovis. 17:54 12559 12 2592 1.5 278k Swap to Water. 17:58 12524 6 2439 0 283 PUH-RIH for dry tag.Pumps offline.PU Wt=28k.RIH wt=7.8k. 18:02 12618 0 284 RIH dry to 12618.then sit down. 18:03 12598 6 2404 1.5 284 Pumps online. 18:27 12612 7 1948 1.48 317g Pump 5 bbl sweep 18:31 12618 6 2349 1.46 322k Swap back to KCL 18:55 12670, 10 2125 1.46 356 Geo at nozzle 19:00 12680, 10 2082 1.45 361 Geovis out short trip 19:04 12608 12, 2175 1.45 368g Swap to Geovis 19:06 12680 12 2313 1.47 371 Continue milling 19:07 12683, 11 2424 1.46 373k Swap back to KCL 19:23 12770_ 11 2215 1.49 395 Stop and WO Geo pill 19:32 12770 13 2122 1.48 407 Geo at nozzle 19:35 12770 11 2088 1.48 412 PUH chasing pill 19:40 12670 11 2152 1.5 419 Center plunger on pump is leaking 19:58 12565 5 2374 1.53 443 Fluid from plunger is oil from the oiler gland and packing is ok,circ last pill OOH and wait for Geo truck 20:25 12655 11 2323 1.5 480 Geo at surface.confirmed.Geo truck on location 20:39 12610 11 2542 1.5 497g Swap to Geovis 11 • WSR-Y-24-4/5/2010 Page 3 of 3 TIME DEPTH TBG CTP BPM BBLs COMMENTS 20:43 12770 10 2777 1.55 503 Continue milling slow 20:46 12773 8 2851 1.55 507k Swap back to KCL 20:51 12780 11 2676 1.57 515 Increase ROP 20:55 12799 11 2424 1.48 520 Stall PU and start again Mech at 12802' 21:00 12798 11 2398 1.55 527 Stall again,might be at the X-0 or tagging in packer.PU and try milling agian 21:03 12798.40 11 2450 1.5 531 Creeping IH and got a hard stall at.2-.3 fpm, 21:08 12798.40 11 2398 1.5 536 Stall again.Geovis at nozzle 21:15 12798 11 2400 1.5 547 Try running in at faster speed to see if we are tagging the packer and 3 attempts to get deeper failed with hard stalls 21:18 12790 10 2222 1.5 551 6 stalls at same depth,looks like we are at the X-0,POOH chasing bottoms up pill at 80% 22:02 7260 0 1832 1.5 615 Geo at surface 22:12 5500 4 1432 1.5 632 Swap to 60/40 22:42 2100 0 1690 1.0 671 60/40 at motor,reduce rate and continue POOH 22:57 555 0 0 687 Good 60/40 at return tank,shut down pump and POOH dry 23:07 0 OOH,bleed off and PU injector 23:16 0 Work on SLB pump 23:53 0 LD 2-1/8"motor&mill 23:59 0 Continue LD BHA 12 , . , . Tie-in log: I voiAckAgosi,;(e. LEAKPOI NT Tm SURVEY ° 411 —.— XTU-CCL-TEMP- LPTM epto^cir,tia. colikce4c44.ric sLavicas 26-Apr-2014 c Company BP EXPLORATION (ALASKA), INC. Well Y - 24 ori < Field PRUDHOE BAY c 0 ›,. Borough NORTH SLOPE State ALASKA ..-,.., .3 . gfin. °ILL Surface—Location Other Services Cl 0 40 to None x 'cr ., ...0 .g 1,349,29' FNL & 83.14' FM. ILI c..4 los to in_ i "E .9 * C l > cr.. Z < SEC. 34 TWP- 11N RGE. 13E _ic Ehmtion a. co Permsnert Datum = MSL Elevaton Cf.0 lc B. 88.851 Log Measured From RKB 88.85 FT. Above Perm. Datum OF. Km 0 3 iiii,Z AP1 Serial Number 50-029-21608-00 G.L Nth Dale 243-Apr-2014 - Run Number P 8-C Driller 13.508' PE!-CiLower Not Taoged Elobcol Logged Intervd 124g2 Top Lap interval Surface . Open Hole Size NIA Toe Fluid LIAt:di 1 kitast Recalled Temp (deo.F 1 T1111,"arkk...111Retadi 7 r)0 FINAL PRINT lane Lower pr(Bottom 121 Equips-nil:II Number SLB EL*2128 ----' — -." L3calton ' Ncrth Voce II seriiim Invoice No I-DIM? _ 1 Aecordei By L Ciusfin thitneseed Ili G Walker M. Borehole Record Tubing Record ;uri Number ' Bit From ' -:; size 1 LB,Fl I t- on ).. —70 I 1 1 17 2.1_1 Su r R.7.- lm 121124' 2 7ig' 5 4IJ ' #2 024. 1- 12".927 , 1 . , Lasilg Teccrd SizeLE m i Ft , rop Botto Surface String 13 16" : 72.00 Suftice 3,.':,..6r . , _ Prot String g VT 47 al, ti(lidArAl , i t weir 7- 26 DO 12 869 — 4. Ltner - 1 13 ' r a; ; .r i I }I CCL (l A) . 1 1 • t[ 4 11 4—Line Speed{LAI �i I 1 I ii 4—Line Speed;8L) t ; t , i d"��{ f --Temperature(LA) 1 Temperature(Leak Active) i • . 4-- If— I 1 i ro 1 . ;o.=-T. . i •_ , _ Terrerairre(Baseline 1 I 10,096'MD , • _. . I Leak Signature r , • I " - _ _p; _ 10,116'MD Z. I ;•i % 1 li !3' ! , : LeaePoin1''-A(Leak Active i } LeakPoinl'w-B(Leak Active) I a_ i i LeakPantTM-C(Leak Active) r ; ' LeakPaintTM-A(Baseline)—* i : I LeakPointTM-B(Baseline) , T _--- r _____ __ �.� LeakPairrtTM'-C(Baseline) { •10200 • '• ( +b f I 'i1 i ! � ( 1. i — __ 14 Patch schematic: 'g" Client' 81, __. Rig/Platbml Wl2�,,,a4tana,7�erS '!Address Field Prudhoe Bay eal erlord Leae/0024 Endicott Well Number 0-24 Company Man Bethany Free! Stale Alaska Phone Country USA _ Type of Operation Wide Pack One Trip Patch OH BHA to Surface Item Tool Description Tool O/D lin) Tool I/O(in) Length Amt No. Connection Top Of Patch 10090 2 Upper Wide Peck Pecker 2.720 1.]85 5.49 WLAK X 23/8 Acme Box 1 3 72000 Sheer To Release ©emenl Set De9th®10094' New Set Depth 10,096'MD - COE to Bottom Of Pecker 1.35' 3 23/8 Spec..Pipe 2.375 1.975 706 BP 23/8 Acme Pio X I'm ICoupling 0710 4 2 3/8 Spaaa Pipe 2.375 1.975 1000 BP 2 3/8 Acme Box X Pin V 30.3 Element Gaga to Cooter A I ■ Tap Of Pecker To COE 1.75' t� 5 Lower Wide Peck Centreliser and Peck Off 2.721 1.785 4.80 0P350037 2 3/8 Acme Box X Mule Shoe - Benet Set Depth El 10114' 3.0S COE to Boum A New Set Depth 10,116'MD •• II , I - WeotherlOrd Intervention Services TWtU TUBING PACE INTERVENTION BHA 1 'Rea 1 I Total Length of BHA 27.19 8 BHA Prepared by: Date, Rae moven el OOa are Vine spomnile aro Wen as a gaakeaa/ Maalmen 0012 2.72 Minimum OD 1.7115 Aaron McDonough 24.Sep-2014 15 .1 Minilog: f" Injector Minilog - Tec log Project:PBU_WWF Well: Y-24 Author. Laura J.Larson Scale 1:1000 Date 9/3/2014 Elevation 88.85 X 64489823 SPUD Date Country USA Elevation datum KB Y 5948907 76 Cornpletton Date 1986-07-1700:00:00 Fret Prudhoe Bay Total Depth 13550 Longitude-148.828262 Status State Alaska Coordinate Sstern NAD27AFT Latitude 70 26783 Operator BPX Company BPXA 1- y�y fDtEND Hpg Z -1.65 WIRE lC3 B-8 7.4 D RES MED NEU PE Comments p G TVDss MD E24gfS7({SHA` y�4.CALC W1 Emoty variabl � w (FEET) (ft) 0.3 OHMA�I 100 6D PU D CALI Shallow Resistivity DT • v Y-24 BurfAII 1:10001:1000 Y-Z4.q /DLCO 1 1 D W ru ,n -oar��'oa Tss -SS SW PHIT a 0. GR RES_DEP TVDSS SW POR O 0 Y-7 ST GR _ u em BESE COMP.110 COMP Y-IA Ida, NSSSS via.(a«WUBO.SW V-M.0*LC wuto Pert 1— 8 . O( 7On d 0 7 l)HMM Tl1D i 1tiW S4® D V[V S U 1f/V IL' 8800- Al TSNA TSHA >♦3 -13200Ai,. TSHB TSHB /¢ TSHC TSHC \ TEIL TEM I -- _...r. 8900- RPF I -_ 1. I i PERF Mks-33300 __.__u .. . 1 C PERF nit ,. ,.RPF �. RPF `. .ar s -9000 -13400- • r tz ,. IL 'S► -13500`---- < r 9100 . =9100 • - TZ1B TDD 16 r Tubing tally: i IUUING SUMMARY Ii •1 '4‘` RIG DOYON 16 04te 11 30'2041 WELL 4 DS Y-24. TUNING 3.V1-60 MSC' WT T 9-2• 432 JTS ON RACK 4p: JTS RAN ' ,,,Ok0 TO 01 13379.96 FT ON RACK 12168 3 FT RAN ITEM O.scnF000 Includ,9 S12E.TYPE,CONNECT1014 IJTS 5.J ID 00 . tENGTN ' TOP 8077063 ,iN:O'JFCU&TO1.1;'�:RS17^.1 _ 3.56251 __9,25+ 732 12612.43 126198' _ -. Pt JP JOII.7 ---._ L.- L.- - 2.937 3116'__�9 66 72602.67 t__.. !261741^ t.70IN-. L-0:i 3 2.7".SCT T'JOING 2.937• 3.96 302012572.43 12537.63 PUP 3044T(3 1+7L-1013SCT1 2.1371 346~ 9.18 _ 12552.55 72577.43 X.1.414,01.:.• , 2.751 336 2.13 12561.42 '7442.15 i PUP JO NT(3 1:2"L-63 NSC.1 2937 3.96 9.77 12551.65 17541 42 1 3CINT.-61 1.7 NS,11 *Alm, 2 937 3 06 30 40 12511 25 12551.65 1 __ Pig'JO:NT I? 1;-1 l0`JSGT' - 2.937 3.16 9.64 1 12511 39 1732!25 :Cc.1 1:2"NSCT EWLX it 3 1:7 145:0=1 ON! 2.917 2.96 1 90 12539 49 17611 39 __ 9 5.5-5.3 PACKER 2.95'4.0 8.25 4.64 12504.55 12549 4E X:C'3 1::NSCT 00X Y 4 1.2"NSCT P'1.1 2.937, 3,96 1.10 12553.05 12504.85 1 X.O t'. 1 lir 5,-f SOX.: Y NSCT PR:; 2.937 3.961 1 10 17531 3S • 12503.05__ 86'4C POR r 31 5 13.61 12417.74 12601.35 { T. 12497 74 12487.14 12',J'S R. ABOVE 3.tOW2 IN 5-3 A5,GF6MB,Y TALLY j i 12447.74 12417,74 { 1 12417.74 12457.74 SFAL ASSEMBLY ISEA..UN,' 11 r 81111::11 2.951 4.9 .37 12487.37 i 1241874 X.O 2.937 3.16 1.16 12485.41 12487.37 `-- 1 .10!P C.P,IP 2.937: 3 96 1.17 I 12479.54 12415.41 KO PUP 41-TIC COX BOX s NSCT Pito 2.9112! 3.96 9.33 ( 12470.21 12479.54 310 PUP IL-50 14507 BOX x FOX 1>114) , 2.9021 193 9.57 ( 12444.64 1 12470.21 3.5"x 2.75-NES'X'N;PP:F IN:HP RHC.,,, I 2.751 les 1.00 1 121439.64 I 12460.94 TUBING:PUP 0.40 NSCT; t 2-9021 3.99 9.73 1 12449.36 1 12459.14 1....115.-6C 3 1:C NSCt TUBING 1115 1 THIt4J.1:19: I 2.8871 3.11 10433.30 i 1016.56 j 12049.8& .!1 3 PUP IL.40 rOx BOX x NSCT v1R j 2,902' 3.98 1.23 2007.31 1 2616.56 35• 7 7Y'4ES'XC*B"wPACKCFF. 17t,-101FQX80P1 2.75! 4715 322 2004.00 i 2007.31 1 KO PUP!L-EC NSCT BOX s FCX PIN) 2.9921 3.15 9.56 I 1534.532004.09 . L.801 VT NSCT TUBING I.TS 310 TNRU 40013.96 1921.00 73.53 I 1994.53 SPACER PUPS 1. _-t_ 346 14.79 $8.74 I T3.SJ .11111111111, 2.867 3 91 32.03 26 7 , 511.74 4 ® 5 1.90 24 81 26-71 4 If7-NS0T PUP 3.95 4.5 1.30 23 51 74.81 TUBING 14A1GFR 3.95 4.5 .81 2270 23.51 I OOYON 16 RK9 ( 22.70 ' 22.70 Correction --- From the PDS .i _ -.-_-_ i } - Caliper survey there are only 338 ; - 1 • . full joints between the SSSVN * 1 - and the X Nipple above the PBR ' 17 2-7/8" tail pipe: 3fri- , pAe-, r oic 2- L.7...-.L: 7-1 L., , , DATE: 7-#"7-S.(' Rd th A ociii 2.. KB: 3 s-.0 5 •././00 JTS ON RACK. 3"I4 JIS RAN. G. -ITS OUT. 124.5-0,7,c,f/FT ON RACK. p ,9%,1-FT RAN. )sos-,9 3.FT OUT. LAST CASING STRING AT • ' ITEM - --I LENGTH f TOP , BOTTOM •, DESCRIPTIO. ! She4117 ..ql,rr ..lc.; g •9 o 11..1,5tY 1 I .TT" 1.7/s riga P 112c 3/. 5-2. 1 1 13''14,14 1 1 1 X ii.,IP P 4 r - L 2.o ill.ic/1.,% 1%.seist.ic : • 1 Ti- ,• 7/21 ri4/4 P 1 Py, 31•6-1 1,1;-g61,37 Mr1)--crt, TBG Stub @ 12623' •1,17P I.r 1. 1-0 1744,1)7 )2-2r4/- 37 for RWO done - 7,• SiSI ttl 2.1fg -rh.ii,.. RiOr 34,4,3 I 2.1T,-.3,s-q /1S6c7-'7 12/04/14 IT 1 c.../ pm cm ra __,Iii.S5 11.7111.95' 11-e4-3.5%.1 1311 Pc.f.P . t.:4a 12.794.49 /2-714.9 . . i / ,r-r- lk.r. 1-86 1_1,57 1,1..7S.7:i 2 1 311. P&IP 0.4_2 IX 7144.qv 1,-7.5-7•IL ! I 5.0,1106 S'ee 'r 3,4,1,; .-i,ifil;fil. IAD-IC.214 _ pc.rip -. *---/47-.-4,g 1 .stst a-144.13'2. , - 1 . '-. I ci- .7"7". 311 r ric.. 1 %fa 314 0.448k.4.42 i2-7.32-.4 1 10.64 11.q31A.A.0 1 -414113. - ' 1 C-4 • -rz l 10.7g 141. Mu -.lo 3)'2_ ' p , . ia,L3 4,44,7, - 117.1-11- . a--r s 3 • r_116, &ley! 2-3S-3. 3;Si- I)ca 4 Io.t.a 1:1..3 ./4i /X35-3,79 -0. • /e,71 I '.1A,43-• /1 343./4 . _L__1I _3k,t P c4 P __IC.. 13I. '1 r . G. 1 Alf • If II 08.1.9a411.31.i.r 1 -4ki_ Pup . /o.Lc ill fr767,2.4111880.clo •Is le,1•4441L1155-9.3_0pi,70.,-14 &I.i-.1 3 , = . 3kA pup Ic. rf. IllftettS7111551.80 Ixl ,r-rs .3$.1- r e6 4 73.4..5. 111144241r SW:We ._i 3i1. POP --- -- o.t. III . - 7_,„.0 0-41•GA. f r i.,,-; ° li -- Ir. ; 11105, s-) I ILF9-1 ,0,61-11,4'114.5oi i 1 loSil_ 3)1i P 0 P .. 7 la i ao loci 1,911,So wirinimmik I 18 • et Z ° 5 a 5 O n N 0 O '< n o n n O m O 0 D D D D D coN 7 D O '"O '"O '"O N + N N O N ON NN N N NO O O n O ,0 N n 0 9V 0 C r. QQ Q Q Q m O 0 0 R lO 0 O O A A V O 44 J 'O °."I ° O O O O Ocr a a = - a s 3 O 1 N c o c c ? .. 9 A .a Q o o m O 3 F. 3 N 13C FL C O J N — O 0 W W (n 3 q V » O » O O O N N > > ...9 O) 9 .. n W • N N (o (o .,- n y O .Q w w w ors 21 M C Y D.a o ; n 5 "' "' n ° a a a O s 1 O T c c 3 u "0 0 3 a °. a_ a o 0 y Q > m .3 0 < 1 0. .. O y ; v o 0 0 g C D 11 n c c 'J P. .°°. o a °° 3 D 9 ? o x o x o a n A 3 '-- - a `a a c co -oCO - 3a p_ �3 O D a O a W S O o 9 = o O 0. p,-1 3 wa 0 v o , 4 ; s 3 p •� < O v (D .� n a f o v a v < o< < u n < 3 O o c CO l° m V a J C -8 w d m o o 11 0 3 C C O X O 3. O c AX (C 77 7' y o a ° p 3 n g o 0 0 0 - p 9 m 3 3 3 2 a . 7 o 01 2.T. a v l' o n 3 0 a s m o ° a c C .`.., m 9 a $m O S m C a R Q C Q V < ° a R. 0 ° c .i -Q v m (D J c a 3 ® ` ° - i? 3 Y O w 7s ; 13 m m 3 • o y .. tD J ° CO ta A (p 3 w A A -• a o (D ° m m CN. m g, < O O rP a N O U <n —C C I — 0,1cn1a1w1ro1 m N L Iii0'G a E co n o vca IZ p0 0 m m m L ° o C �.007 3 —'a A 1.0.IR IIC — — — — N -� W CI) 7-'v 0 I�Imlal� m m m 3 3 a O O O J 10-101,713' 0.1 0 1, _ - - O O 91 l/� O,�,y,y r m T , ] a D a I IW M' C c c ° ° i v 'M n *.O.O 0 a a a m m •< ii c a c 11 I 0 1 m I rn o < • co � •� A A W C m 7. a r a 0 >3i -a m a c, r A. " < 0 m I I I°1:::1.0 -• s A. n, CD 0 m N O x ° Q 11131x1'0 K L 0 0 73 _ ,a., . a' I I I 0 I I 13 '0 QFl o' 3 Gr a 3.I 0m m 0 -1 3 C G' I°I I 3 m aa- a n 0 3 m 0 ' ' 'C a a n 7 ° a m013 pm I3IrI . 10 o co_ o tDA Ccl �I�11 3W -_m E I D O N n illl10 1 o oc0 D X=-D0 N C Q c ac a. NO 0TI0 n U �m0013c Ia1 m ° = g c I � 0 CO N CO 11 1 I I W m B -I I I 1 1 CD r9 1 1 1 1 v N o 4.;., o - 3 A a o > 1 1 1 1 1 K o� v a O V• u, CA co, I I I I I — — _ — o :1,---_ N m 3 o o o I I I I I a N m o c 0 A 3 N •O N 0 0 a d a R ' O I I x v.' 3 1 19 Contacts: Travis Montgomery (W) 564-4127 or (C) 918-281-9663 Matt Brown (W) 564-5874 or (C) 907-223-7072 Kristine Odom (W) 564-5365 or (C) 907-460-6776 TIS= 3-118 MCE VOY SAFETY NOTES:H2S READINGS AVERAGE 125 ppm WELLHEAD- MCE VOY V_2 A WNB4 ON MI.WELL REQUIRES FULL WHEN ON ML ACTUATOR= O11S i it OKB,ELEV- 88.85' / I BETWEEN SSSVN&X NIP AOOVEPBR PKR(ONLY 338 BEV EV= 51.35' JOINTS). DEPTHS FROM SSSVN-OVERSHOT REFLECT NOP= 1050' 120"CONDUCT-� .-.90' CALIPER(02/15/07).REE•AIR SQZ 12700'-12905'. HOLE � Max Angle= 58'Q 6900' - ..— _ O DRLD ID=2.28".LAST TDM 13434'W A 2.2"OD Datum MD= 13138' CB4TRALILH -03127100. Datum IVO= 880U SS -__-- 1 2027' 2.75: [ 1133!8'CSG,721,L-80 BTRS,D-12.347' 3053' 02 �R ;4 P4 3171' H9-5/8"x 7°BKR ZXP FKR/HG =6.31" I IT'LW-MN,269,1-80,.0383 bpl.D=6 276" - -5509' •-• 4� RD Minimum ID= 1.70 12500' 3-!' ' A{V/6kCS 16ji$/_CIL{ 7"%141 • I . . . . 10090'-10117 I-4.1/2.141f0 WOE PAK.01,E-TRIP01,E-TRIPRESTRICTION ill STRAODLEPATCH,OAL=2T,D=1.785' [TUBING PINCH(02/13110) -{12450'-12452' ;';1471 wir4 12302' CF3MBRT TOP(02/28/10d 11 1'91 12466' 3-1/2'HES X NP,D=2.75' I I X11111 ►IIIA 111 40 1�1�1� 0. 12492'J (8KPBR D=2.95'R 60/40 I RESTRICTION-UNABLE TO PASS w 11.70' 12500'... I/ail 111 (02108/14) G/:1' .. 11►►1AA.. 12508' 9-516'X 3-12'BKR S-3 TCR,Co=3.875' I ►t ►M 312"TBG,9.25,L-80 RBCT, I -12610' , I 12866' 1-3-112'HES XN NP,MLLEU TO 2.74"(01/02/02) .0387 bpi,ID=2.992' ET 13-12"TBG STUB(11/26/01) 12623' 12618' UNEOUE CUSTOM OVERSHOT , •./41� ! $I 111 12743' 31/2'07"6 SLD SUV,i3=2750'I 1 13-t2'TBG,9.30,L-80,.0087 Opt,0=2.99T 12795' ��� 111 �' 91 12795' 9-5/8'X 3-1/2'TNN I'EP-R BPKR I 1017,01 ►.,.R '.:, ►•••� e••ik 12824' 3-12"X 2-78'X0,D=2.387"I • 04, '•••4 ►•••(I CIO• 12800' --I2-7/8"07"6 X NP,D=2.313' ►•••: 21.4••4 s•i i .$4 1281' 93/8'X 7"BOT LNR MGR w/T833A0C,ID=_" I • •Ri [ElM OF CMT SHE/7"'H(02126110) 12905'dbet jt '��� 12893' 2-7/8'OTE X NP,D=2.313'I 12-7/8'TBG 6 48,L_80,.0056 bpi,D=2.441' I 12927' •4 to: 'A:It.:'I:.i. ; 12927' -12-7/8'AUG,D-2.441'I 19-5/8"CSG,476,L-80 BUTT,0=8.681' 13138'_.._ 1 12886' I-I B.PD TT LOC,GFD ON XX/XX/XX I F13RFORATX)N SUMMARY ' FIEF LOG. SWS-BHCS ON 07/12/86 AMIE AT TOPPE7F: 43'@ 13138' Note.Refer to Production DB for historical pert data I 13164' 1-17'MARKER JON- SEE SFF MHRVAL OpNSgz SHOT SOZ 2-1/8' 6 13138-13153 0 02/19/89 ------� - 13400' FISH-MLLEDFASDRILL(04/06/10)1 2-1/8' 4 13262-13364 0 09/10/88 4 I-II-W RP ELEMENT(06117/07) I • 13432' (-mit 2-1/8'X 8'PERF GUNBILLNOSlE 7'LNR,260,L-80 WS,_0383 Of,V=8.276' I: 13433' I— ii CENTRALIZER SPRING -77 77— XO r LNR,290 13434' -{FISP{34'X 2-1/8'PERF GUN,&CCI:TOP I I Pero I-L13508' I 111114111 1 r LNR,290,L-80 SIRS,.0371 bpf,D=6.184' FL 13550' 111111111 DATE REV BY CONIENTS GATE REV BY OOMIENTS PRUDHOE BAY(NT 07118186 AID 2 INITIAL COMPLETION 09/02/13 JL5/PJC SET WRP(SFE3;CLEARANCE) 1NE3.L: Y-24 12104/01 D•15 !000 02/08/14 .1/.0 PJC FULL W19 REST10L:iUN PERMIT Nb:9861130 03/19/10 LLESV FKRSO2(02/28/10) 109117/14 JM) MINOR EDITS FIR TALLIES API N0: 54029-21608-00 04/22/10 JKIYSV FISH MILLED FASORI.L(04/06/10) 10/18/14 CJS/PJC SET STRADDLE PATCH SEC 34,T1 IN,R13E 1349'FM.,83'1W. 02/16/11 MAD AODEDSSSV SAFETY NOTE 01/23/12 WHAM ADD®FQS SAFETY NOTE . - BP Exploration(Alaska) 20 Monthly Injection Report for GPB•MA, Northstar, Milne Point & Endicoofor May 2... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, June 12, 2011 5:14 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Daniel, Ryan Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for May 2011 Attachments: AOGCC Inj Report 06- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the May 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 06- 11.zip» Notes on wells: ^ �:. � Added to Report: WGI -06 (PTD #1900300): Moved from Quarterly Not Operable injection report to Monthly Injection Report after RWO Taken off Report: Y -24 PTD #1861130 A 3.023 cancelled on 5/27/2011 GI -03 (PTD # 1750610): Removed from report after being added for signs of IA represurization during proration 6/2010 Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 6/13/2011 • • SITAlfE AIASEA SEAN PARNELL, GOVERNOR ++ ALASKA OIL .AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO 3.023 Mr. Doug Cismoski, P.E., Wells Intervention Manager Attention: Well Integrity Engineer, PRB -20 BP Exploration (Alaska) Inc. P.O. Box 196612 e JUN u i C01' Anchorage, AK 99519 -6612 RE: Cancellation of Administrative Approval AIO 3.023 Prudhoe Bay Unit Well Y -24 (PTD 1861130) Borealis Oil Pool Dear Mr. Rossberg: Pursuant to BP Exploration (Alaska) Inc. (BPXA)'s request dated May 3, 2011, the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Administrative Approval AIO 3.023, which allows continued water injection in Prudhoe Bay Unit (PBU) well Y -24. This well exhibited tubing by inner annulus (TxIA) communication and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. BPXA has since performed a packer squeeze within PBU Y -24. The well passed a witnessed MITIA on December 17, 2010 and has not shown any indication of TxIA communication while injecting either water or miscible gas. Consequently, Administrative Approval AIO 3.023 no longer applies to operation of this well. Instead, injection into PBU Y -24 will be governed by provisions of the underlying AIO No. 3. DONE at Anchorage, Alaska and dated May 27, 2011. The Alaska Oil and Gas Conservation Commission Daniel T. Se. - • unt, Jr. Cathy ' . Foerster Commissioner, Chair Commissioner • RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of tune shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsi- deration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the appli- cation for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or deci- sion on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That ap- peal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distri- butes, the order or decision on reconsideration, As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to nm is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Y -24 Request for approval to place on MI Page 1 of 3 • Maunder, Thomas E (DOA) From: Vazir, Mehreen [Mehreen.Vazir ©bp.com] Sent: Friday, April 29, 2011 6:29 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: Injector Y -24 (PTD #1861130) Request to cancel AA and continue MI service Attachments: Y -24 TIO 04- 29- 11.doc Tom, WAG Injector Y -24 (PTD #1861130) was placed on MI injection 4/17/2011 and the TIO plot has been monitored for 12 days. It appears the packer squeeze has mitigated the TxIA communication to gas. Do you approve of cancelling the AA (A103.023) and continuing MI service on this well? A TIO plot and Injection plot are attached for your reference. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.6593102 Email: AK, D &C Well Integrity Coordinator @BP.com y, � - ) MAY 7 Z01 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, February 25, 2011 2:44 PM To: AK, D &C Well Integrity Coordinator Subject: RE: Y -24 (186 -113) Request for approval to place on MI Torin, A repair (cement packer) has been attempted on this well. Since the IA pressure was bled in early December, it appears that a differential pressure has been maintained although the amount has been variable. It does appear that the IA and OA are responding to changes in the tubing pressure. This would not be unusual with the annuli fluid packed. It is acceptable to initiate MI injection into this well for the 2 week period you propose. I look forward to seeing the pressure results. Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [ mailto :AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, February 25, 2011 2:30 PM To: Maunder, Thomas E (DOA); AK, D &C Well Integrity Coordinator Subject: RE: Y -24 Request for approval to place on MI 5/26/2011 Y -24 Request for approval to place on MI Page 2 of 3 • • Tom, The IA pressure was bled in early December creating a differential to ensure if there was TxIA communication it would be noticed and reported properly. I have provided an extended TIO plot per your request. Torin From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, February 25, 2011 2:08 PM To: AK, D &C Well Integrity Coordinator Subject: RE: Y -24 Request for approval to place on MI Torin, Do you have "older" TIO information that goes back to when the well was placed on line after the packer squeeze ?? On the TIO data submitted, what caused the lowering of the IA pressure in early December? That pressure change doesn't correspond to any rate change as shown later in the plot? Thanks in advance, Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, February 25, 2011 1:32 PM To: Maunder, Thomas E (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: Y -24 Request for approval to place on MI Tom, Injector Y -24 has an AA (A103.023) for PWI only due to TxIA communication. The well passed an AOGCC witnessed MITIA on 04/15/10 after a packer squeeze was performed 02/27/10 to mitigate the TxIA communication. The asset has recently asked to place the well on MI. Before canceling the AA (A103.023) we would like to place it on MI and monitor the TIO plot to verify the packer squeeze mitigated the TxIA communication while on gas. The proposed plan forward is to cancel the AA if no further signs of IA repressurization are seen while on MI. However, we would like to keep the current AA in place if IA repressurization occurs. Please let us know if you approve placing the well on MI for 10 -14 days at which time the AOGCC will be notified of the results. A TIO plot, injection plot, wellbore schematic and AA have been attached for your reference. «Y -24 TIO Plot 02- 25- 11.doc» «Y- 24.pdf» «Y -24 AA Approval aio3 -023 12- 17- 08.pdf» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 5/26/2011 • • Injector Y -24 (PTD #1861130) TIO Plot W.tY -24 � T - IA 00 OA 000 9...9 0 o. 1SUi M 0029/11 02/05/11 02,2,1 02/1911 02/26, 12/05,1 03/1 69119/11 63/260 24)0210 2419111 04,6,1 0423,1 Injector Y -24 (PTD #1861130) Injection Plot We[V' 24 3200 n - 5 000 3,100 2930 4,800 3000 4.926 906. 2900 4,IG0 2,200 4.816 620 4000 I 3800 - 3900 3 100 q - . 2300 wHro 604 1 700. zsm - w 920 -MI 500 CO Q 1.100 1 2.200 c OIM On 00 2000 1292 1.192 - 1200 1000 &q 900 I 1 100 80 00 V 600 500 000 900 220 800 300 169 120 01/2911 62/05/11 22 02/9111 02/06111 0310/,1 03712/11 03/1 03/19,1 04402/11 04109111 04/16311 04/23/11 • • 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday, January 03, 2011 P.I. Super Jim Rp er visor __ (( J ���? 14 / SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Y -24 FROM: John Crisp PRUDHOE BAY UNIT Y -24 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry JC' NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT Y - 24 API Well Number: 50 029 - 21608 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr101220074005 Permit Number: 186 - 113 - Inspection Date: 12/17/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Y-24 " Type Inj. W' TVD 8423 - IA 780 2600 • 2560 2550 ' P.T.D 1861130" TypeTest SPT Test psi 2105 - OA 140 340 360 360 Interval 1 Interval REQVAP P/F P - Tubing 1260 1260 1260 1260 Notes: AA for IA repressurization. A5-e3, M.. cG,Le 10 114II , ' +,'51K5 A---7113 5,erz..: r tt,tre 4- c�i6 -e 1115 110 6,ur .v3sd b, :A -oae9 AdiiiiNED FEB ( 71 Nil Monday, January 03, 2011 Page 1 of 1 s • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 20, 2010 Mr. Tom Maunder A '10:1 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue r - ;Siot1 Anchorage, Alaska 99501 < _^ Subject: Corrosion Inhibitor Treatments of GPB Y Pad 113 Dear Mr. Maunder, 4. Enclosed please find multiple copies of a spreadsheet with a list of wells from Y Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 12 /20/10 Corrosion Well Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Name PTD # API # cement pumped _ cement date inhibitor sealant date ft bbls ft na gal Y - 01B 2010760 50029203940200 NA 2.5 NA 8.50 4/11/2010 Y - 02A 2011730 50029203950100 NA 0.1 NA 0.85 4/11/2010 Y -03A 2042350 50029204110100 NA 2.2 NA 18.70 4/16/2010 Y - 04 1791050 50029204230000 NA 1 NA 5.10 4/11/2010 Y - 05B 2081380 50029204360200 NA 3.3 NA 20.40 4/15/2010 Y - 06A 2042510 50029204310100_ NA 0.7 NA 3.40 4/16/2010 Y - 07A 2071050 50029205600100 14.5 2.0 0.3 NA 1.70 8/4/2010 Y - 08A 1880560 50029205720100 NA 4 NA 15.30 8/5/2010 Y - 09A 1970830 50029205790100 19 _ 1.5 3.6 NA 17.00 8/4/2010 Y - 10A 2042500 50029205870100 19 3.0 8.75 NA 54.40 8/6/2010 Y - 11C 2051640 50029205130300 NA 0.1 NA 0.90 4/14/2010 Y - 13 1811120 50029206340000 NA 0.4 NA _ 3.40 4/15/2010 Y - 14B 2011010 50029218320200 NA 3.8 NA 20.40 4/10/2010 Y - 15A 2010890 50029209400100 NA 2.1 NA 11.90 4/10/2010 Y - 16 1830490 50029209320000 18.8 2.0 1.7 NA 10.20 8/4/2010 Y - 18 1830290 50029209160000 5.10 4/9/2010 _ NA 0.8 NA Y - 19 1880960 50029218570000 NA 0.2 NA 0.85 4/15/2010 Y - 20A 2010250 50029215870100 NA 1.5 NA 11.90 4/14/2010 Y - 21A 1950370 50029215740100 NA 0.1 NA 1.70 4/13/2010 Y - 22A 1881150 50029215580100 NA 0.5 NA 3.40 8/4/2010 Y -23B 2031640 50029215900200 NA - 1.2 NA 6.80 4/13/2010 r . Y -24 1861130 50029216080000 NA 1 NA 6.80 4/12/2010 Y -25A 2081400 50029218830100 NA 0.3 NA 1.70 4/18/2010 Y - 26A 2010430 50029221910100 NA 0.3 NA 1.70 4/15/2010 Y - 27 1900280 50029220190000 NA 0.5 NA 3.40 4/14/2010 Y - 28 1910650 50029221690000 NA 3.5 NA 28.90 4/12/2010 Y - 29A 1960910 50029221230100 NA 0.2 NA 1.70 4/13/2010 Y - 30 1910150 50029221350000 NA 0.5 NA 2.60 4/13/2010 Y -31 1910560 50029221610000 NA _ 0.5 NA 3.40 4/12/2010 Y - 32 1910410 50029221490000 NA 0.3 NA 1.70 4/18/2010 Y -33 1910300 50029221440000 NA 0.9 NA 6.80 4/12/2010 Y -34A 1990040 50029221780100 NA 0.9 NA 5.10 4/11/2010 Y -35A 2022370 50029221860100 NA 1.5 NA 10.20 4/15/2010 Y -36 1931310 50029224000000 NA _ 0.9 NA 5.95 4/10/2010 Y -37A 2020460 50029224030100 NA 0.8 NA 6.00 4/14/2010 i MEMORANDUM To: Jim Regg ~ ) P.I. Supervisor ~~fi / ~ JZ3,f ~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, Apri122, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Y-24 PRUDHOE BAY UNIT Y-24 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv -,.~ Comm Well Name: PRUDHOE BAY UNIT Y-24 Insp Num: mitCS100418100353 Rel Insp Num: API Well Number: 50-029-21608-00-00 Permit Number: 186-113-0 Inspector Name: Chuck Scheve Inspection Date: 4/15/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Y-za "Type Inj. ~ ~/ 'I'`/D 8423 IA 750 2400 ~ 2350 2340 P.T.D 1861130 ~TypeTCSt SPT Test psi 2105 ~ QA 110 280 280 280 Interval °T~R ~ p/F P ~ Tubing noo 1100 1100 1100 NOteS: Test performed post packer cement squeeze. Thursday, April 22, 2010 ~` `..:, x' "- - Page 1 of 1 OPERABLE: Injector Y -24 (PTD #1861130) AOGCC MITIA Passed Page 1 of • • Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWelllntegrityEngineer ©BP.com] Sent: Friday, April 16, 2010 2:08 PM To: NSU, ADW Well Integrity Engineer; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); GPB, Area Mgr Central (GC1 /3 /FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Welis Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Schmoyer, Al; Holt, Ryan P (ASRC); Quy, Tiffany Subject: OPERABLE: Injector Y -24 (PTD #1861130) AOGCC MITIA Passed Attachments: MIT PBU Y -24 04- 15- 10.xls All, Well Y -24 (PTD #1861130) passed an AOGCC witnessed MIT -IA to 2400 psi on 04/15/2010. The passing test verifies the well has two competent barriers and re- establishes UIC compliance. The well has been reclassified as Operable. AA 3.023 approved 12/17/08 will now be cancelled. Please find the attached MITIA form from the test as reference. «MIT PBU Y -24 04- 15- 10.xis» Please call with questions or concerns. Thank you, M � 1 LO Gerald Murphy (for Anna Dube) Well Integrity Coordinator Phone: (907) 659 -5102 Pager: (907) 659 -5100 x1154 : NSU, ADW Well Integrity Engineer Sent: Th • . , April 08, 2010 5:47 AM To: 'Maunder, Th. E (DOA) ; 'Regg, James B (DOA) ; 'Schwartz, Guy L (DOA) ; 'Brooks, Phoebe L (MAY; GPB, Area Mgr Central (GC1 /3 /FS3); GPB, GC1 OTL; GPB, GC1 - : •. Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Welis Opt Eng; GPB, Optimization Engr; - •rod Controllers Cc: Schmoyer, Al; NSU, ADW Well Integrity Enginee , .It, Ryan P (ASRC); Quy, Tiffany Subject: UNDER EVALUATION: Injector Y -24 (PTD #18611 ready for injection post packer squeeze to obtain AOGCC MITIA All, Injection well Y -24 (PTD #1861130) had TxIA communication and was approve. • continued water injection under AA 3.023 approved 12/17/08. After an attempt to patch the well was unsuccess . he well was classified as Not Operable. A packer squeezed was completed on 2/27/10 and the well passed an MITIA to 4000 psi on 3/6/10. The downhole plug has been milled an now the well is ready to be placed on injection. The well has been reclassified 5/26/2011 ~,~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION API~~P~ OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair W Plug Perforations ^ Stimulate^ Other ~ PKR REPAIR Performed: Alter ~ ing Perforate New Pool ^ Waiver^ Time Extension ^ Cer-+ew~E Pav~e~ Change Approved Program ^ utdown ^ Perforate ^ Re-ente Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: y.~Y•ce Name: Development ^ Exploratory ^ 186-11 30 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ API Number: Anchorage, AK 99519-6612 50-029-21608-00-00 8. Property Designation (Lease Number) : 9. Well Name and Numbe ~ ADLO-047471 PBU Y-24 10. Field/Pool(s): Prudhoe Bay FIELD / Prudhoe Bay POOL 11. Present Well Condition Summary: Total Depth measured 13550 feet Plugs (measured) None feet true vertical 9207.2 feet Junk (measured) 13432' 13434' feet Effective Depth measured 9207 feet Packer (measured) 3171 12506 12795 true vertical 9151 feet (true vertical) 2743 8423 8634 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 3015 13-3/8" 72# L-80 SURFACE - 3053 SURFACE - 2672 5380 2670 Intermediate 13100 9-5/8" 47# L-80 SURFACE - 13138 SURFACE - 8889 6870 4760 Production Liner 681 7"26# L-80 12869 - 13550 8688 - 9207 7240 5410 Scab Liner 2696 7" 26# L-80 3171 - 5800 2743 - 4294 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 3-1 /2" 9.3# L-80 SURFACE -12795 SURFACE - 8634 2-7/8" 6.4# L-80 12824 - 12927 8655 - 8732 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X7" BKR PKR 3171 2743 9-5/8"X3-1/2" BKR S-3 PKR 12506 8423 9-5/8"X 3-1/2" TIW HBBP-R PKR 12795 8634 12. Stimulation or cement squeeze summary: Intervals treated (measured): (n~ ~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 912 985 14. Attachments: Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X 16. Well Status after wo Oil Gas WDSPL GSTOR ^ WA GINJ ^ WINJ! ~ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-008 Contact Gary Preble Printed Name Gary Pr a Title Data Management Engineer Signature Phone 564-4944 Date 4/13/2010 rune iuwu~r r~fsvwCU ~icuu~ • ^vi7fYiV FU I~ 1 = (U10 ~ / ~uuin/n/v'ii~ jai viuy Y-24 186-113 DFDF ATTA(_NMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Y-24 10/28/86 PER 13,262. 13,342. 8,983.97 9,046.05 Y-24 1/1/87 APF 13,342. 13,364. 9,046.05 9,063.11 Y-24 1/1/87 RPF 13,302. 13,342. 9,014.99 9,046.05 Y-24 10/5/87 SQZ 13,262. 13,364. 8,983.97 9,063.11 Y-24 10/24/87 RPF 13,262. 13,364. 8,983.97 9,063.11 Y-24 11/23/87 RPF 13,262. 13,364. 8,983.97 9,063.11 Y-24 3/26/88 SQZ 13,262. 13,364. 8,983.97 9,063.11 Y-24 4/24/88 RPF 13,262. 13,272. 8,983.97 8,991.71 Y-24 9/10/88 RPF 13,262. 13,332. 8,983.97 9,038.28 Y-24 2/19/89 APF 13,138. 13,153. 8,888.95 8,900.24 Y-24 2/19/89 RPF 13,332. 13,364. 9,038.28 9,063.11 Y-24 2/10/10 BPS 12,836. 12,837. 8,664.15 8,664.89 Y-24 2/13/10 APF 12,450. 12,452. 8,383. 8,384.43 Y-24 2/27/10 SQZ 12,300. 12,500. 8,277. 8,418.86 Y-24 4/6/10 BPP 12,836. 12,837. 8,664.15 8,664.89 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE Y-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 2/10/2010?"""WELL SHUT IN ON ARRIVAL"** (pre pkr sqz) DRIFT W/ 2.25" CENT, TEL, 1-1/2" S. BAILER TO TT @ 12910 SLM, -14' _ a 12896' CORR. TO ELMD SET COMPOSITE FAST DRILL PLUG @ 12850 SLM/ 12836' MD~„~ CMIT TxIA 3620 PSI TUBING LOST 10 PSI IN 15 MINUTES & 0 PSI 15 MINUTES LATER, IA LOST 0 & 0 ***WELL LEFT SHUT IN, DSO WALK THROUGH UPON DEPARTURE''** 2/10/2010~T/I/O = 0+/Vac/Vac. Temp = SI. TBG & IA FL for SL. TBG FL @ 210', IA FL ;near surface. Slickline in control of well. 2/13/2010 ***WELL SHUT-IN ON ARRIVAL*"" (ELINE -TUBING PUNCH) ~SSV =CLOSED ON ARRIVAL, INITIAL T/I/O = 900/950/0. BLEED TUBING DOWN TO 250 PSI. RU ELINE FOR TUBING PUNCH. T BING PUNCH 3-1/2" 9.3 # TUBING AT 12450'-12452' R FERENCED TO ~S B LDL DATED 4-SEPTEMBER-2007. ATTEMPTED TO CREATE PRESSURE DIFFERENTIAL ACROSS TUBING SAND IA, PUMPED UP TUBING TO 800 PSI, IA FOLLOWED, TRIED TO BLEED IA DOWN, TUBING PRESSURE TRACKED. T/1/O = 700/700/0 AT FIRE. 'TUBING PUNCH FIRE CONFIRMED AT SURFACE. "**JOB CONTINUED ON 14-FEBRUARY-2010*** 2/14/2010,"""JOB CONTINUED FROM 13-FEBRUARY-2010*"* ~RD ELINE FROM TUBING PUNCH. WELL SHUT-IN ON DEPARTURE. FINAL T/I/O = 100/100/0. *""JOB COMPLETE*** 2/24/2010~T/I/0= 100/100/20 Temp= S/I Circ-out TxIA (Pre CTD, cement squeeze) 3Attempted to take returns down Y-30, flowline appears to be frozen. Currently standing by for well support to rig up new hard line jumper to Y-23. *** Job 3continued on 2-25-10 WSR*'"'` 2/25/2010~CTU 8, 1.75" CT, Job Scope: Packer squeeze. Move from F 09 to Y 24. Arrive on Y pad wait for full bore to finish circulating Y-24 with diesel. MIRU. ;Wait on weather. See weather ticket for CTU #8. 2/25/2010:*** Job continued from 2-24-10 WSR*** Circ-Out (Pre cement squeeze) Pumped ~3 bbl Neat Meth spear followed by 860 bbls inhibited SW followed by 210 bbls `75*f diesel for freeze protect. U-tubed TxIA for 1 hr. Bled W HP down. Bled back -3 bbls fluid. FWHP's= 0/0/20. Freeze protected surface equipment w/ 10 bbls diesel. Y-23 turned back over to PCC. Y-24 tree as follows: Swab, Wing, SSV= shut. Master, IA, OA,= open. 2/26/2010 CTU #8 w / 1.75" ct: Job scope: Cement packer squeeze. Complete rigging up. Make up 2" cement nozzle. Wait on PO to open SSV. RIH to plug at 12855' ctmd. Begin cement job. Pump 16 bbls of 15.8# cement. Displace with water with cementers. Job continued on 2/27/10. 2/27/2010;CTU #8 1.75" CT, Job Scope :Packer squeeze. Cement job continued from X2/26/10. Continue displacing 16 bbls of cement with cementers through CT. 'S~ueeze away 12.5 bbls into IA. Wash tubing with biozan, POOH ,freeze protecting at 2500 MD. At surface, secure CT and wait on weather. (Ambient PTemp: -45 F, Wind chill: -65 F) 2/28/2010;CTU #8.1.75" CT Job scope Packer Squeeze. End Weather standby at 7pm. RDMO from Y-24. Move to SLB yard."*Job Complete** 3/5/2010 T/I/O=SSV/Vac/Vac. Temp SI. IA FL (pre Full Bore). IA FL near surface. ,SV,WV,SSV=C. MV=O. IA,OA=OTG. NOVP. Pressured up tbg to 1400 psi with 0.5 bbls methanol. Rigged up to IA and pressured up to 4000 psi with 10.6 bbls neat methanol. IA lost 40 psi in first 15 `minutes and 30 psi in second 15 minutes for a total loss of 70 psi in 30 minutes. Second test - IA lost 0 psi in 30 minutes. Bled IAP. FWHP's=0/0/OVALVES in =following positions -and operator notified of positions and result of job: Wing closed, Swab closed, SSV closed, Master open, IA open, OA open -Well SI .~..._..... ~~.~_. ~ .~. _~.~.~.m.~~ 3/6/2010~T/I/O=0/0/0 Temp=SI~MIT IA PASSED to 4000 psi (Post packer squeeze 4/2/2010~T/I/O & Temp- unavailable @ this time. Pull flash point samples and prep for continued excavation of well cellars. Crew Change Out 4/4/2010 CTU #9 1.75" CT Job Scope: Mill Fasdrill Plug. CTU on location waiting for DSO to sign permit. .....Job continued on WSR 4/5/10 ~._.~ _. m _ .. ~ ~ ~____ _-_-_ 4/4/2010 T/IfO=O/0/0 .Temp=15 RG-2401 (Surface casing corr mitigation) PJSM. Set up the Hydro-vac & job site. Start & complete the excavation on the well cellar. RDMO. 0 4/5/2010 T/t/O = 20/0/0 . MIT Tubing PASSED to 3650 psi. Pumped down Tbg 3.1 bbls diesel to MIT. Tbg lost; 110 psi in 1st 15 mins and 50 psi in the 2nd 15 mins for a total loss of 160 psi in the 30 minute Test. Bled pressures back to starting and CTU is on location. Notified Pad operator of well status. FWHP's=0/0/0. _.~_..~.~.~~.~.® M~..~_ ~~~~ ~..m~~~~~~n..~ a CTU #9 1.75" CT Job Scope. Mill Fasdrill Plug. Continue from WSR 4/4/10. MIRU CTU. MU BTT Milling BHA w/ 2.30" 3-Blade Junk Mill and RIH. Sit down at 12393'. Mill cement from 12393' to 12461' ctmd with 6 hard stalls. POOH to change BHA. RIH with 2.13" motor and 2.68" Pirahnah Mill. Milled to 12798' ctmd and had several hard stalls, POOH for smaller mill for composite plug. ...Job continued on WSR 4/6/10... 4/6/2010CTU #9 1.75" CT Job Scope: Mill Composite Plug Continue from WSR 4/5/10 Continue swap out milling BHA's. RIH with 3-Bladed Junk Mill to mill plug. ~Ta ed com osite lug at 12, 869' ctmd, had a few stalls then were able to push ;the plug 35' past bottom pert. Lay in 6 40 eOH freeze protect from 2500'. ~RDMO. ***Job Complete*** FLUIDS PUMPED BBLS 1156 1% KCL 324 60/40 METH 20 GEOVIS 55 150K LSRV GEOVIS 15 DIESEL 2148 Total TREE = 3' 1/8" MCEVOY WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = 88.85' BF. ELEV = 51.35' KOP = 1050' Max Angle = 58 @ 6900' Datum MD = 13138' Datum ND = 8800' SS (20" CONDUCTOR ~-~ 90' 13-318" CSG, 72#, L-80, ID = 12.347" ~--) 3053' ~ 7" LNR-CMTd, 26#, L-80, .0383 bpf, ID = 6.276" ~ TUBING PUNCH (02/13/10} ~-~ 12450' - 12452' Minimum ID = 2.28'" @ 12844' TOP OF CEMENT SHEATH SAFETY NOTES: 3-112" TALLY (11130101} LIST 339 FULL Y-24 JOINTS BETWEEN SSSVN & X NIP ABOVE PBR PKR (ONLY 338 JOINTS}. DEPTHS FROM SSSVN -OVERSHOT REFLECT CALIPER (02/15!07}, REPAIR SQZ 12700' - 12905'. HOLE DRLD ID = 2.28". CAUTION: FISH ON BTM. LAST TD @ 13434' W A 2.2" OD CENTRALIZER - 03127100. 2027' 3-1/2" HES XDB SSSVN, ID = 2.75" a 3171' 9-518" x 7" BKR ZXP PKR /HGR, ID = 6.31" 12302' ~TOPOFCMT(02/28/10) 12466' 3-1/2" HES X NIP, ID = 2.75" 12492' BKR 80!40 PBR, ID = 2.95" 12506' 9-518" X 3-1/2" BKR S-3 PKR, ID = 3.875" 12566' ~ 3-1/2" HES XN NIP, ID = 2.74" (MILLER 01102!02} 12618' H UNIQUE CUSTOM OVERSHOT ' ' 12743' 3-112" OTIS SLD SLV, ID = 2.750" 12795' 9-518" X 3-1/2" TMi HBBP-R PKR 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 12795' 12824' 3-1/2" X 2-7l8" XO, ID = 2.387" 12836' 2-718" FASDRILL (02110110) ~~~°ip ~~~ 12$Q4' "TOP OF CMT SHEATH IN TBG, ID = 2.28" aQaw ... 12860' 2-7/8" OTIS X NIP, ID = 2.313" 9-518" X 7" BOT LNR HGR W/ TIEBACK LBTM OF CMT SHEATH (CTM) i '1-i Z9U5`Ct 2-7/8" TBG, 6.4#, L-80, .0058 bpf, ID = 2.441" 12927' 9-518" CSG, 47#, L-80 BUTT, ID = 8.681" ~-j 13138 PERFORATION SUMMARY REF LOG: SWS - BHCS ON 07/12186 A NGLE AT TOP PERF: 43 @ 13138' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1(8" 6 13138 - 13153 O 02!191$9 2-118" 4 13262 - 13364 O 09/10/88 PBTD 7" LNR, 26#, L-80 TC4S, .0383 bpf, ID = 6.276" 13508' 13550' 2-7/8" OTIS X NIP, ID = 2.313" 12927' --12-718" TBG TAII, ID = 2.441"' 12896' ELMD TT DATE NOT AVA ILABLE 3161' H 7" MARKER JOINT J-1 FISH - WRP ELEMENT (06(17/07} 13432' FISH - 2-118" X 8" PERF GUN/BULLNOSE CENTRALIZER SPRING 13434 FISH - 34' X 2-1l8" PERF GUN, & CCL TOP DATE REV BY COMMENTS DATE REV BY COMMENTS 07!18!86 ORIGINAL COMPLETION 03(19/10 LLVSV PKRSOZ (02128!10) 12/04/01 RWO 06/10/09 TFA/TLH PATCH PULL & RESET 02/27/10 OPGPJC PULL PATCH (01!12!10) 02/27/10 JF/PJC SET' FASDRILL (02110/10} 02!27!10 JF/PJC TBG PUNCH (02/13/10) PRUDHOE BAY UNff WELL: Y-24 PERMIT No: 186-1130 AID No: 50-029-21608-00 SEC 34, T11 N, R13E 1349' SNL, 83' EWL BP Exploration {Alaska} UNDER EVALUATION: Injector Y-PTD #1861130) Ready for injection post packer squeez... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, April 08, 2010 5:47 AM K,~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Schmoyer, AI; NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Quy, Tiffany Subject: UNDER EVALUATION: Injector Y-24 (PTD #1861130) Ready for injection post packer squeeze to obtain AOGCC MITIA All, Injection well Y-24 (PTD #1861130) had TxIA communication and was approved for continued water injection under AA 3.023 approved 12/17/08. After an attempt to patch the well was unsuccessful, the well was classified as Not Operable: A packers ueezed was completed on 2/27/10 and the well passed an MITIA to an~o psi on 3/6/10. The downhole plug has been mille an nowt a well is ready to be placed on injection. The well has been reclassified as Under Evaluation so that once it is on-line and thermally stable, an AOGCC witnessed MITIA can be obtained and the old AA can be cancelled...- Please find the attached MITIA form for reference. «MIT PBU Y-24 03-06-10.x1s» '~ Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Gaordinator GPB Wells Group Phone: {907) 659-5102 Pager: (907) 659-5100 x1154 `~~)y~ ~ Prt ~ ~ ~ 1C' 4/8/2010 e ~ ~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alas ka.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe~ y@alaska.,gov 1 ~ ¢~~' ~/° ~ ~ OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay / Prudhoe Bay / Y-Pad DATE: 3/6/10 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well Y-24 Type Inj. N TVD 8,423' Tubing 1,400 1,950 1,950 1,950 Interval O F P D. 1861130 P T Type test P Test psi " 2106 Casin X4,000 3,960 3,930 / P/ . . Notes: MITIA post packer squeeze. Plan to put well on OA 0 0 0 0 injection and obtained AOGCC witnessed MITIA for UIC compliance. Well Type In'. TVD Tubing Interval P/F P.T.D. Type test Test psi Casing Notes: OA Well Type Inj. TVD Tubing Interval P/F P.T.D. Type test Test psi Casing Notes: OA Well Type Inj. TVD Tubin Interval P/F P.T.D. Type test Test psi Casing Notes: OA Well Type Inj. TVD Tubin Interval P/F P.T.D. Type test Test psi Casing Notes: OA INTERVAL Codes TYPE INJ Codes TYPE TEST Codes I =Initial Test D =Drilling Waste M =Annulus Monitoring 4 =Four Year Cycle G =Gas P =Standard Pressure Test V =Required by Variance I =Industrial Wastewater R =Internal Radioactive Tracer Survey T =Test during Workover N =Not Injecting A =Temperature Anomaly Survey O =Other (describe in notes) W =Water D =Differential Temperature Test MIT Report Form MIT PBU Y-24 03-06-10.x16 BFL 11/27107 • • SEAN PARNELL, GOVERNOR t~itCS-7~ OI~ ~ 1i0-7 333 W. 7th AVENUE, SUITE 100 COI~TSER~A'!'IO1~T COrII~II55I011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Matt Brown Well Intervention Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 ,, t l Anchorage, Alaska 99519-6612 1 t Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU Y-24 Sundry Number: 310-008 ~ F ~ Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount Chair h~ DATED this2' ~ay of January, 2010 Encl. STATE OF ALASKA ~~~ t•~Z'r~ ~~ ALAS IL AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALS on nnc o~ inn s :~ x t v a 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool^ Repair Well^ Change ApprovedT Program^ Altercasing^ Plug Perforations ^ Perforate^ Pull Tubing^ j yt~ p pp~~ ~~+s ~. di l~Si~~ iJ~i Cat iyrv:a ~i: ~ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ + .r, Other: KR REPAIR 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 186-1130 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21608-00-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^ ^ PBU Y-24 Spacing Exception Required? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-047471. PRUDHOE BAY Field / PRUDHOE BAY Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13550 ~ 9207.2 - 13487 9151 NONE 13432', 13434' Casing Length Size MD ND Burst Collapse Structural Conductor 110 20" SURFACE 110 SURFACE 110 Surface 3015 13-3/8" 72# L-80 SURFACE 3053 SURFACE 2672 5380 2670 Intermediate 13100 9-5/8" 47# L-80 SURFACE 13138 SURFACE 8889 6870 4760 Liner 681 7" 26# L-80 12869 13550 8688 9207 7240 5410 Scab Liner 2629 7" 26# L-80 3171 5800 2743 4294 7240 5410 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - 3-1/2" 9.3# L-80 SURFACE 12795 2-7/8" 6.4# L-80 12824 12927 Packers and SSSV Twe: 7" BKR ZXP Packers and SSSV MD and ND (ft): 3171 2743 3-1/2" BKR S-3 12506 8423 3-1 /2" TIW HBBP-R PKR 12795 8634 12. Attachments: Description Summary of Proposal ^ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^/ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/28/2010 Oil ^ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^~ - GINJ ^ WAG ^ Abandoned ^ Commission Representative: 6 ~~ 3,023 .2 . ~GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Brown Printed Name B n Title Well Intervention Engineer Signature Phone Date 564-5874 1/14/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3/v r a4~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other. Subsequent Form Required: /~ , L~ 0 APPROVED BY COMMISSIONER THE COMMISSION A d b Date: ~ Z pprove y: otiv \ ~ RBD,~: JAN` 2 2 20~ ~Rr~f~AL ~-z~/~ l~i~D Form 10-403 Revised 12/2009 Submit in Duplicate Y-24 186-113 PFRF ATTAC_NMFNT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth .Base Y-24 10/28186 PER 13,262. 13,342. 8,983.97 9,046.05 Y-24 1/1/87 APF 13,342. 13,364. 9,046.05 . 9,063.11 Y-24 1/1/87 RPF 13,302. 13,342. 9,014.99 9,046.05 Y-24 10/5/87 SQZ 13,262. 13,364. 8,983.97 9,063.11 Y-24 10/24/87 RPF 13,262. 13,364. 8,983.97 9,063.11 Y-24 11/23/87 RPF 13,262. 13,364. 8,983.97 9,063.11 Y-24 3/26/88 SQZ 13,262. 13,364. 8,983.97 9,063.11 Y-24 4124/88 RPF 13,262. 13,272. 8,983.97 8,991.71 Y-24 9/10/88 RPF 13,262. 13,332. 8,983.97 9,038.28 Y-24 2/19/89 APF 13,138. 13,153. 8,888.95 8,900.24 Y-24 2/19/89 RPF 13,332. 13,364. 9,038.28 9,063.11 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~~ Y-24 Packer Repair To: Jerry Bixby /Clark Olsen, Well Operation Supervisors AI Schmoyer - Y- Pad Engineer From: Matt Brown -Wells Engineer Subject: Y-24 Packer Repair Please perform the attached packer repair procedure: Date: January 14, 2010 Code: PBYPDWL24-N 1 S Pull Patch. Caliper tubing to >12927'. Set WRP at 12300'. MITT to 4000 psi. Pull WRP. Run composite in 2-7/8" tubing at 12836' CMITxIA to 4000 si. Pum down tub & establish circ rate u IA. 2 EP Punch Holes at 12450. Establish circulation. Pending low circ rate in step 1. 3 C Cement Packer Squeeze. FCO to composite. WOC 3 days 4 F MITIA to 4000 psi. 5 CP Mill composite & push to bottom- Pending MITIA success Current Status PWI Well, SI Latest Inj 2600 BWPD, 1700 PSI WHIP, 5/09 Max Deviation 58° at 6900 ft Min ID 1.75" C~ 12378' (patch) 2.28" C«~ 12844' (cement sheath) Last Tag:. 13,341' SLM on 5/23/06 Last Downhole Op: Set WFD tubing patch, 6/10/09 Latest H2S value: No data available for well SBHP/T: 3357 psi / 215° ave for Y-Pad for 2009 SBHP/T: 3512 psi /209° on 08/19/99 most recent for Y-24 Note: Sundry from -the State for this work needs submission & approval Objective: The objective for this job is to place a cement plug in the IA to repair TxIA communication via leaking seals in the PBR at 12492'. Once the ann comm has been repaired, the well will be put back into MI service. Y-24 Packer Repair Historv: Y-24 was drilled in 1986 as a producer and cum'd 550 mbo. It was converted to injection in 1992 and has cum'd 8.3 mbw and 4.9 bcf of MI to date. A pacer squeeze was performed in 1996 to fix ann comm. During this squeeze, a sand plug was placed, cement circulated up the IA and then subsequently milled out of the tubing. A cement sheath was left in the tubing. tail, reducing the id from 2.441" to 2.28". A RWO was performed in 2001 to run & cement a scab liner across leaks in the 9-5/8" casing and to and replace the tubing for MI service. During the RWO, there was considerable difficulty in spacing out; sand, metal pieces and some cement kept plugging up the the tubing while stabbing into the PBR. It is likely that the some of the seals were damaged at this time and eventually failed completely. A LDL performed in 5/07 indicated a leak at 12402' in the 3-1/2" tubing. The leak was patched in 7/07. The followup MITIA failed and a second. patch was run in 1/08. The well continued to have some TxIA comm problems and was put on PWI-only service. A TecWell LDL was performed in 11/08 but found no leaks. The patch was pulled and a long slick stick patch was run in 6/09. The followup MITIA failed and the well has been SI since the patch was run. Due to the positive FOR response seen in offset producers Y-20A and Y-29A, the asset would like to fix the TxIA communication and return Y-24 to MI service. Job Discussion The patch will be pulled as the first part of the procedure. A caliper of the tubing is called for to determine the nature of the cement sheath left behind during the 1996 packer fix; the documented id thru the 2-7/8" tubing tail is 2.28". A Baker Quik Drill composite plug OD is 2.113" and the Halliburton FasDril is 2.18". The caliper will tell if setting a composite plug is a viable option for the packer squeeze. After the caliper, a WRP will be set above the known leaks and the tubing pressure tested to ensure integrity above the holes. Pending results of the caliper, a composite plug will be set in the 2-7/8" tubing tail to isolate the perfs. Holes will be punched at +/-12500' and circulation from the tubing up the IA will be established. CT will place 12.5 bbls up the IA thru the holes and the cement in the tubing will be cleaned out and the cement will be allowed to set up for 3 days. Subsequently, a MITIA to 4000 psi will be performed. After passing the MITIA, the composite will be milled up and pushed to bottom. AnnComm Historv: 2 Y-24 Packer Repair > 08/03/01: MITOA Passed > 11/16/01: PPPOT - IC Passed > 12/04/01: RWO fixed PC leak > 03/27/02: AOGCC MITIA Passed post RWO > 10/19/02: MIT-IA 3500 psi Passed > 08/27/03: Pit water injection complete > 02/28/04: CAM repair WH leak, PPPOT-T to 5000 psi Passed > 03/05/04: MIT-IA 4000 psi Passed pre-MI swap (State Witnessed) > 03/31/04: Pulled TTP, ran MCX w/ 0.75 bean > 06/30/06: IA FL @ Surface > 07/25/06: De-watering complete > 09/05/06: Bled TIO from 1430/1940/380 to 1430/410/230, IAP repressured to 1550 is 2 days > 09/10/06: Notified AOGCC of IA repressurization > 09/28/06: T FL @ 408', IA FL @ surface > 09/30/06: AOGCC MITIA Passed to 3000 psi > 02/17/07: Tbg Caliper 419 jts 0-20%, 1 jt 21 > 02/18/07: WRP set @ 12538' MD > 03/09/07: PPPOT-T Passed to 5000 psi, IC Passed to 3000 psi > 03/30/07: CMIT-TxIA Passed to 3000 psi, MIT-T Failed, MITIA Failed > 05/05/07: MITT Failed, est LLR~9.66 gpm @ 1000 psi > 05/08/07: LDL identifies leak at 12402' > 06/17/07: Pull WRP from 12529' SLM > 07/24/07: Set lower patch > 08/18/07: Set upper patch > 08/24/07: MITIA Failed post-patch, Est LLR of 1 bpm @ 2400 psi > 09/04/07: LDL found leak @ 12420 w/ smaller pin holes > 11/14/07: Pulled patch > 02/12/08: Set WFD lower packer assy @ 12440' > 02/24/08: Set WFD upper packer assy @ 12424' SLM > 02/25/08: MITIA Passed to 3000 psi > 03/16/08: AOGCC MIT-IA Failed > 03/20/08: Requested AOGCC approval to leave well on injection to repeat MITIA > 03/23/08: MITIA Passed to 2400 psi > 03/29/08: AOGCC MITIA Passed to 2400 psi > 09/20/08: MIT-IA Passed to 4000 psi > 09/27/08: IAP bled to 550 psi > 09/30/08: IAP increased 1440 psi since bleed > 10/01 /08: IAP bled to 590 psi > 10/02/08: IAP increased 850 psi overnight > 10/03/08: IAP increased 500 psi overnight > 10/10/08: AOGCC MITIA Passed to 4000 psi, witnessed declined > 10/13/08: IAP bled to 290 psi > 10/14/08: IAP increased 750 psi overnight > 11/15/08: Ran Memory TecWell from 12408' SLMD to surface - no leaks found > 05/25/09: Pulled patch @ 12440' 3 Y-24 Packer Repair > 05/28/09: Set lower ER Packer C«3 12490' > 06/09/09: Set slick-sticks and upper Packer up to 12391' > 06/16/09: MIT-IA Failed Contact for Procedure: Matt Brown 564-5874 w 223-7073 c 344-1130 h CC: Well File 4 Y-24 Packer Repair Slickline: 1. Pull WFD patch assembly. See attached diagram for patch details. 2. Run PDS caliper survey from tubing tail (12927') to surface. Download data and correlate to tubing tally (attached). 3. Set WRP at 12300'. MITT to 4000 psi. 4. Pull WRP from 12300'. 5. Set composite plug for 2-7/8" at 12836' (1St jt of 2-7/8" tub). 6. CMITIA to 4000 psi. 7. Swap to pumping down tubing & taking returns up IA. Establish LLR. 8. RDMO. E-line- NOTE: to be performed if LLR < 2 bpm at 500 psi in step 7 above 1. MIRU E-line. MU GR/CCL + 2' 20 ES Puncher RDX charges + eccentering subs per PE Manual guidelines. 2. RIH & tie into SLB LDL of 4-Sep-07. 3. Shoot holes at 12450'-12452'. POOH. 4. Pump diesel + seawater down tubing, taking returns up IA, allowing enough diesel to FP IA. Monitor pump rate and pressure. RDMO. CT: 1. MIRU 1.75" CT unit. Ensure Tubing & IA are liquid packed. 2. MU cementing nozzle, connector and no check valves. RIH and tag composite Cap 12836'. Pick-up until full string weight is observed. PUH 10'. Flag CT. 3. Confirm LLR TxIA circulation by pumping diesel down the tubing and taking returns up the IA. Monitor for 1:1 returns. 4. Batch mix 16 pumpable bbls of 15.8 ppg Unislurry cement which will give 500 psi compressive strength in 5 hours and ~ 2000 psi ultimate compressive strength. BHT at packer depth of 12506' (8334' SS) is 210 deg F. Cement properties: Volume to Pump 16 bbl total Cement Type 15.8 ppg Unislurry Thickening Time. 2 hours at 170°F BHCT Fluid Loss 90 - 120 cc/30-minutes at 170°F BHCT 500 psi comer str 3-5 hours • Volume calculations: 5 Y-24 Packer Repair o Target 100 ft of cement above highest leak in tub = 12402' -100'= 12302' cement top in IA o Bottom in tub: 12836' (composite plug to be set) o Vol cmt in tub below punch holes: [12450'- 12836'] x 0.0087 bbl/ft= 3.4 bbls o Vol cmt in IA above packer: [12506' - 12302'] x .0613 bbl/ft= 12.5 bbls o Total cement: 3.4 + 12.5 = 16 bbls • Catch a sample of the cement for QC testing. (This needs to go to the lab to determine when the blend reaches 500 psi compressive strength. Lab must be notified prior to the job 659-2423.) Once the blend is approved, conduct Job Scope meeting to ensure that participants know the upcoming job sequence. 5. RIH to flag. Pump following down the coil: • 5 bbl water spacer • 16 bbls Unislurry Cement • 5 bbl water spacer • MEOH for FP of CT Pump as follows, taking returns up CT x T annulus: a. Pump 5 bbl water spacer. Shut in reel valve. b. Displace surface lines until good 15.8 ppg cement is achieved. Open the manifold to the reel and pump the cement -into the reel. Pump 16 bbls of cement and shut in reel valve. c. Displace the surface lines to fresh water. Open reel valve and chase cement with fresh water. 6. Displace the cement to the nozzle at max rate. Reduce the pump rate when cement is 2 bbls from the nozzle. Nozzle should be at flag. 7. Pump 1 bbl cement up around coiled tubing and then POOH while laying in cement at 1:1 returns (as best as possible) with IA shut in. Lay in 16 bbls cement. 8. PUH to safety at 10900'. WCTOC is 10995' if no cement is placed in the annulus. Maintain 100 psi WHP. 9. Shut in CT x T annulus and open IA. Hold WHP at 100 psi. 10. While parked at safety, Circulate 12.5 bbls of cement up the IA. Monitor returns at surface to 40 bbl tank. Close in IA once 12.5 bbl fluid has returned to surface. Once IA is closed, Maintain constant IA pres. WHP will increase as cmt is circulated up IA and cleanout begins. 6 Y-24 Packer Repair 11. Swap to biozan down CT. Circ bio to nozzle maintaining IA pres constant. Once bio is near nozzle, RIH jetting at max pump rate to 12836'. The only cement to contaminate & circ out is the ~3.4 bbls below the tubing punch holes and above the composite at 12836'. Take bbl counts, accounting for volume pumped and CT displacement. 12. POH 1:1 jetting to 10900'. Swap to slickwater. Park coil and note IA pres & WHP. Circ out bottoms up. Pump 65 bbls slickwater (CT x 3-1/2" annular vol at 10900' is 65 bbls). 13. POOH from 10900' while replacing voidage. Maintain constant. WHP and IA pres. FP top of well with McOH or diesel. 14. RDMO CT. FB- MITIA 15. WOC for 3 days 16. MITT to 4000 psi. 17. MITIA to 4000 psi. If there is a leak, establish LLR &pres. CT- Mill Composite- PENDING MITIA PASS 18. MU motor and 2.3" mill & jars and RIH. 19. Mill composite at 12836' and push to bottom. 20. POOH. FP well. Y-24 Packer Repaf;r TREE= 3-1/8" MCEVOY WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = w,.. 88.85' _a „ - BF. ELEV = . .~ . 51.35' K_OP=_ _ ~ 1050' Max Angle = 58 @ 6900' Datum ND = 131 DatumTVD= 8800' 38' ~ 20" CONDUCTOR SS L-80, D = 12.347 D = 6.31" 17" LNR CMi'D. 2611, L-80, D = 6.276" 12378'-12490' ELM 3-1/2" WFD"ER" PATCH (06/10109), D= 1.75" 12466' 3-i/2"HESXNP,D=2.75"lBEHINDPATCH 02/24/08) Minimum ID =1.75" @ 12378' ELM TOP OF 3-1/2" WFD PATCH = z.7a" 13-112" TBG, 9.3#, L-80..0087 bpf, ID = 2.992" I 12844' H "TOP OF CMT SHEATH N TBG, ID = 2.28" 9-518" X 7" BOT L(W2 HGR W! TIEBACK BTM OF CMT SHEATH (CTM) TBG. 6.4#, L-80, .0058 bpf, ID= 2.441" D = 8.681" PERFORATION SUMMARY REF LOG: SWS - BHCS ON 07/12/86 ANGLE AT TOP PERF: 43 @ 13138' Note: Refer to Production DB for historical pert data SQE SPF NTERVAL Opn/Sqz DATE 2-1/8" 6 13138 - 13153 O 02119189 2-118" 4 132fi2 - 13364 O 09/10!88 17" LNR 26#, L-80 7C4S, .0383 bpf, ID = 6.276" H 13550' SAFETY NOTES: 3-112" TALLY (11!30101) LIST 339. FULL Y-24 JOINTS BI7VYEEN SSSV N S X NIP ABDV E PBR PKR (ONLY 338 JOINTS). DEPTHS FROM SSSVN-OVERSHOT REFL~T CALIPER (02/15!07). REPAIR S(3Z 12700' - 12905'. HOLE DRLD ID= 2.28". CAUTION: FISH ON BTM. LAST TD ~ 13434' W A 2.2" OD CENTRALIZER - 03/27/00. 2027 3-1 /2" HES XDB SSSV N, D = 2.75" 7L/4S I'"-I3-1/[V1IJ SlU JIV, IU=Z./JU 12795 9-518" X 3-1/2" TM! HBBP-R FKR 12824' 3-112" X 2-718" XO, D = 2.387" 12860' 2-718" OTIS X NIP, ID = 2.313" 12893' 2-7/8" OTIS X NIP, ID = 2.313" 12927 2-718" TBG TAB, ID = 2.441" 12896' ELMDTTDATENOTAVAILABLE 161' H 7" MARKER JOINT i ? FISH - WRP ELEMENT (06!17/07) 432' FISH - 2-1/8" X 8" PB2F GUWBULLNOSE CFNTRA L¢ER SPRING 434' H FISH - 34' X 2-118" FERF GUN. 8 CCL TO DATE REV BY COMMENT8 DATE REV BY COMMENTS 07!18186 ORIGINAL COMPLETION 11/20!07 GJF/PJC PULL PATCH (11!14!07) 12104(01 RWO 02/22/08 JKDlfLH LWRPKRASSYSET(02/12/OH) 06!05101 CWKAK CORRECTIONS 03/11/08 CJN/TLH UFPERPATCHSET(02l24/O8) 01/07/02 CWTP CORRECTONS 06/10109 TFAfRH PATCH PULL 8 RESET 06/24/07 HS/PJC RWO CORK/ SFTY NOTE 09/18707 JLJ/PJQ SET UPPER PATCHASSY(OS/18! 07) PRUDHOE BAY UNIT WELL: Y-24 PERMIT No: 186-1130 API No: 50-029-21608-00 SEC 34, 711 N, R13E 1349' SNL, 83' EWL BP Exploration (Alaska) 8 Y-24 Packer Repair LDL 04-Sep-07 Y-24 Packer Repair _ _.__ . __.._.7 .•.+.~, ~ 11/V.ifV ~IVAIi1NMA 1 R4G ppYQl+l1b D;~a# 111]Od2001 ~ '~ WELL. ~! t?S Y.34 T'U9QM~4G ~.'~'' t-bQ NSC7 THG YY'f, 9.2~ 132 J"CS 4N 4il4GK apt JTS RAht ::' ~'~:1 ~JIfB TT;t 8f 433711,85 CT Ot+t RACK t23~s3 i4 F4° RI-N ---~ ITEM palm lion Sl-tFieda~; $122:.+TY~'E, Cf~1~1+19CTtt'iN t37`S d/,ill IL? ! 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To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska], Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and l'7 ~s-62C~ ? ~5 4/9 ProActive Diagnostic Services, Inc. V ~ ~-' I ~ ~ " I l3 ~ ~~5 b Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907] 2458952 1) Leak Detection -.~ 31 ~ct-08 06-05 2J LeakDetection - WLD 14Nov 08 Y-24i , I Signed Print Name: • Date ' -`~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORA3E, AK 99618 PHONE: (907)245-8951 FAX: (907)245-88962 E-MAIL : ~~s~~c~3+3r~r~eCa)srae9fiaa~'~J£®~ WEBSITE : ~NLww.rs9~a'23ar~$~~e~.v~3s'~a 1 Color Log / EIS 50-029-20298.00 1 Color Log / ~0E ~~' S~O~ 1 fi`t ,s, ~' C:\Documenfs and Settings\Ownet\Desktop\Transmit_BP.docx OPERABLE: Y-24 (PTD #1861130) IA repressurization Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ ~~i~j~~ Sent: Friday, November 21, 2008 4:49 PM t To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC1 Wellpad Lead; GPB, GC1 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Quy, Tiffany Subject: OPERABLE: Y-24 (PTD #1861130} IA repressurization All, / ~, Well Y-24 (PTD #1861130) has confirmed !A re ressurization but assed a MITIA to 4000 psi on 10/10/08. Therefore the weal has been reclassified as Operable. request far AOGCC Adminis ra Ive pprava or continued operation with IA repressurization will be signed and sent to the AOGCC on Monday, November 24, 2008. A leak detection log was run will the well was on water iniection but was unsuccessful at locating a leak. Once MI injection is available, the well will be logged while on Mi injection in attempt at locating the leak. Unti! then, the well may remain on water injection. Please let me know if you have any questions. Thank you, ,,~nna ~Du6e, ~'. E. Weil Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907} 659-5100 x1154 ~~~~~~ ~~ ~ G! ~F ~ 20~ From: NSU, ADW Well Integrity Engineer Sent: Saturday, November Ol, 2008 9:17 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GCi Wellpad Lead; GPB, GCl OTL; GPB, Area Mgr Central (GC3/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot Subject: UNDER EVALUATION: Y-24 (PTD #1861130) High IA Pressure Hi all, Y-24 (PTD #1861130) has been reclassified as Under Evaluation. Although the MITIA passes and plans are already progressing to run a leak detect log, increased injection rates have caused the iA pressure to increase above maximum operating pressure limits. The wellhead pressures were tubing/lA/OA equal to 1680/2140/540 on 10/30!08. The welt has been placed on a 28-day clock. Operations may continue to operate the well at these higher pressures as the iA has been tested to 4000 psi until the log is obtained. The plan forward is to: 1. Eline: Log the well on water 2. Well integrity Engineer: Evaluate log results for repair ar secure. A TIO plot and wellbore schematic have been included for reference. ~ 11 /24/2008 OPERABLE: Y-24 (PTD #1861130) IA repressurization Page 2 of 2 • Thank you, Anna 1~u6e, ~'.2. Weil Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, October 28, 2008 1:00 PM To: 'Regg, James B (DOA)' Cc: 'Maunder, Thomas E (DOA)'; NSU, ADW Well Integrity Engineer; Engel, Harry R Subject: Y-24 (PTD #1861130) Plan to place well on MI injection Hi Jim, Y-24 (PTD #1861130) exhibits IA repressurization however it passed a MITIA to 4000 psi on 10/10/08. Our plan is to place the well on MI injection and conduct an LDL to determine the source of the leak. It is believed that there is a higher chance of identifying the leak with the well on MI injection. Please respond with your concurrence of this plan. The well will be added to the Monthly Injection Report. Plan forward: 1. Operations: Swap well to MI Injection 2. E-line: Leak detection log with well on MI 3. Operations: Swap well back to water injection 4. Well Integrity Engineer: Evaluate log results for repair options A TIO plot and wellbore schematic have been included for reference. ~/ Thank you for your assistance, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: {907} 659-5102 Pager: {907) 659-5100 x1154 11 /24/2008 i ~- N ~ .~ ~~ 1 1 • .~ 0 a 0 d ~ O ~ ~ a a 0 m _~ O O 1 ---- TREE= 3-118" MCEVOY WELLHEAD= --- MCEVOY ACTUATOR - OTIS K8. ELEV = _ 88.85' BF. ELEV - 51.35' KOP = 1050' Max Angte = 58 c? 6900' Datum MD __ Datum TV = 13138' ~ 20" CONDUCTOR D - 8800' SS 13-3l8" CSG, 72#, L-80, ID = 12.347" • I 3053' I SAFET TES: 3-112°' TALLY {11f30f01) LIST 339 Ft#LL ~~~~ JOfN~WEEN SSSVN & X NIP ABOVE PBR PKR {ONLY 338 J S). DEPTHS FROM SSSVN -OVERSHOT REFLECT CALIPER {02115107}. REPAIR SQZ 12700' - 12905'. HOLE DRLD ID = 2.28". CAUTION: FISH ON BTM . LAST TD @ 13434' W A 2.2" OD CENTRALIZER - 03!27!00. 2{)27' 3-112" HES XDB SSSVN, ID = 2.75" 3171' f -I 9-518" X 7" BKR ZXP PKRIHGR, ID = 6.31 "' 7" LNR-CMTD, 26#, L-80, ID = 6.276" I-{ 5800' 12413'-12471` H 3-1l2" WFD "ER" PATCH (02124/08}, ID = 1.75" 124$6` H3-1/2" HES X NIP, ID = 2.75" {BEHIND PATCH 02!24108) J Minimum iD =1.75" @ 12437' 3-1 d2" WFD PATCH {MIDDLE) 12492' BKR 80/40 PBR, ID = 2.95" 1 12506` 9-5(8" X 3-1/2" BKR S-3 PKR, ID = 3.875" 12~- 566' ~- 3-1i2" HES XN NIP, ID = 2.74" (MILLED 01/02/02) I I 12618' ~ -~ UNIQUE CUSTOM OVERSHOT I ' 12743` 3-112" OTIS SLD SLV, ID = 2.750" 12795' 9-5/8" X 3-112°` TMJ HBBP-R PKR 3-112" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 12795` 12$24` 3-1/2" X 2-7/8" XO, !D = 2.387" 12$44° *TOP OF CMT SHEATH IN TBG, ID = 2.28" 12860` 2-718" OTIS X NIP, ID = 2.313" 9-5f8" X 7°' BOT LNR HGR Wl TIEBACK BTM OF CMT SHEATH (CTM) ~ 1- j 2905 ct 2-718" TBG, 6.4#: L-8fl, .0058 bpf, ID = 2.441" 1292T 9-518" CSG, 47#, L-80 BUTT, ID = 8.681" ~ 1313$' PERFORATION SUMMARY REF LOG: SWS -BRCS ON 07112!86 ANGLE AT TOP PERF: 43 @ 13138' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-118" 6 13138 - 13153 O 02f19/89 2-1/8" 4 13262 - 13364 O 09i10l88 PBTD 7" LNR, 26#, L-80 TCAS, .0383 bpf, ID = 6.276" 1350$' 12$93' I--12-718" OTIS X NIP, ID = 2.313" 12927' -~ 2-7/8" TBG TA ll, !D = 2.441 " 12$96' ELMD TT DATE NOT AVAILABLE 13161' I-{ 7" MA RKER JOINT ~-j FISH - WRP ELEtvtENT (06117/07} 13432' FISH - 2-1l8" X 8" PERF GUN/BULLNOSE CENTRALCZER SPRING 13434` FISH - 34' X 2-118" PERF GUN, & CCL TOP DATE REV BY COMMENTS DATE REV BY COMMENTS 07!1$186 ORIGINAL COMPLETION 11/20/07 GJFfPJC PULL PATCH (11114/47) 12104/01 RWO 02122!08 JKDITLH LWR PKR ASSY SET (02/12108] 06105/01 CH/KAK CORRECTIONS 03111/08 CJNITLH UPPER PATCH SET (02l24i08) 01107,102 CHiTP CORRECTIONS 06(24/07 HS/PJC RWO CORR.( SFTY NOTE 09(18(07 JLJ/PJC SET UPPER PATCH ASSY (O8i18/07) PRUDHOE BAY UNff WELL: Y-24 PERM(1" No: 186-1130 API Nc: 50-029-21608-00 SEC 34, T11 N, 813E 1349' SNL, 83` EWL BP Exploration {Alaska} Y-24 (PTD #1861130) Plan to place well on MI injection Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, October 28, 2008 2:23 PM I ~ t~~~Z~~Zi~~ To: 'NSU, ADW Well Integrity Engineer' Cc: Maunder, Thomas E (DOA); Engel, Harry R Subject: RE: Y-24 (PTD #1861130) Plan to place well on MI injection Page 1 of 1 Based on information provided regarding Y-24, it is acceptable to swap the well to MI to perform the LDL. Once lagging is completed, you may return the well to water injection while you pursue repairs ar administrative approval for continued injection without repair. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~~y4~~~ ~;C?1' ~ ~ 20G$ From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, October 28, 2008 1:00 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSU, ADW Well Integrity Engineer; Engel, Harry R Subject: Y-24 (PTD #1861130) Plan to place well on MI injection Hi Jim, Y-24 (PTD #1861130} exhibits IA repressurization however it passed a MITIA to 4000 psi on 10/10/08. Our plan is to place the well on MI injection and conduct an LDL to determine the source of the leak. It is believed that there is a higher chance of identifying the leak with the well on MI injection. Please respond with your concurrence of this plan. The well will be added to the Monthly Injection Report. Plan forward: 1. Operations: Swap well to MI Injection 2. E-line: Leak detection log with well on MI 3. Operations: Swap well back to water injection 4. Well Integrity Engineer: Evaluate log results for repair options A TIO plot and wellbore schematic have been included for reference. «Y-24 TIO PIot.BMP» «Y-24.pdf» Thank you for your assistance, Anna ~u6e, X1'.2. Well Integrity Coordinator GPB Wells Group Phone: {907} 659-5102 Pager. {907} 659-5100 x1154 10/28/2008 ~ ~ ~ yy ~~ ~ T ~ ___--_ N N O O Q. ~_ £ ~1 l M :4 ~~ N -~ T ~ d c~ a o 0 0 a o ~ ~ ~ i o r I 0 0 L { o ~ a ~ o ~ a j ~ ~ v I I i o 0 N Fti O a cv a v w a~ 0 z- Tom' ~,'~ ~ ~ ~ 4-a 4~ N N ~~ ~---~ &oJ VV 0 0 a o 0 0 cv TREE= 3-1r8" MCEVOY WELLHEAD= MCEVOY ACTUATOR = KB. ELEV - OTIS 88.85' BF. ELEV - KOP = Max Angle = _..51.35' 1050' 58 @ 6900' Datum MD = 13138' Datum TV D = 8800' SS • 20" CONDUCTOR ~--~ 90' 13-3f8" CSG, 72#, L-80, ID = 12.347° ~--~ 3053' 9-5l8" X 7" BKR ZXP PKRIHGR, ID = 6.31 " 7°' LNR-CMTD, 26#, L-80, ID = 6.276" S-i 5800' Minimum ID =1.75" @ 12437' 3-112" WFD PATCH (MIDDLE) ~ 12413'-12471'r 3-112" WFD "ER" PATCH (02!24!08}, ID = 1.75" 12466' - 3-112" HES X NIP, ID = 2.75" (BEHIND PATCH 02!24!08} 12482' BKR 80/40 PBR, iD = 2.95" 125O6~L-5f8°' X 3-112" BKR S-3 PKR, ID = 3.875" 12566. ~~- 3-1/2" HES XN NIP, ID = 2.74" (MILLED 01102102} I I 1261$" ~ UNIOUE CUSTOM OVERSHOT , I I 12743' 3-1(2" OTIS SLD SLV, fD = 2.750" 12795' 9-518" X 3-112" T(W HBBP-R PKR 3-112" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 12795` 12824` 3-1r2" X 2-7/8" XO, ID = 2.387" 12844° °TOP OF CMT SHEATH IN TBG: fD = 2.28" 12864` 2-718" OTIS X NIP, tD = 2.313" 9-5r8" X 7" BOT LNR HGR W/ TIEBACK BTM OF CMT SHEATH (CTM) 2-7l8" TBG, 6.4#, L-80, .0058 bpf, tD = 2.441" 9-518" CSG, 47#, L-$0 BUTT, ID = 8.681" ~-~ 13138 PERFORATION SUMMARY REF LOG: SVt~S - BHCS ON 07112186 ANGLE AT TOP PERF: 43 @ 13138' Note: Refer to Production DB for historical parf data SOLE SPF INTERVAL OpnlSgz DATE 2-1l8" 6 13138 - 13153 O 02/19/89 2-1x8" 4 13262 - 13364 O 09/10x88 PBTD 7°` LNR, 26#, L-80 TC4S, .0383 bpf, ID = 6.276" 13508' 13550' 12893' ~-{ 2-718" OTIS X NIP, ID = 2.313" 1j 2927' (-j 2-7r8" TBG TAIL, ID = 2.441" 12896° ELMD TT DATE NOT AVAILABLE 13161' H 7" MARKER JOINT _~-~ FISH - WRP ELEMENT (06117107} 13432' FISH - 2-118" X 8" PERF GUN/BULLNOSE CENTRALIZER BERING FISH - 34' X 2-118" PERF GUN, & CCL TOP DATE REV BY GOMMENTS DATE REV BY COMMENTS 07(18186 ORIGINAL COMPLETION 11/20/07 GJF{PJC PULL PATCH (11114/07) 12104/01 FtWO 02/22!08 JKDlTLH LWR PKR ASSY SET (02/12(08) 06(05/01 CH(KAK CORRECTIONS 03/11/08 CJNITLH UPPER PATCH SET {02x24108) 01107102 CH1TP CORREGTIONS 06/24/07 HStPJC RWO CORR.( SFTY NOTE 09!18!07 JLJIPJC SET UPPER PATCH ASSY (08r18r07) PRUDHOE BAY UNIT WELL: Y-24 PERMIT No: 186-1130 API No: 50-029-21606-00 SEC 34; T11 N, R13E 1349' SNL, 83' EWL BP Exploration {Alaska} UNDER EVALUATION: Y-24 (PTD #1861130) IA Repressurization Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ I d1 Z~3 ~0 $ Sent: Thursday, October 02, 2008 8:04 PM ~~ l To: Regg, James B (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng Cc: Townsend, S. Eliot; Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Schmoyer, AI; Julian, Jennifer Y Subject: UNDER EVALUATION: Y-24 (PTD #1861130) IA Repressurization Attachments: Y-24.pdf; Y-24 TIO and Injeciton Plots.doc Aii, Well Y-24 (PTD #186113fl) is exhibiting IA re~ressurization after being patched in February 2008. The wellhead pressures were tubing/IA{OA equal to 1550119701470 on 10/2/08 when the IA pressure was hied to 470 psi. The fA repressurized to 1440 psi overnight. The high pressure was first thought to be due to an increase in 'rniection rate but the repressurization is more than is expected from thermal effects alone. The well has been reclassified as Under Evaluatian. The plan forward is to: 1. Operations: Leave the well on water injection 2. Fullbore: AOGCC MITIA 3. Well Integrity Coordinator: Evaluate MITIA results and passibly apply for AA if the MITIA passes. /2 ~~~dc~ ~~~~~ A wellbore schematic, TIO pint, and injection plot have been included for reference. r/ «Y-2 > «Y-24 TIO and Injeciton Plots.doc» Please let me know if you have any questions. 10/28/2008 OPERABLE: Y-24 (PTD #1861130) MIT-IA Passed Page 1 of 2 • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, October 13, 2008 4:12 PM To: Regg, James B (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng Cc: Townsend, S. Eliot; Schmoyer, AI; Julian, Jennifer Y; NSU, ADW Well Integrity Engineer Subject: OPERABLE: Y-24 (PTD #1861130) MIT-IA Passed All, Well Y-24 (PTD #1861130} passed an MIT-IA to 4,000 psi on 10/10008. The passing test proves two competent barriers. Therefare, the well has been reclassified as Operable. However, possible IA repressurization is still suspected and further diagnostics will be completed. The plan farward far the well is as follows: 1. D: Bleed IAP to evaluate IA repressurization 2. WIC: Eval far LDL or AA applicatian Please call with any questions or concerns, Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Thursday, October 02, 2008 8:04 PM To: 'Regg, James B (DOA)'; GPB, Area Mgr Central (GC1/3/FS3); GPB, GCl OTL; GPB, GCl Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng Cc: Townsend, S. Eliot; Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Schmoyer, AI; Julian, Jennifer Y Subject: UNDER EVALUATION: Y-24 (PTD #1861130) IA Repressurization All, Weil Y-24 (PTD #1861130} is exhibiting IA repressurization after being patched in February 2008. The wellhead pressures were tubing/IA/OA equal to 1550119701470 on 10/2/08 when the cA pressure Was bled to 470 psi. The IA repressurized to 1440 psi overnight. The high pressure Was first thought to be due to an increase in injection rate but the repressurization is more than is expected from thermal effects alane. The Well has been reclassified as Under Evacuation. The plan farward is to: 1. Operations: Leave the well on water injection 2. Fzallbore: AOGCC MITIA 10/28/2008 OPERABLE: Y-24 (PTD #1861130) MIT-IA Passed Page 2 of 2 3. Well Integrity Coordinator: Evaluate MITIA results and possibly apply for AA if the MITIA passes. A welibore schematic, Tl0 plot, and injection plot have been included for reference. Please let me know if you have any questions. Thank you, /~nna 1~ude, ~'.E. WeII Integrity Caordlnatar GPB WeIIs Group Phone: (907) 659-5102 Pager: {907) 659-5100 x1154 10/28/2008 PBU Y-24 TIO Pressures PTD 186-113 a,onn 3,000 nnn 1,r~on PBU Y-24 Injection Plot <),C~Or ~ a,000 3 F00 <<, ii i ~ ~ 3.000 ~' 2,500 0 ti s ~ ni ii i 2,000 1,500 0 ~'~~~iCI 1:000 500 07/05/02 07113102 02/02/08 02116102 0$130102 Oy113102 Oy/Z7102 i ~ ~2{ zeug L s 07105!02 07172,'00 0?fly/02 07f26fD2 USfULfUY U~:v~'uu unnbiu~ uo~c.iruu UOIJV~u0 ~~:uu,v~ ~~. ~..•..., ~...--.-- --~- ~ -- Y-24 (PTD #1861130) MIT F~ • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~ ~~/.~,~z~~ Sent: Thursday, October 23, 2008 4:13 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: Y-24 (PTD #1861130) MIT Form Hi Jim, The AOGCC North Slope Inspector declined to witness the test on Y-24. Thank you, Anna ~u6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: {907) 659-5102 Pager: {907) 659-5100 x1154 :~ From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, October 21, 2008 1:59 PM To: NSU, ADW Well Integrity Engineer Subject: RE: Y-24 (PTD #1861130) MIT Form who from AOGCC witnessed? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Sunday, October 19, 2008 8:29 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert) (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: Y-24 (PTD #1861130) MIT Form Jim, Tom and Bob, 7 Please see the attached MIT form for the passing AOGCC witnessed MIT-IA on well Y-24 (PTD #1861130). «MIT PBU Y-24 10-10-08 .xls» ----- Please call with any questions or concerns. Thank you, 10/24/2008 Y-24 (PTD #1861130) MIT F~ ~ Page 2 of 2 Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 10/24/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. ~e ~ LD ~ ~' ~ Prudhoe Bay !PBU / Y Pad 10/10/08 Andrea Hughes Packer Depth Pretest Initial 15 Min. 30 Min. Well Y-24 Type Inj. W TVD 8423' Tubing 1,380 1,380 1,380 1,380 O P.T.D. 1861130 Type test P Test psi 4000 Casing 1800 /4000 3940 3900 Notes: MIT-IA to eval well for IA re-pressurization. OA 0 25 25 28 Well Y-24 Type Inj. W TVD 8,423' Tubing 1380 1,380 1,380 1,380 Interval O P.T.D. 1861130 Type test P Test psi 4000 Casing 3,900 4,000 3,960 3,940 P/F P Notes: MIT-IA to eval well for IA re-pressurization. OA 28 32 32 30 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPEINJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Repor[ Form BFL 11!27!07 2008-1010 MIT PBU Y-24 2tests.xls From: NSU, ADW Well Integrity Engineer [NSIJADWWeIIIntegrityEngineer@BP.com] Sent: Monday, April 07, 2008 1:04 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Operations Supervisor; Engel, Harry R; NSU, ADW Well Integrity Engineer Subject: Y-24 IA valve flange replacement Attachments: 100_0091.] pg Jim, ~ ~, ti~3~ ~i '~" ~- I received a phone call from John Crisp a few days after the MITIA on Y-24 explaining that he had found an ANSI 1500 blind flange connected to the IA companion valve during the test. Due to a lack of knowledge transfer during change out of the field crew, I cannot confirm that the flange was in fact ANSI 1500. However, I can confirm that the flange has been replaced with an API 5000 flange with a needle valve connected. I have attached a photo for your reference. «100_0091.jpg» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 S~ANINED MAY 0 6 2008 `~~~j~ MEMORANDUM TO: Jim Regg ~ GF I~~~~ P.I. Supervisor ~~~ FROM: John Crisp Petroleum Inspector State of Alaska . Alaska Oil and Gas Conservation Commission DATE: Friday, April 04, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC Y-24 PRUDHOE BAY Lei iIT Y-24 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~l'~- Comm Well Name: PRUDHOE BAY UNIT Y-24 API Well Number 50-029-21608-00-00 Inspector Name: John Crisp Insp Num: mitJCr080403123705 Permit Number: 186-113-0 Inspection Date: 3/29/2008 Rel Insp Num: Packer Depth Pretest Initial 15 blin. 30 Min. 45 Min. 60 Min. WBII ~ Y-24 ~T~e Inj. !~ W ~ TVD ~ 8426 `~ IA 390 ~~ 2360 ~~ 2260 2190 ~ 2160 P.T. ~ 1861130 ~T~'peTCSt~ SPT ~ TCSt pSl ~ 2106.5 '~ QA ~ 10 ~ 40 ~ 40 ~ 40 40 Interval ~TAL P/F -Y P ~jv, - Tubing ', t ~ ~o t ~ ~o ~ I t ~o '~ > > ~o ~ t t ~o I Notes' ~ bbl's pumped for test. The Operator is going to call this test a pass. I will request Supervisor review to make AOGCC determination of pass or fail. This test performed with tri plex pumping methanol. The previous test was performed with diesel using Hot Oil truck. The final pressure after 45 minutes was close enough to 10% loss to have Supervisor review. ~s~~~+ JUL G ~ 200$ Friday, April 04, 2008 Page 1 of I Y-24 (PTD #1861130) Reclassified as Operable Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) ~ `i ~~~~ Sent: Wednesday, April 02, 2008 12:31 PM ~~~~ (, To: 'NSU, ADW Well Integrity Engineer' Subject: RE: Y-24 (PTD #1861130) Reclassified as Operable Please add PBU Y-24 to the monthly well integrity rpt so TIO pressures can be monitored at least for the next month. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 ~~~„~~ ~UL ,~ ~ ~~~$ Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Sunday, March 30, 2008 3:28 PM To: Regg, James B (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GCi OTL; GPB, GC1 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Schmoyer, AI Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); NSU, ADW WI Tech Subject: Y-24 (PTD #1861130) Reclassified as Operable All. Y-24 (PTD #1861130) passed an AOGCC witnessed MITIA on 3130/08 after the well had reaohed thermal stabilization. The passing MITIA verifies patch integrity and restoration of wail integrity. The Well has been reolassified as Operable. Please see the attached MiT farm details. «MIT PBU Y-24 03-29-08 .xls» Please call With any questions or concerns. Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Thursday, March 20, 2008 2:39 PM To: 'Regg, James B (DOA)' Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: RE: Y-24 (PTD #1861130) Reclassified as Under Evaluation Hi ,)lm. Y-24 {PTD #1861130) recently failed an AOGCC Witnessed MITIA after being patched. The form was submitted by e-mail on 03118108. With year approval, We plan to leave the Well on injection to conduct another MITIA to assist in further diagnostics. if the MITIA fails, the well will be shut-in and a plug Will be set. If the MITIA passes, We Will contact the AOGCC inspector to witness another MITIA. The plan forward includes: 1. DHD: Repeat the MITIA to 2400 psi with triplex and obtain a liquid leak rate if it fails. 2. Slickline: if the MITIA fails, drift to top of patch; set WRP at 12,385' MD 4/2/2008 Y-24 (PTD #1861130) Reclassified as Operable Page 2 of 2 3. Fulibore Pumping: MIT-T to 2400 ~gainst WRP. If the MIT-T fails GMIT-Txi,~2400 psi. d If the MITIA fails, setting a plug and pressure testing Wiil help determine if the leak is above or below the plug. From: NSU, ADW Well Integrity Engineer Sent: Wednesday, February 27, 2008 8:14 AM To: 'Regg, James B (DOA)'; GPB, Area Mgr Central (GCl/3/FS3); GPB, GCl OTL; GPB, GCl Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Schmoyer, AI Cc: Townsend, S. Eliot; Holt, Ryan P (ASRC); Dahlem, Jason E; NSU, ADW Well Integrity Engineer Subject: Y-24 (PTD #1861130) Reclassified as Under Evaluation Jim, Well Y-24 (PTD #1861130) passed an MITIA post tubing patch on 02/25/08. The passing MITIA verified the patch integrity, which mitigated the TxIA communication. The well has been reclassified to Under Evaluation and will have an AOGCC witnessed MITIA performed once the well has been put back on injection. Please see the attached MIT form for the MITIA. Operations -The well can be put on water injection at your earliest convenience. Please notify Well Integrity if any indication of TxIA communication still exists. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 4/2/2008 MEMORANDUM TO: Jim Regg ~~~ ~34 P.I. Supervisor G FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commis DATE: Thursday, Apri103, 2008 SUBJEC"I': Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Y-24 PRUDHOE BAY UNIT Y-24 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ ~~~ Comm Well Name: PRUDHOE BAY UNIT Y-24 Insp Num: mitCS080318085647 Rel Insp Num: API Well Number: 50-029-21608-00-00 Inspector Name: Chuck Scheve Permit Number: 186-113-0 Inspection Date: 3/16/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- __---- - - - -- Well Y-za Type Inj. w TVD 8446 IA soo 2360 zz6o ztso ztoo --- P.T D ts6tt3o TypeTest SPT Test psi znt.s p,~ too 220 ~ 2to Ito zlo ~ --- --- interval OTHER p~F F Tubing tz6o tz6o }} t23o tzoo t2oo -- - --- - __ ___ _.- ..- - --_ _ __ -~ - -- _ L_ - --- ------ -~-- -- Notes' A tubing patch had been set from12413 to 12471 measured depth. This report reflects the second test performed at this time. The initial test showed 160 psi loss in first 15 minutes and 120 psi loss in second 15 minutes. r ~Gt55P~ I [~~'~~ GYM ~ Z ~ ~ r • . - ~~~es~ ~~~-.car- ~rbvtc~ ~u.e~~-c~l~~ ' ~~o pbt ~.,~uU,~,,{z,~ ~+~e5,w-~~ L~~ivtnt,ti~ 4~ ~ ~Zfiur~ ~~N APR 4 ~ 200$ Thursday, April 03, 2008 Page 1 of 1 RE: Y-24 (PTD #1861130) Recled as Under Evaluation Page 1 of~, • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, March 28, 2008 4:34 PM To: 'NSU, ADW Well Integrity Engineer' Subject: RE: Y-24 (PTD #1861130) Reclassified as Under Evaluation Timing for completion of the 2nd MIT? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~ APR ~ ZO(s~ From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com} Sent: Thursday, March 20, 2008 2:39 PM To: Regg, James B (DOA) Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: RE: Y-24 (PTD #1861130) Reclassified as Under Evaluation Hi Jim. Y-24 (PTD #1861130) recently failed an AOGCC Witnessed MITIA after being patched. The form Was submitted by e-mail on 03118!08. With your approval, we plan to leave the Well on injection to conduct another MITIA to assist in further diagnostics. if the MITIA fails, the well Wili be shut-in and a plug Will be set. 1f the MITIA passes, We Will contact the AOGCC inspector to witness another MITIA. The plan forward includes: 1. DHD: Repeat the MITIA to 2400 psi With triplex and obtain a liquid leak rate ifi it fails. 2. 5lickline: If the MITIA fails, drift to top of patch, set WRP at 12,385' MD 3. Fullbore Pumping: MIT-T to 2400 psi against WRP. If the MIT-T fails CMIT-TxIA to 2400 psi. if the M1TiA fails, setting a plug and pressure testing Will help determine if the leak is above or below the plug. Please let me know if you have any questions. Thank you, ,~ l~ul6e, ~'.~E. ell Integrity Coordinator GPB ells Groufa Phone: {9017) 659-5102 Pager: (907) 659-5°1(30 x°1'154 From:. NSU, ADW Well Integrity Engineer Sent: Wednesday, February 27, 2008 8:14 AM To: 'Regg, James B (DOA)'; GPB, Area Mgr Central (GCl/3/FS3); GPB, GCi OTL; GPB, GCl Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Schmoyer, AI Cc: Townsend, S. Eliot; Holt, Ryan P (ASRC); Dahlem, Jason E; NSU, ADW Well Integrity Engineer Subject: Y-24 (PTD #1861130) Reclassified as Under Evaluation 3/28/2008 Y-24 (PTD #1861130) Reclassif d as Under Evaluation • Regg, James B (DOA) Page 1 of 1 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com) ~ c 3 i t~ I~ Sent: Wednesday, February 27, 2008 8:14 AM ~ ~ l To: Regg, James B (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Schmoyer, AI Cc: Townsend, S. Eliot; Holt, Ryan P (ASRC); Dahlem, Jason E; NSU, ADW Well Integrity Engineer Subject: Y-24 (PTD #1861130) Reclassified as Under Evaluation Attachments: MIT PBU Y-24 02-25-08 .xls Jim, Well Y-24 (PTD #1861130) passed an MITIA post tubing patch on 02/25/08. The passing MITIA verified the patch integrity, which mitigated the TxIA communication. The well has been reclassified to Under Evaluation and will have an AOGCC witnessed MITIA performed once the well has been put back on injection. Please see the attached MIT form for the MITIA. "~ Operations -The well can be put on water injection at your earliest convenience. Please notify Well Integrity if any indication of TxIA communication still exists. «MIT PBU Y-24 02-25-08 .xls» Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 3/19/2008 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay /PBU / Y-Pad 02!25/08 Anna Dube ~~ 3~(~(v rf ~,~~,3 ~~ Packer Dept Pretest Initial 15 Min. 30 Min. Well Y-24 Ty e Inj. N TVD 8,423' Tubing 50 50 50 50 Interval O P.T.D. 1861130 Type test P Test si 3000 Casing 0 /3000 2920 2880 P/F P Notes: MIT-IA to 3000 psi post tubing patch OA 0 0 0 0 Well T e In~. TVD Tubing Interval P.T.D. Ty e test Test si Casing P(F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. T e test Test si Casing P/F Notes: OA Well T e In'. TVD Tubing interval P.T.D. T e test Test si Casing P/F Notes: OA Well T e Inj. TVD Tubin Interval P.T.D. T e test Test si Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test i INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11 /27!07 MIT PBU Y-24 02-25-08 .xis • Wage 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 25, 2008 12:46 PM To: 'Preble, Gary B (SAIC)' Subject: 404 questions Gary, I am reviewing some recently submitted 404s and have some questions ... PBU Y-24 186-113 This relates to the patch operation of mid February. On 2/12, the lower packer was set. Are there continuing operations to set the actual patch pipe and the upper packer? PBU C-236 203-060 The information provided relates to milling out the CIBP. Perforating is also checked, but there are not details. Were perfs shot? Thanks in advance. Email is fine for any additional operational summaries. Tom Maunder, PE AOGCC ~~ MAR ~ ~ 2D0~ Maunder, Thomas E (DOA From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Friday, February 29, 2008 2:19 PM To: Maunder, Thomas E (DOA) Subject: Emailing: Y-24.pdf Attachments: Y-24. pdf L'~J Y-24.pdf (30 KB) The message is ready to be sent with the following file or link attachments: Y-24.pdf Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «Y-24 , pdf» --~~ .,., ~~,~~:,~~ • STATE OF ALASKA ~~0~ FHB '~ ©~~1Q8 ALASKA OIL AND GAS CONSERVATION COMN1~5101~,~a~~ a Ofl & Gas Gans. Commissiar~ REPORT OF SUNDRY WELL OPERATIONS Anchorane 1. Operations Abandon ~ Repair Well Q Plug Perforations ~ Stimulated Other ~ TUBING PATCH Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 186-1130 - 3. Address: P.O. Box 196612 Stratigraphic Service +~ 6. API Number: Anchorage, AK 99519-6612 50-029-21608-00-00 7. KB Elevation (ft): 9. Well Name and Number: 88.85 KB ~ PBU Y-24 ~ 8. Property Designation: 10. Field/Pool(s): , ADLO-047471 ' Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 13550 ' feet Plugs (measured) None true vertical 9207.2 - feet Junk (measured) 13432' .13434' Effective Depth measured 13487 feet true vertical 9151 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' Surface 3015' 13-3/8" 72# L-80 Surface - 3053' Surface - 2672' 5380 2670 Intermediate 13100' 9-5/8" 47# L-80 Surface - 13138' Surface - 8889' 6870 4760 Liner 681' 7" 26# L-80 12869' - 13550' 8688' - 9207' 7240 5410 Scab Liner 2629' 7" 26# L-80 3171' - 5800' 2743' - 4294' 7240 5410 Perforation depth: Measured depth: 13138' - 13364' _ _ True Vertical depth: 8889' - 9063' _ _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 12623' - 12795' 3-1/2" 9.2# L-80 SURFACE - 12488' Packers and SSSV (type and measured depth) 9-5/8"X7" BKR ZXP 3171' 9-5/8"X3-1/2" BKR S-3 12506' 9-5/8"X3-1/2" TIW HBBP-R PKR 12795' 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 Subsequent to operation: 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ' Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil "` Gas WAG GINJ ~' WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-335 Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 2/20/2008 Form 10-404 R~sed 04/2006 ~ ~~' ~~~R k~ ~ ~~a~ -~. ~rti~~ Submit Original Only • • Y-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 11/13/2007:*'`'WELL S/I ON ARRIVAL*** PULL PATCH -DRIFT FOR NEW PATCH (UPPER SECTION 25' ) ', ' RIH W/ 2.65 RELEASEABLE SPEAR BAITED W/GR PULLING TOOL. "*"CONT. ON 11-14-07*"* 11/14/2007;*"*CONT. FROM 11/13/2007*** PT. LUB :300/2500 :PULL 25' WFD SLICK STICK PATCH FROM 12,400 SLM :PULL LOWER ANCHOR ASSY FROM 12426' SLM, (LOST HALF RUBBER :ELEMENT & SPRING) 'FISH PACKER SPRING @ 12,453 SLM. MADE 2 ATTEMPTS TO FISH RUBBER '"** NOTE 1/2 OF PACKER ELEMENT LEFT IN HOLE.** '**" CONT. ON 11/15/07*** 11 /15/2007 i **'`CONT FROM 11 /14/07*"* :RUN 2.74" DRIFT FOR NEW PATCH. S/D @ 12,781 SLM. (TOP OF CEMENT :SHEATH @ 12,824' MD). NO PROBLEMS. **NEW PATCH TO BE SET @ 12,385' - 12,440' ELM"*" '**WELL S/I NOTIFY DSO*"" 2/12/2008:*"**'`***WELL SHUT IN UPON ARRIVAL***'`'`**'` 'INITIAL T/I/O = 150/0/0 PSI 'STANDBY FOR SLOP TANK FOR 2.5 AND HEATER FOR 5.5 HRS. TWO TRIPLEX'S FAILED WHILE ATTEMPTING TO PT LUBRICATOR. !o~T~ni~nTU~n~nnn i ~~nicn nnniirn ri rner_niT nom- ~nenn~ ran rrr SLICKSTICK PATCH. MAX OD = 2.72", PACKER LENGTH = 2.86', ID = 1.75" FINAL T/I/O = 0/0/0 PSI ***JOB COMPLETE""* FLUIDS PUMPED BBLS 1 diesel 1 Total .. Digital Well File Welt: Y-24 Surface Weil Y-24 Status PE IOR 300 ~~ Well Type Vertical ~~ Zone TSBG, TSAD, 47SB, 45SB PE Status Active WAG injector Finder Water Injector Status Shut-In (W8) 12 Mth ,0000 On-Time • Current Welt Bore Y_24 Twin Completions Date Drilled 07/17/1986 Tubing/Liner Last Tag Date 02/18/2007 Last Tag MD 12510 Last PL/IPROF 09/04/2006 ~~ Well Comments [Rs~i._ ,.__r] [View.All] Page 1 of 1 Fluid Picture Last Neutron Date ~~ GOC, Depth MD GOC, Depth TVD ~~ HOT Log Date ~~ HOT, Repth MD ~~~ HOT, Depth TVD I_.___.~ OWC Log Date ~~_~ oWC, depth MD ~~ OWC, Depth TVD I~ D~pi;h.„C,gnv_erter Date CommenC Type Comments 12/21/2007 Need MI cycle in support of Y-29a when tbg integrity is restored. Planned Action [ :,.. , ~~>;-] There is currently no Action data for this selected well. Operational Highlights [~`.~;_° ~•,~] L~.I~.'N All] Date Comments 02/25/2008 '.FS MIT-IA to 300fl psi passed. Well is now "Operable" and can be returned to injection. 02/12/2008 Set WFD upper patch assembly at 12,424'. 02/04/2008 Set WFD lower Pkr assemblt at 12,440' 09/04/2007 LDL finds leak at 12,420'. Pulled patch. 06/19/2007 Tbg patch set across leak from 12,385` to 12,414'. MTT-IA fails on 8/24/07. {: :;.. . help:!/digitalwel lfile.bpweb.bp.cam/PElnfo/Home/Default.aspx 2/29/2008 ALASSA OIL AID GrAS COK5ERQA'i'IOAT COM1~II55IOK Herry Subekti PE BP Exploration Alaska inc. PO Box 196612 Anchorage, AK 99519-6612 ;~~~ NOV ~ ~ 2007 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oif Pooh PBU"~=24 Sundry Number: 307-335 Dear Mr. Subekti: ~t~ ~~. Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considerecl timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~i n cerely. DATED this (~ day of November, 2007 Encl. ` STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~-~ APPLICATION FOR SUNDRY APPROVAL ~n aac ~s ~~n RECEIVED ' NQV 0 2 2007 the ~ perational shutdown Perforat 1. Type of equest: Abandon Suspend C Altercasing^ Repair well y~~!" ""~~~~.. `'~ Plug Perforations^ Stimulate ^ Time Ea1~19r~ttti~Q Tubing Patch ~` Change approved program^ Pull Tubing ^ t Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmeni^ Exploratory ^ 186-1130 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: Anchorage, AK 99519-6612 50-029-21608-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU Y-24 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-047471 88.85 KB Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13550 9207.2 13487 9151 NONE 13434' 13342' Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface 110' Surface 110' Surface 3015' 13-3/8" 72# L-80 Surface 3053' Surface 2672' 5380 2670 Intermediate 13100' 9-5/8" 47# L-80 Surface 13138' Surface 8889' 6870 4760 Liner 681' 7" 26# L-80 12869' 13550' 8688' 9207' 7240 5410 Scab Liner 2629' 7" 26# L-80 3171' 5800' 2743' 4294' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): O 13138' - 13153' 8889' - 8900' 3-1/2" 9.2# L-80 Surface - 12488' O 13262' - 13272' 8984' -9015' 3-1/2" 9.2# L-80 12484' - 12625' S 13262' - 13302' 8984' - 9015' 3-1/2" 9.3# L-80 12623' - 12795' O 13262' - 13342' 8984' - 9046' - O 13272' - 13332' 8992' - 9038' - O 13332' - 13364' 9038' -9063' - Packers and SSSV Type: 9-5/8"x3-1/2" TIW PACKER Packers and SSSV MD (ft): 12795' 9-5/8"X3-1/2" BKR S-3 12506' 9-5/8"X7" BKR ZXP PKR 3171' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/15/2007 GAS ^ PLUGGED ^ ABANDONED ^ OIL 16. Verbal Approval: Date: ~ WA GINJ ^ WINJ ^~ WDSPL ^ Commission Representative: tl~~ Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Herry Subekti Printed Name a Sube Title PE Signature Phone 564-5112 Date 11/1/2007 COMMISSION USE ONLY diti f l tif th t t C i i C '' N mber: S d it ti un ry u on ons o approva : o y a represen a ve may w ness omm ss on so a earance ^ Plug Inte grity ^ BOP Test ^ Mechanical Integrity Test ~ Location C ` ` Other: V V ~C~` CO 6~~'C~\ ~C~V~1 ~ ~ l ~ ~` ~~ >r~HC, C! V ~ ~O Subsequent Form Required: ~O APPROVED BY ~/' ~ / ~~ COMMISSION D t Approved by: a e: O M SIONER THE Form 10-403 Revised 06/2006 ~~°E-1'u I IV H L ~~ ~,I(}~t '' ~(~p% Submit in Duplicate (r1 ~ J To: C. Olsen, J. Bixby GPB Well Ops TL From: Herry Subekti, Pad Engineer DeWayne Schnorr, Wells Engineer Subject: Y-24i Tubing Patch Request PBYPDWL24-N • Date: November 01, 2007 Est. Cost: $60 M IOR: 400 BOPD 1 S Pull Patch. 2 E Run 3-1/2" Weatherford L-80 Patch Lower Packer. 3 S Run Slicksticks & Upper Packer w/ E-fire. 4 F MIT-IA 3000 psi. LLR if MIT-IA fails. (post patch) Note: Tie-in log is SLB LDL log 05/08/2007. Current Status: SI, Not Operable, TxIA Communication Last injection: 7/14/06: 4082 bwpd at 1833 psi Deviation at patch: 45 @ 12400' MD Min. ID: See WSR 06/21/2007 -difficultly petting through SSSV w/ 2.74". Also 1.75" @ 12385'-12,410' ELMD, ID of WF patch Last TD tag: Drifted to 12,700'SLM 02/15/2007 Last Downhole Ops: 09/04/2007 LDL -found leak at 12420'MD Latest H2S level: N/A WAG Injector Tie in Log: SWS LDL on 05/08/07 Job Objective The objective of this procedure is to pull a patch out of well and reset longer patch in order to restore tubing integrity and bring well back on injection. A Weatherford patch will be run because a 3-1/2" Baker patch cannot pass through the SSSV. Well History Y-24i is a WAG injector that was SI since 9/28/06 due to TxIA communication. Well was drilled in 1986 and RWO was completed in 2001 to replace the tubing and fix PC leak. Caliper indicates tubing is in great condition. This well has very good conformance to the offset producers Y-21 A, Y-29A and Y-20A. AnnComm History: > 09/04/07: LDL found leak @ 12420 w/smaller pin holes > 08/24/07: MITIA Failed post-patch, Est LLR of 1 bpm @ 2400 psi > 08/18/07: Set upper patch > 07/24/07: Set lower patch > 06/17/07: Pull WRP from 12529' SLM • > 05/08/07: LDL identifies leak at 12402' > 05/05/07: MITT Failed, est LLR~9.66 gpm @ 1000 psi > 03/30/07: CMIT-TxIA Passed to 3000 psi, MIT-T Failed, MITIA Failed > 03/09/07: PPPOT-T Passed to 5000 psi, IC Passed to 3000 psi > 02/18/07: WRP set @ 12538' MD > 02/17/07: Tbg Caliper 419 jts 0-20%, 1 jt 21 > 09/30/06: AOGCC MITIA Passed to 3000 psi > 09/28/06: T FL @ 408', IA FL @ surface > 09/10/06: Notified AOGCC of IA repressurization > 09/05/06: Bled TIO from 1430/1940/380 to 1430/410/230, IAP repressurizes to 1550 is 2 days > 07/25/06: De-watering complete If you have any questions or comments regarding this procedure, please call Jennifer Julian at (w) 564-5663, (h) 274-0929 or (c) 240-8037 or Herry Subekti at 564-5112. cc: w/a: Well File 2 s Patch Specs 3-1/2", 55' Slickstick Weatherford L-80 Patch. Note: During the first patch attempt. Although a Baker dummy patch was drifted successfully, the Baker patch got stuck ~ the SSSV and Eline had to pull out of weak point. The subsequent 2.74" dummy patch run had difficulty passing through SSSV, so a Weatherford patch turned down to 2.72" was run successfully. Patch Depth •All depths are referenced to SWS LDL 05/08/2007. Patch Setting Depths are 12385'- 12440' ELM Patch Length: 55' from element to element. Leaks are from 12402'-12433' --- just above X nipple @ 12435' ELMD. Collar Locator Summary from Eline SLB LDL log. tbg jt tbg jt tbg jt pup jt X nipple pup jt pup jt pup jt PBR assembly 12332' 32-' (tubing length) 12364' 29' 12393' 32' (Leaks C 12402' - 12433') 12425' 10' Pup Joint 12435' 1' X Nipple (ID = 2.75") 12436' 10-' Pup Joint 12446' 10-' Pup Joint 12456' 6-' Pup Joint 12462' 14' PBR Assembly Pre-Patch Slickline 1. RU SL & Pull WF Patch. 2. Drift with Weatherford 2.72" dummy patch to 12500'. Note: (3-1/2" HES X Nipple C 12435' ELMD, ID = 2.75" --- See note above about restriction) Eline --- Set Lower Packer 3. RU EL and tie into X nipple jewelry using SWS LDL 05/08/07 4. Set turned down (2.72") Lower Packer Element at 12440' ELM (just below X nipple) per manufacturer's recommendations. Slickline --- Set Slicklsticks and Upper Packer 5. RU SL & RIH with Slicksticks and Upper Packer. 6. Set turned down (2.72") Upper Packer Element with Efire ~ 12385' ELM. F (Post Patch) 7. MIT-IA to 3000 psi. LLR if MIT-IA fails. 3 • ~ WELL SERVICE REPORT WELL Y-Z4 JOB SCOPE PATCH TUBING /LINER UNIT SWCP #4 DATE 6/18/2007 DAILY WORK PULL MECHANICAL PLUG; DRIFT TUBING DAY SUPV BULLOCH COST CODE PLUS PBYPDWL24-N KEY PERSON SWCP-HENRY NIGHT SUPV FORE MIN ID 2.28 " DEPTH 12844 FT TTL SIZE 2.875 " DAILY SUMMARY ***CONT. FROM 6/19/07 WSR**** DRIFTED W/ 3.5" WFD DMY PATCH..TAGGED LINER TOP C~ 12794' SLM. NO PROBLEMS. **"WELL LEFT SHUT IN**'* LOG ENTRIES Init Tb , IA, OA -> 0 0 0 TIME COMMENT 00:01 CONT. FROM 6/17/07 WSR. CONTINUE IN HOLE W/3.5"WFD DUMMY PATCH_(2.74" OD) 00:30 SD C«~ LINER TOP @ 12794' SLM 01:05 _.._......_______ 01:15 OOH W/ DRIFT _________.____________________~...~______________ee_ ___-____~.._......____e____~..._ BEGIN RIG DOWN ___ __.___..~.._-._._____ _____ 02:45 RIG DOWN COMPLETE..WALK THROUGH W/PAD-OP 03:00 END TICKET..LEAVE LOCATION Fi nal Tb , IA, OA -> 0 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST ~ CUMUL TOTAL ~ ~~~ SCHLUMBERGER $817 $6,264 VECO $100 $1,242 WAREHOUSE $0 $10 TOTAL FIELD ESTIMATE: $917 $7,516 WELL SERVICE REPORT WELL Y-24 JOB SCOPE PATCH TUBING /LINER UNIT SWS 2158 DATE 6/19/2007 DAILY WORK PATCH TUBING /CASING DAY SUPV FLORA COST CODE PLUS PBYPDWL24-N KEY PERSON SWS-SIMONES NIGHT SUPV DOSHIER MIN ID 2.75 " DEPTH 12464 FT TTL SIZE 3.5 " DAILY SUMMARY ***** CONTINUE AWGRS FROM 19-JUN-07 ***** T/I/O/ .100/0/0 RIH WITH PATCH, SET DOWN AT SSSV AND GOT STUCK. PULLED OUT OF WEAK POINT AND RD. TOP OF FISH AT 2006' MD. RDMO ***JOB POSTPONED*** LOG ENTRIES Init Tb , IA, OA -> 100 0 0 TIME COMMENT 00:30 RIH WITH PATCH: HEAD/ERS/UPCT/FIRING HEAD/B-10/PATCH. LENGTH: 43', OD: 2.74" 01:02 ~ SET DOWN ON SSSV AND GOT STUCK, PULLED OUT OF OUR WEAKPOINT AND POOH. ___._.~________e______.________ ~ ----________.___ __.e._________ ~_r Oi:45 REACH SURFACE, CLOSE SWAB, RDMO. Final Tb , IA, OA -> 100 0 0 JOB COSTS SERV{CE COMPANY -SERVICE DAILY COST CUMUL TOTAL ~ __ BAKER OIL TOOLS WEATHERFORD`________...w.._____ _._________._.._______..___.__..____w_ __ $47,985_ .-~ ~-°°°-_--~-----~-- $337 ____ __ _ $47,985 _ M~u~ $337 WAREHOUSE $0 $10 TOTAL FIELD ESTIMATE: $49,014 $56,530 • ~ Difficultly Drifting through SSSV with 2.74" WFD DMY Drift --- 06/21/2007 WELL SERVICE REPORT WELL Y-24, JOB SCOPE PATCH TUBING /LINER UNIT SWCP 4516 DATE 6/21/2007 DAILY WORK DRIFT TUBING DAY SUPV BULLOCH COST CODE PLUS PBYPDWL24-N KEY PERSON SWCP-DELOZIER NIGHT SUPV FERGUSON MIN ID 2.28 " DEPTH 12538 FT TTL SIZE 0 " DAILY SUMMARY --______.__...._.--._.~. -_~ __e_ ._..~~...-_. _____-_-________ _-_-__..._____-_______--_-ve-___-_____ __--_-- _______-e.._-__-~. _.~..______..._~ *** CONTINUED FROM 06-20-07 WSR *** RAN 32' x 2.74" DRIFT & WAS UNABLE TO GET THROUGH SSSVN, HANGING UP @ 2042' SLM RAN 2.74" SWAGE, 3 1/2" BL-BRUSH & 2.74" WFD DMY DRIFT, HANGING UP IN SSSV NIP, ABLE TO BEAT DOWN UP THROUGH SSSVN BUT UNABLE TO PASS THROUGH SMOOTHLY *** WELL LEFT S/I "* LOG ENTRIES Init Tb , IA, OA -> 350 0 0 TIME COMMENT 00:01 WSR CONTINUED FROM 6/20/2007. 00:21 KEPT SITTING DOWN WITH 32' DRIFT AND HANGING UP @ 2,042' SLM. NEVER ABLE TO WORK TOOLS PAST TIGHT SPOT. 01:07 RIH WITH 2.74" SWEDGE (BUFFED DOWN MORE FROM EARLIER RUN), 3 1/2" BLB, AND 2.74" WEATHERFORD DRIFT. 03:50 TOOLS GETTING STUCK 02,022' SLM. HAVE TO HIT APPROX. 6-8 HARD LICKS DOWN TO GET THROUGH AND SAME FOR GETTING BACK UP THROUGH TIGHT SPOT. WORKED TOOLS FOR AWHILE AND IT'S NOT GETTING ANY BETTER. SIBD. 04:20 RIH WITH SAME SETUP. BUFFED SWAGE DOWN SOME MORE TO 2.739". 05:12 ABLE TO WORK PAST TIGHT SPOT THE FIRST TIME FAIRLY EASY AND THEN PROGRESIVLY KEPT GETTING HARDER TO PAST THROUGH. SIBD. 05:20 SWEDGE HAS REAL BAD METAL SCORE MARKS DOW N THE SIDES. CALL BP REP. HE W ILL CALL BACK. 07:50 -.._.~_. 07:59 CO-MAN CALLS BACK, WANTS TO RD ....-_______.__.._._...._-____~..._e__r____._--.__~_---__-__-___..~.d~- _e__~ ~ ~._. ~__...__m~~..._...._~_______~._..._..---_._~..____-_-_~...-e--_. BEGIN RD 08:24 BEGIN STACKING EXTRA RISER IN WELLHOUSE 10:00 CREW C/O TO NOSKO 10:59 RD COMPLETE, WELL NORMALLED UP, PAD-OP NOTIFIED, TRAVEL TO Z-PAD F inal Tb , IA, OA -> 260 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST _ CUMUL TOTAL SCHLUMBERGER $4,221 $17,007 VECO $200 - ~-- - $2,254_ ~-~ WEATHERFORD --- -~~~~ ~- $135 $472 BAKER OIL TOOLS $0 $47,985 WAREHOUSE $0 $10 TOTAL FIELD ESTIMATE: $4,556 $67,728 FLUID SUMMARY N/A r WELL SERVICE REPORT WELL Y-24 JOB SCOPE PATCH TUBING /LINER UNIT SWS 2158 DATE 7/24/2007 DAILY WORK PATCH TUBING /CASING DAY SUPV LYNCH COST CODE PLUS PBYPDWL24-N KEY PERSON SWS-DECKERT NIGHT SUPV BOYLES MIN ID 2.75 " DEPTH 2038 FT TTL SIZE 3.5 " DAILY SUMMARY INITIAL WHP 300/0/0 SET WFD ER PACKER W/WLEG, ME 12413', TOP OF PATCH 12410..7', BOTTOM PATCH 12413.5', WITH 1.79" ID. CORRELATED TO SWS LDL DATED 8-MAY-07 DOWN 40 FPM ANOMOLY PASS. FINAL WHP 300!010 ""Job Com lete""~ LOG ENTRIES Init Tb , IA, OA -> 300 0 0 TIME COMMENT 10:00 MIRU, PJSM, SIMOPS __ _.. - ~~~~~ ~ ~ 11:00 _ _~___ _~_ - ~__ PT LUB 300 LP 3000 HP .. _ __ _ 11:30 _ 20' X 2 72" MOD, RIH WITH HEAD/ERS SUB/WT BAR/CCUSECURE/BST 2.70"/LOWER PATCH WFD 2.72', TOOL WT 265# 14:00 CORRELATE TO SWS LDL DATED 8-MAY-07, ANOMOLY DOWN PASS C«~40 FPM. 14:21 POSITION CCL 12403.7' WITH ME @12413', FIRED WITH GOOD SURFACE INDICATION, RIH TAG PUH-POOH. TOP OF PATCH 12410..7', BOTTOM PATCH 12413.5', WITH 1.79" ID_. 15:50 SWAB SHUT, BLEED START RD _ .___._ ___, _~____ 17:00 _ RDMO Fi nal Tb , IA, OA -> 300 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST ~~~ ~ CUMUL TOTAL _ _ ~ ORBIS $1,000 W ~ $1,000 SCHLUMBERGER tl $12,484 $2_9,491 ~~~~ ~ _ VECO $692 $2,946 W EATHERFORD $6,793 $7,265 BAKER OIL TOOLS $0 $47,985 WAREHOUSE $0 $10 TOTAL FIELD ESTIMATE: $20,969 $88,697 FLUID S_UMMARY_ 1 BBL DIESEL FOR PT ~._____.__._______e_e__.___.__.__._ _ - __ __._ ____ ~_~___... _ • Setting Upper Packer with Slicksticks with E-fire --- 08/18/2007 WELL SERVICE REPORT WELL Y-24 JOB SCOPE PATCH TUBING /LINER UNIT SWCP 4515 DATE 8/18/2007 DAILY WORK PATCH TUBING /CASING DAY SUPV BULLOCH COST CODE PLUS PBYPDWL24-N KEY PERSON SWCP-NEMEC NIGHT SUPV JONES MIN ID 0" DEPTH OFT TTL SIZE 0" DAILY SUMMARY "'* WELL SHUT IN ON ARRIVAL'' RAN WEATHERFORD 25' SLICKSTICK TOP PATCH ASSY, (MAX O.D.2.72,) (I.D.1.75 ) LATCHED INTO BOTTOM WFD PACKER Q 12,459 SLM. SET UPPER SECTION OF PATCH WJ E-FIRE.RDMO. NOTE: DISCREPANCY BETWEEN E-LINE DEPTHS & SLICKLINE DEPTHS. TOP OF BOTTOM PACKER SET ON E-LINE @ 12,410' ELMD. 12,459' SLM TOP OF PATCH @ 12,434' SLM. 12,385' ELMD. '** LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER. """'' LOG ENTRIES Init Tb , IA, OA -> 250 0 0 TIME COMMENT ._...~..____e_..~. _~ ~_~_____ 06:00 ________.-..-.. __e.__..__________.~._~.~.~.._..______e_...~__~._.~_ ___._.~_e--__~.~___.___ "" MOVE TO Y-24 "' 07:20 CREW C/O TO VELA, MEET Q G-PAD,DRIVE REST OF EQUIP. 07:45 CALLED PAD OPER,LEAVE LOC. 08:30 ARRIVED ON LOC,INSPECT AREA,MOVE EQUIP. OUT OF WAY. _ _~_ 08:50 SPOT EQUIP. _ 09:10 TGSM.ON PICKING UP EXTRA RISER. 09:30 BEGIN RIG UPTAKE CONTROL OF SSV, CYCLED,ALL GOOD. 10:10 _._ _~~~..... 11:00 PICK UP EXTRA RISER. ..._._..______~_____.r._._-__~~--~~_____.__~__..___~~~-~__...__ _ _.._ ~__________._........~~~~~.-_.-.___.._......_______________..~ _._.__.._________.._.......~......_.~. w_.....__._______e ALL EQUIP. READY, GET WFD SPOTTED, PICKUP SLICKSTICK,SET INSIDE RISER. 11:45 ALL READY, LUB UP IN THE AIR, WAIT ON E-FIRE REP TO PROGRAM TOOL. 12:30 WFD REP,SLB E-FIRE REP IN MANLIFT, MAKING UP TOOLS AND LUBRICATOR. 13:15 ___~~e~~. 13:29 TEST EQUIP. 300-LOW,2000-HIGH,GOOD TEST _ _ _ _ __ _ ___ e.___~_____~__.._e~_~~___._____..._~.__~--e-_____._.__~. _ .._...._.....__~.._._._w~.a_e RIH W/ 8` i 718 STEM, LSS, W/ E-FIRE TOOLS, (WEATHERFORD SLICKSTICK PACKER 25'. WFD SETTING TOOLS 7' & E-FIRE TOOLS 8'. OAL 40'~~ MAX O.D. 272~~I.D 1.75") _~~________~~~_~~~ ..._ __ 15:15 Q 11,000` SLM. STOP AND START AIRMING SEQUENCE. 15:30 DOWN TO 12,300 SLM. START FIRING SEQUENCE, 16:07 SAT DOWN C«~ 12,459 SLM. HIT DOWN TWICE,PICKED UP TO 1600#,CAME FREE, HIT DOWN 3 TIMES, PULLED UP 1700#,GOOD PULL TEST, AS PER WEATHERFORD REP, SLACK OFF,TO 850#,WAIT FOR TOOL TO FIRE. 16:20 TOOL DID NOT FIRE, RESET TOOL. 16:35 RUN FIRING SEQUENCE AGAIN, NO LUCK,DID NOT FIRE.RESET TOOL. 16:45 ENCE AND FIRING AGAIN,WHILE TOOL IS LATCHED IN. _ R UN ARMING SE QU 17:00 _ _ _ TOOL FIRED, LOST 150#, SAT BACK DOWN, TO 12,459 SLM.PULLED OFF CLEAN, PULLED UP TO 12,000 17:13 C~ DEPTH, WAIT FOR DISARMING SEQUENCE. 17:35 DISARMING COMPLETE,POOH 18:20 OOH W/TOOLS W/ E-FIRE TOOL,GOOD SET. ______ ._____ _ __.. e...____ _ __.__._-.-_.-._-- 18:30 _ _ _ _ BEGIN RIG DOWN AS PER BP REP. 19:23 CREW C/O TO NEMEC, LAY DOWN 15' RISERS, CONTINUE W/ RIG DOWN 19:59 "`* RIG DOW N COMPLETE, SSV BACK TO PANEL TREE CAP ON & TESTED F inal Tb , IA, OA -> 240 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST ~......_~..~.. CUMUL TOTAL ..._..~~..~...._ ORBIS $1,300 $2,300 ~ SCHLUMBERGER $13,773 $43,264 WEATHERFORD $6,720 $13,985 _ BAKER OIL TOOLS _ ~_ $0 $47,985 VECO $0 $2,946 TOTAL FIELD ESTIMATE: $23,866 $112,563 FLUID SUMMARY 1 BBLS DIESEL FOR P.T. 7 • 3 ~ .,,L ,~,,, :dELLHE~~~-~ r E ~,,,, "IJi+' ,i~ ~ Po h6 ELE: ~ ~' E~F E! ~. ._,~ D-,~ ~ ~' .s - `CCiR3C~JCTGR ts(}' f,~- „ , ~, ~ ~- 72tr l-St3, fit=22..347" 305x' I' i t r ~rtnini~~Ert It3 = 2.28" ~ 12844" f:EPvlE?~IT SHEA"~H 1,~151DE TBG ~R~1VI' PKR SQZC)F (15;'19f~6; ivIILLED t7LNT B'~ ~ILI/Lt ~'UBINU • .~®,.y,.-~r- .. ° ~ ,°i ~ .SRC+tC 2._ i i ~ C-ASTTC ~ ,. 4 - . C ,. 2127' ;4 ~a'< HEM XpES SS~u'..., _ --~{ 3171:' h-I~~t~ ,~ ; ,, ~~c~ ~x>7 ~~s~+~s~r~ lr~.- ~s.~~ 123$5`-12A13, T~,.-'z ~~sC~tSE''. t[)- ~.7~r 12166' ~---: ~ :- ~.~~„ 12492' Eil~- . ~..I[5-2<yr, 12506' _ ~, .. - ---~~ 1:2566' ~~~~ t f_~ X`1 ,r '. iG~ 2.3x4.' f~~I€,LE ~ )1 ti 1:261.$' ~I i6 ~ ~,' :, ~F3f-1Cti.;- 1274' ~. t~'IS ~ i ILA 12i?~5' I '~ I ~E " 1?82~f' s- x ` .. irr - 12i> 14' `T;?F~ VF t:Jsnl SN"rr+ i;ri N~ t ~ ~, IU ~ 2.28" 1 ~6C1` 2-7:'8" ~715:~ NIF ICJ=2.323" 12#393' ~-r;~° ta-ro5 ~ r,~l ~ r. T~ 2-7;8" TF1G, fi.4# L "~. ""' „ • < ~7, ~- 2.441 ~ 1:2327' FERFfrs; ~ 'AI r ~~ti~~~r ~.-. -t,r,c APl ,~ ,E ~~.,1 E~~ . . L'G ~:."F P:1-~~ 'r. L. ~~ ~ "y:: Rte`"E 2 4 ~ :~ z, F?BTLS L , " 161' H;., FAt~F ~ .- ~..J 7 FISH - 1': r F E_~ 'tti" , F =I ~E "F '. - x., ~B~ ~©k,~AdENlE;a "E f~El~Sf ~t r.T,'c'.~ F J'-%'°iC7EB~ ~`lJNCE t7f~lGfi~lAL --;,'PL[=i`!C'1€~7 3i F' ~`- i--Cr ~F?~ ','~'< ___ ' 2! 1: _ F?'4"JC3 ,i.~V ~n:L~:~ERfr 'ri 'rs "Iiu: ~- 6i't rC _?RRZ-ii_', _ iLk~ SEE' f ~:r+ i, ~~ tJ~: _ ~z ~ti~-(-° CC?RE:E ";~:-.':- 5E~34< r a ~N "'.:~E ' ~ J ;FJI.. mw.L >;`F C~1h.GF~ ._~ I^_FE7.L=:f' ,~°'3'8 flf>33 ~ L,LL - , ~~~ F `~H ~F* ~{sktra'kiort Ila.i~~tt ~j g • Y-24i SLB LDL (05/08/2007) Use this Loq for all Depth References. The Well Drawing is deep by ~31 ft. i~K Ar N2385' at 12440') OLD Patch (25') 12388' - 12413' - X Nipple @ 12435' PBR Assembly @ 12462' x_ 9 • .~_ ~. 74.~E)Stdti; 5~11~CM1i~i~'r' .~ '.IZIf~ r ~ NJLi,L ~ II(.'r'YC J1~I 1l• i:,a Y' 2d f-~:1'St tt'e i. Zt;li1 432,JT9 {)W HACK =tl.ii J t~ kAty :' i ?ho ti Tt, Eif 1'3175.8fi P7 CAN R,2CI~ t 3?ti,~', ~ T F2tLN p'!'~D,1 Do.scrr~fiivr' t-~clu~e~... SIZE, 7Y4"E_ COh?JEC'~L'.,.p'h9 {J"~"~' ~-a')= ,...- t I[7 - f.31`7 i ENi 1 H _ _ TC~Y ~ >3~ ThiRt flit (t 1 ir,1 1 1 ! ...._ ~ . . 3§U ..... _ . .. 9 : 23~ ... fLFrt i~J r2~16~ _ .. _ _ d...® _. ,. . _ drr £- n~ ~ 1 rt kJLU a~~ _... ~ ., _, ~ ..,937 "H 3 9~ ~__. __ _ :fJ .:, .. ~._ . f."5~2 4~ '2n,~2 ~ __ . ~ . -. n . ~t~H „! ~+* 1 t.~ 1 ." i ni ~ NSl•T i 2 aZ, ~ '~ 9b . 9.EiB 12542.55 t2`72d,~ - - ,. ~., .~._.,~ h JJ la ~' r m ....-{~-~- .~ 2.751 .", +lrs 1 l:f 125E1 42 f2`tt~7 5" tJl dG7"hJ 7 "' L tl 1 r __ - _.._ - 2.9~ 39L _ F~ 7 _~ _ ~ .- .. 12u51 85 "25f Al M .. ~ ...~ _ - - I k.l.l I-UI, , 1'1~.' I li~i',~ 2ft.S 39iti J)-04,~ ~_ c- ..~ Y2a211.L . w.,~.~ 1'~55sb`~ ' i ~, __......_ ~ llf ~:d I!T t v ~ ;.,~ I ?~, IJ' ~~ 1 _...-,.~e ~~ =m~ ~~W___~_ _~. `? '~1'~ ......~ .'1 9Cr l,~ 81j ~ .~..._ t .e,m. tw511 3f4 . n,, J i2: ~ .--. .~;(i.,t N5~ 1r,~:.k:,ta"PJL~;1~ ~ . ~ 2.93e' ~~_ 3-9~ __ 1.Sii3 _ , _..., e. #2S~9d ®_ e, 125f'1.3.~ . . e w ~~ r~ ~:£S :,-3 ~'N~.r( r;: 2. 95'~S.!? . 8.25 4 64 725174.8 _ „_ _ `150y_~t'_: ~J c~ Iv.~, l ,u?: x 4 P ~ T r fi,j - --- . __ .~ x:.~l 1 _.:,( H_~~.~ S 1 ..:~t 7FIf'' di ter r'E1}~ t _.~ _ _ 2.57 ~f.~~ 79~1~, .t4Es 31 ___..__ 1 tl~ i7ti 1l ~t _ ... . 7233 G§ 7a5Jt l~ 724if7 ~4 7 2487 i4 _ ' 2604 8 f2h~7;St)-.. 125(11 s , r 124{J] 7A ~ _ .W ~_ t r C1 lv rH S J ~ ~eeF3 ~ r -ri 1 J ~ ^' 1 ~ i ~ t2~d3 ~A ~ 32407 t4 ~ _ E ~ 12467 T4 1e'~1u7.74 d n.i..K...,.-.P€E3L ,' 1 H~- IP..I ? ~. i C.`.•.,) ~ ~ ~'3 [ 2.35 '.937a A rg ~ 8t; 37 1 9& s 124f47 37 ~ 424E3S 41 ~ 124ii7 74 ~ 12487 3~ _. -__._... __-_~~_._~.____, . __ .____, -.._ __.___, ruhrr,~ : ~r.ls~ ~ ____ _._ :~-~aa' ~ « ~ ~r7 - ' -~~~ r «.., ~ rar --~ ~_, ~k ~:~4t~ ~.~ .~.. _. _ _ _.._, ~ 1z4~1, 4a __ ~ _4r _ ~- _ _.__ ~ ._~. a~~ F .I~ il.-tai F{.x iJGk r P~.rE: f f4lt~il _ . _ ..... ~ . 2.992 ...~. 1.rTt{ ~ ~.~. ~ P. ..~ fl 4 4 ,.~.,-.,,...,., W ._-, . i _- 1247(},2.4 _____ m~~ t?473.54 a Yj[7 s-11RlL-Y'i1J NS~T N'`eX % GilX f~fPe~4 ° 2.$92' 3.9Br 9 57 ~ 1246U.ti4 t24Til.27 ' 5" x 7 T :" };F`~ x Pd?i'P[ {,` HF' rH„ rT ~ 2.7'9; J,95 t.bti 120.59.84 f?16*~.~4 ~ T~IETIRI~ 'E_r';r,_ H d t~l-;C:13 I 2,4Cf2~ a.'~8 9,7~ 12A-SB:B~ 1?~46*e3_S4 ~- iii I1 l-~f + 1 ' Cl a 1 fl1Nl i i I ~ H~ is 44 I ~ rli7(lll 91,i"t ft)XdJ '~~f! 'iFityi __ ~ _.y. ,SBCF. :?IMa ;99h 3.911 -~-y ((1433 3i A25 --..__~ ~ _____ 21r1~'S+s 20p771 ,.r. 1 4A98t 2£11b56 i a ' r Hf-S Y N ~r r A rt F-r 1 P° C~ Fis' ~>S'1 ( 2.7`5 .1.7415 3 3 ? 1 200k U3 .E~r87 3t C~ FI , st ~'t la ,T H r FC' ) ~'1 ., L G~ d 1 1' P:SC.T IllbltvC, t., 1 ~ :, ti, Z n 'i,. .r, i ~ ... 2<4yZ 2.$67 3 59 3 9n 9 5ti 19,1.0+6 1 a94 53 73.53 ?C~4 0$ ~.~~ 1594 ;,ate ~.._ ..~. - ~ '>1~,41:r-F2 Nt,i-+~, . -°~ -~ _s. 28G7 . . .~ 31tFi ~ ~ - - - 4d 1:~ _____- 5A 74 . j 71.53 ...- . . ..._._...~ . ~£l~l 1-J :i1z 1i1-.~1-T13Ji.''•,U '~T rr gf•15 _. . n,... ,.. 2.1{ii,7 ,. 3'J fi ., 2 {7J 3 _~_ ?fii T7 ~ _..-.r~.e... ,+iFt 7~i X yl-~ 1„a ^i..4f;t PIlJ e •i 7 ~J:;.f;l xxitx~_. .._ ~?.Afr7 .. ........... ~~ ... _ ...v1 Sit} .. _._ ..2481 .,. ..........~ 2~.,.7~1 . _ 4 ~, ~° S7`,t;T PUs~ 3.95 t a,5~, . . m,...~,-. 1_a(} ;[3 SI ___r -~...R.<... __ ._~ _ 2a.a1 T~BtNi;, HA?JC3~fd ;3.~5 4 5' 81 - ?2.70 ~ 23.51 . _ [7,.Y~~ty 80 F.K,!3 f 22-7f1 .. 22,70 - ._w_.. . .~__ ~._. _ ..~ r., .....,, .w . ~ -... ~ . _ - ._..... ~ ~ -. ~ , ..,-- ~ .._- ~. -,~ _.a. S -- -- Correction --- From the PDS ~ _ _ - +-~ ._ _ li h l 338 C '- a per survey t ere are on y s _ ~ _ R full joints betvueen the SSSVN ~ - _ . _ _ h PBR d h X Ni l b -- ~ ove t an t pp e a e . e ,- .. ~w,_ w.y ---- _ - --- _ ~ ~ _; ----~ -'~ ~.. ..~~ ,~~~ _ _ _ ~. -- __ _ ~ ~.~ ~ ~ ~__~__~ ~ m.J f ~ ._.__~.w_ 1 , -- T --_. _d--~~ _ _ -- _ - - _- s ..~._. ~ , _ _~. A -. 10 ii ~. t li 111 _; r~ t. ......... ......... ...... .~'-"..... ...... .. t _ ~ _ ~_ ~~~: .. ,«=t t .. _ , ~,~,. ~ . ,r:. ~~ f>, .. , ,. • ii i~ ' . Bali .. . ir' i;z~l~t : {`r, ~ :•, . ,l ! 'ai+. "~ a aE r E~i` i. i.i.. Fig" I ( ' fit ' ;i 1' , I ... . ~ ... Fro i t :~ i •... I I ~1 1 fJ { I ~ i I .~ ~~ m il~ i ~. ~ y ~ .Il ~ il ~. ,. I p ~ .. ' e ~~ ~ _.... I ~ ~ E 'r :. t ., [ ».~t • f i i r r 'a4, j i ; ~~.; ~ I ~ ~_.. ~ ~ ~ - .. ~ _ ,u ~,, ~ . _ ~ . -- - _ _ _ _ - ~ - - _ _ i _. i = 3 ~ i ~ - ~ ,~ 1 I . ._.".. r a ;~ V `, % .... _ _ r ,~ ~ i t i' ` f ~ 1 1i.r ~ .. _._ ~ f i - 'W __ ~__ ~ ~ ~ ~ e _ _.. ........ 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J .._~ . _...,.,...„_._ _ _ . _,_ ,,..... __ . k - _. -.. _., _..... _.. _.. t .. _ I I ttt'~~~' f ~ ~ ~ ~ . ~ .'~ ... .. *.~~ _ I t" ~1 . I ~ i a ~ I " , ~ _ 1 .. ~" ~ I : ~ I ' I _ ~ - - _ _. ~ " l ~ ~ ~ ~ € ~. ~ G 1 ~ , j ~ I . .i; ~ ~- _ I r : ~ ~ E ~ ~ ~ E - ~ ~ - , . - '... t} 1 , j - - E I 1 I. ~ ~ I ~ i ( 1 , ,,. ~ ~ 1 ,,. ~f ,. i : ~ , ( f I ~ ~ ~ .. ~ I i . ... . ... .. .. ~ .. f ._.. ~ ( I . I .: ' I r i Ali I" i '-~ Rre `~ ~ 1 I I 1 I` ~ _. ~ .~,, ~ ~. r 3'f. t ~ ~ ~~ ~ 1 .~tE u - _. .., ~ r a ~. '- k ~ r i l ~ r ~ ~ ~ [ ~ _._ - _.._ .. r_. ~ ~ ~ ~ ... - _...., ~ i i .. ~ ... '~ ~ ~; . ., .... ,.... ..... __ ,_. ,___ . i ,. ,. . ,. ,.. ._ .. ,.- ii ~ i i ~ ., . i =-. [ . t ~ i t ~ e ~ I r ~~ ( ." I ~ t ' 3.t r x ".I . .~ ; . ~ ~ 1 ~ e ~ 1 i . ~ ~ ~ 1 _ d r } ~ i t ~ i~ I,- °i' a I' i ~ ,' ~ .. a~ ~ ~ ~ . r ~ f r r. _. ~ ~, , ~'~,` -• :1 i ,,n _ib° >:l_, 1'~a;~W 13 • .~ ~~, , ~ ~ ~_`_ ,._ , i ,, i~ u~ r ~ f,. ,~i~ I. .:.I. r. . < <ai ~i.a .7_ _ ? .. ~. .. .._„ ':t~.' ('._.. tar,", i i~:E::. i ;-, u - I ,.. ~ ~ t is r ~ ~~ - r m e ,~»~..... >- ', a.. ~~ ''I ~~.r~t % il;?. ~.~ ~..'. ~. _. i wa ~~...~. u._a kA i 1 3 1 f I f ','Ji. F n tt 1 i .~ . 14 st j i ~. n 'i; i i ~i: - u. • ~ 9i ... ~~~; ~~ ~~ . ra~;_ :~5 ~ .' ~ '.~_ -i " , . ilia ~ ~ ~ _ ,. ,. ~71~ t_.7~~~ ~~± ~`l ~} 4 4M~ ~!~ ii:lj~`_I~ _~ ~~11f. 1f ~_CI'~. Pr] Iii :?~. ~e~ • • • ~ 1`.:.. ..;111'. .,~t ~. ..., ~ ~ f 1! I .a ~ t. :!1 t . I. ~I ~ G~ j 1 j € 3€ i I ~ 17 ''~,:.E ~~, t:~,~ . _..~ .,:~u ~, '.p_~Y,-. ~. ~4 ifi G~~:.3",i i(1V €s~" Ii. ..{. ,il tii.'-~a ,t; ~ ,,.- ,: ~ :~ s~i L" ~ ~~.. ~u ~iF'n° t ria.. ~. .I-. ~: E;~t., i ~ ` ~.. ~' t ~"' f _ - ~""~~~ °X" ~ 4`~+~ lit t~ ~ ,r ` IS osrzaro7 SChl~mber~ge~ N0.4440 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambeii Street, Suite a0o f(~t~! ~?~y Alaska Oil 8a Gas Cons Comm Anchorage, AK 99503-2838'°~,~'°, ~'~ ~t,1 V ~ Lt1~~ Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 700 Anchorage, AK 99501 Field: Prudhoe Bay WPit .Inh $ t nn flncrrin4inn n~fn RI Rnlnr en 15-39A 11661174 MEMORY PROD PROFILE 09123/07 W-42 11745235 MEM SBHPSITEMP 09/14/07 Z-07A N/A SBHP SURVEY 09/14/07 1 A-04 11594519 SBHP SURVEY a - 08/26/07 1 Y-24 11630499 LDL 09/04107 1 L5-28A 11855810 PRODUCTION PROFILE - (~ 08/31!07 1 X-33 11849931 SBHP SURVEY S - t~L 08/31/07 1 E-14A 11686784 LDL ~~ ~ 09123/07 1 01-15A 11855509 DDL ~ - a j (~ 09/22107 1 D-21 11626119 PRODUCTION PROFILE ~,~ - ~ 09/11/07 1 K-07D 11745234 MEM PROD PROFILE C _ 09/06/07 1 11-32 11630498 PRODUCTION PROFILE j ~ - 09/03/07 1 L-01 11745233 MEM LDL a V ~- ~ 09104107 1 07-30A 11661168 MEM STP & CORRELATION - 08/28/07 1 Z-28 11630500 INJECTION PROFILE ZC 09/05/07 1 Z-16 N/A SBHPSIJEWELRY j 09113/07 1 14-26 11676959 LDL ..-/j 09109/07 1 04-02A 11630504 LDL !( - 09/11/07 1 14-37 11695075 LDL - 09/13/07 1 3-35/L-36 11630502 PRODUCTION PROFILE 09109/07 1 F'LCASt AI+r~NVVVLtUIat Ktl;t1Y 1 tSY '{liN{NG ANUJ3fG1 VIdN{NFa'l'~Nt tiUYY tAITFI iU: BP Exploration (Alaska) Ina ' Petrotechnical Data Center LR2-1 900 E. Benson Btvd. Anchorage, Alaska 99508 6 "~'~~- r~ ~~ ~~~"eft d Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~ Anchorage, AK 99503-28 ATTN: Beth Received by: • • REC~ 'VE:i STATE OF ALASKA I ~I. AUG 0 a.«IOAW'AOILANDGASCONSERVATIONCOM SION j:J<r(l5 l\iaska Oil & B~~(9ªJ;s9F SUNDRY WELL OPERATIONS 1. Operations Aband0I]¡Ji:GhDr¡;¡nn Repair Well 0 Plug Perforations D Stimulate D Other D tubing patch <' Performed: Alter Casing D " Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Ope rat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 186-1130 - 3. Address: P.O. Box 196612 Stratigraphic Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21608-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 88.85 KB PBU Y-24 ~ 8. Property Designation: 10. Field/Pool(s): ADLO-047471 11. Present Well Condition Summary: Prudhoe Field/ Prudhoe Pool ~ 1'""1"", Total Depth measured true vertical 13550 r 9207.2 / feet feet Plugs (measured) None Junk (measured) 13434' 13342' Effective Depth measured 13487 feet true vertical 9151 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' Surface 3015' 13-3/8" 72# L-80 Surface - 3053' Surface - 2670' 5380 2670 Intermediate 13100' 9-5/8" 47# L-80 Surface - 13138' Surface - 8889' 6870 4760 Liner 681' 7" 26# L-80 12869' - 13550' 8688' - 9207' 7240 5410 Scab Liner 2629' 7" 26# L-80 3171' 5800' 2743' - 4294' 7240 5410 Perforation depth: Measured depth: 13138' - 13364' True Vertical depth: 8889' - 9063' - - Packers and SSSV (type and measured depth) 3-1/2" 9.3# L-80 3-1/2" 9.2# L-80 3-1/2" 9.2# L-80 9-5/8" TIW 9-5/8" BAKER S3 7" SCAB LINER BAKERR ZXP o 12623' - 12795' Surface - 12488' 12484' - 12625' 12795' 12510' 3171' o Tubing: (size, grade, and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED AUG 1 6 Z007 Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl Shut-in Shut-in Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG Tubing pressure o o Service p x Contact Gary Preble WINJ WDSPL 17. I hereby certify that the foredoing is true and correct to the best of my knowledge. Title Data Management Engineer Signature Phone 564-4944 Date 7/30/2007 Form 10-404 Revised 04/2006 OR1G\NAL RBDMS BFL AUG 152007 Submit Original Only . . Y-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/24/2007 INITIAL WHP 300/0/0 SET WFD ER PACKER W/WLEG, ME 12413', TOP OF PATCH 12410..7', BOTTOM PATCH 12413.5', WITH 1.79" ID. CORRELATED TO SWS LDL DATED 8-MAY-07 DOWN 40 FPM ANOMaLY PASS. FINAL WHP 300/0/0 *** Job Complete*** FLUIDS PUMPED BBLS I 1 DI ESEL 1 TOTAL Scblumbergep NO. 4290 1 zom Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN; Beth Commi$~iQn Field: Prudhoe Bay Well Job# Log DescriDtion Date BL Color CD L5-23 11733320 PRODUCTION PROFILE 04/30/07 1 W-38A 11660532 MEM PROD PROFILE 05/02/07 1 Z-38 11660534 MEM PROD PROFILE 05/05/07 1 17-22 11745213 LDL 04/29/07 1 W-19A 11628772 MEM PROD PROFILE 05/07/07 1 Y-24 11630477 LDL 05/08/07 1 16-08A 11686747 LDL OS/20/07 1 G-05 11773110 LDL 05/13/07 1 16-03 11686743 LDL 05/11/07 1 14-07 11637334 PRODUCTION PROFILE 05/08/07 1 V-03 11628770 MEM LDL 04/30/07 1 MPF-91 11628759 MEM TEMP SURVEY 03/09/07 1 MPF-89 11628758 MEM TEMP SURVEY 03/08/07 1 MPS-10A 11638630 INJECTION PROFILE 05/07/07 1 B-34 11594500 INJECTION PROFILE OS/22/07 1 04-10 11594498 LDL 05/19/07 1 . B-07 11657125 PRODUCTION PROFILE 05/11/07 1 H-24 11745216 PPROF/GLS 05/02/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 C-28A N/A LDL 05/09/07 1 M-07 11630476 LDL 05/07/07 1 P1-14 11745214 INJECTION PROFILE 04/30/07 1 P1-16 11594494 INJECTION PROFILE 05/01/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 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 ATTN; Beth ~ Received by: r~ -- 5tANNED JUN 2 1 2007 Date Delivered: CJ":rL J~fn -lt3 ....,. d~ 06/07/07 . . . ~lr~lrŒ (ID~ ~~~~æ~ . A"~SIi& OILAlWD GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Herry Subekti PE BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 ~ q,b- 113 Re: Prudhoe Bay, Prudhoe Bay Oil Pool, PBU Y-24 Sundry Number: 307 -190 s~ JUN 1 1 2007 Dear Mr. Subekti Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of June, 2007 Enc!. 1. Type of Request: 07::1' G/¡ ~ . STATE OF ALASKA ¿-?-ð? ~OILANDGASCONSERVATIONCOMM N Á RECEIVED APPLICATION FOR SUNDRY APPROVAL I~ ,JUN 0 7 ?007 20 AAC 25.280 Operational shutdown Perforate wa~Ïa Other Plug Perforations D Stimulate D Time Extension qllb~9~ß~¡Çons. ammissi¡ Perforate New Pool D Re-enter Suspended Well D .I\nchorage 4. Current Well Class: 5. Permit to Drill Number: Development 0 Exploratory 0 186-1130 Stratigraphic 0 Abandon Alter casing D Change approved program D 2. Operator Name: Suspend Repair well 0 Pull Tubing D 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes D 9. Property Designation: 11. Total Depth MD (ft): 13550 Casing Conductor Surface Intermediate Liner Scab Liner Perforation Depth MD (ft): 13138' - 13364' Packers and SSSV Type: 12. Attachments: Service ø 6. API Number: 50-029-21608-00-00 8. Well Name and Number: PBU Y-24 No D 10. KB Elevation (ft): 11. Field/Pools(s): 88.85 KB Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY ADLO-047471 Total Depth TVD (ft): 9207 Effective Depth MD (ft): Effective Depth TVD (ft): 13487 9151 Plugs (measured): NONE Junk (measured): 13434' 13342' Collapse Length Size MD TVD 110' 20" Surface 110' Surface 3015' 13-3/8" 72# L-80 Surface 3053' Surface 13100' 9-5/8" 47# L-80 Surface 13138' Surface 681' 7" 26# L-80 12869' 13550' 8688' 2629' 7" 26# L-80 3171' 5800' 2743' Perforation Depth TVD (ft): 8889' - 9063' Burst 110' 2672' 8889' 9207' 4294' 5380 6870 7240 7240 2670 4760 5410 5410 Tubing Size: 3-1/2" 9.2# 3-1/2" 9.2# 3-1/2" 9.3# Packers and SSSV MD (ft): Tubing Grade: L-80 L-80 L-80 Tubing MD (ft): Surface - 12488' 12484' - 12625' 12623' - 12795' 9-5/8" TIW PACKER 9-5/8" BAKER S-3 7" SCAB LINER BAKER ZXP 12795' 12510' 3171' o 0 13. Well Class after proposed work: Exploratory 0 Development 0 Descriptive Summary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Service ø Commencing Operations: 16. Verbal Approval: Commission Representative: 6/13/2007 Date: 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 WAG 0" GINJ 0 WINJ ~ WDSPL 0 Prepared by I..:>i:try r-rtwle 564-4944 Printed Name Signature Conditions of approval: Plug Integrity D ä ,90l'fect to the best of my knowledge. Title Phone 564-5112 COMMISSION USE ONLY Contact Herry Subekti PE Date 5/30/2007 Sundry Number: BOP Test D Mechanical Integrity Test '~ Location Clearance D " Other: ~l' \. c.o G'-\ ,0 \ <C~,3\. \>~"" \>CL ,'dO ~~c... 'ðS"". d-~ ~ Subsequent Form Required: "'-\C)~ Approved by: Form 1 0-403 Revised 06/2006 Date: 6-% /() ,JUN 0 8 2007 APPROVED BY THE COMMISSION Submit in Duplicate ö . . To: C. Olsen, J. Bixby GPB Well Ops TL Date: June 5, 2007 From: DeWayne Schnorr, Wells Engineer Est. Cost: $Æ!.M lOR: 400 BOPD Subject: Y-24i Tubinq Patch Request PBYPDWL24-N Please perform the following procedure(s): Step Type Procedure 1 S Pull WRP. Drift w/ 3-1/2" dummy patch. 2 E Run 3-1/2" L-80 Baker Patch. 3 F MIT-IA 2400 psi. LLR'if MIT-IA fails. Current Status: Last injection: Deviation at patch: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S level: Tie in Log: SI, WRP set at 12538' MD 02/18/07 7/14/06: 4082 BWIPD at 1833# WHP 45 @ 12400' MD 2.28" @ 12844'MD, cement sheath inside tbg from pkr sqz 5/19/06 Drifted to 12,700'SLM 02/15/2007 05/09/07 LDL - found leak at 12402'MD WAG Injector SWS LDL on 05/08/07 Y-24i is a WAG injector that was SI since 9/28/06 due to IA repressurization - 1000 psi/30 min. The well was drilled in 1986 and RWO was completed in 2001 to replace the tubing and fix a PC leak. A caliper run on 02/15/07 inducates the tubing is in excellent condition. The objective of this procedure is to patch a confirmed leak at 12402' ELMD (05/08/07 LDL) to restore tubing integrity. The well will provide further support to the offset producers and improve the WF/EOR recovery. If you have any questions or comments regarding this procedure, please call DeWayne Schnorr at 564-5174 (w) or 244-7214 (c) or Jennifer Julian at (w) 564-5663, (h) 274- 0929 or (c) 240-8037. cc: w/a: Well File Pre-Patch Slickline . . 1. RU SL. Pull WRP. 2. Drift with Baker 3-1/2" dummy patch to 12550'. Note: (3-1/2" HES X Nipple @ 12464', ID = 2.75"). Patch Specs 3-1/2",25' L-80 Single Set Baker Patch. (L-80 carbon steel is recommended for this injection well. Do NOT run a chrome patch.) Patch Depth ***AII depths are referenced to SWS LDL 05/08/2007***. Patch Setting Depths are 12388'- 12413' ELM Patch Length: 25' from element to element. Relevant Top Depths --- Full Joints below SSSVN. From SSSVN JT 335 JT 336 JT 337 JT 338 JT 338.1 JT 338.2 JT 338.3 JT 338.3 JT 338.4 JT 338.4 Eline Set Patch SWS LDL(ELM) 05/08/2007 12299' 32+' 12332' 32-' 12364' 29' 12393' 32' (Leak @ 12402') 12425' 10' Pup Joint 12435' l' X Nipple (ID = 2.75") 12436' 10-' Pup Joint 12446' 10-' Pup Joint 12456' 6-' Pup Joint 12462' 14' PBR Assembly ~t~, 3. RU EL and tie into ~ jewelry and short joints using SWS LDL 05/08/07 4. Set 3-1/2" Baker Single Set Patch from 12388'- 12413' ELM per manufacturer's recommendations. 5. MIT-IA to 2400 psi. LLR if MIT-IA fails. Note: The Tubing Talley is wrong _m It has 339 joints between the SSSVN and the X nipple above the PBR. The POS Caliper only has 338 full jts across this same interval. The SLB LOL log (05/08/2007) finds the SSSVN at the same depth as the Tubing Talley, and an earlier ELMO TT measurement found the tubing tail to 31 ft short of the Tubing Talley. So there you go. 2 . . 'TREE.. 3-1.." hCeJOV WB.1.HEAO.. tŒ/OY ACTUA'IOR.. 016 KII. a.et" 88.85' SF. B.e,t .. 5135' KOP..--------IÕ5li' Y-24 SAFElY NOTSI: PKRRfPAtR SQZ 12700' . 12905'. HOL£ DRLO 10 II 2.28", CAUTICN: FISH OHBT,.. LAST TO@ 13<13<1' W A 2.2" OD CENrRAUZER- 03127100. 3-112" HES XHNlPMILlEOTO 2.74-10BY CTU01.02A12. 3-1f2" TOO, 9.31. L-OO, .0087 bpf.IO" 2.992' . 2038' 3-1f2"HESXD8SSSVN.1O .2.75" 13-3... CSG.12I. L-OO.IO " 12.347" 9-5/'8" X7" BKRZXPf'KRlHGA,IO.. 6.31" 7" tNR-CM'I'D. 261. L -«1.10 .. 6276" 2J!Ii1' WFO WAf' SEr (021181'01) 3-1f2" HES XNIP,IO "2.75" I!KR 80140 FeR, 10.. 295" 9-5.6" XT" OOT LNR HGRWITlfBACK 2-711'f' 016 X Nfl. 10. 2.313" 2-7/1'f' OT6 X .NfI.ID" 2.313" 2-7.." TBG, 6.4#. L-OO,.OOS8 bpf.ID" 2.441" BTM Œ CMT SHEATH (CTM) 9-5/'8" CSG. 47#, L -«I. D " 8.ß81" 13200' PIR'ORA 110NSUMMARY REFLOO: SWS - BHCS OO07112J1!6 ANGLEATTOPÆRF: 43@1313B' Nole: Aefel'toProdooícnDBforlis1orical elf data S2E SWINTER\I AL ~Sqz no, TE 2-1/8" 6 13138 - 13153 '"' 02l19.e9 2-118" 4 13262 - 13364 ," OQ/IO,ea T" LNR, 261. L-OO TC4S. .0083 bpf. D" 6276" 13432' 13434' 34'X2-1I8"PERFGUN,&0Cl TOP no, TER£:V BY eot.tt.e(IS 07118186 ORIGINAL COM PLErION 12104101RWO œiOSIOI CH4<AK OORRB::TIONS 01/07102 Gm' OORRECTIONS 021181'01 c.HPI\G SErWFDWRP@ 12538 no, TE Rei BY eot.tt.e(IS PRUDHOE SAY UNIT WELL: Y-24 PERMlTNo: 186-1130 API No: 50.œ9-21608-00 £34. T11N.RI3EI349'SN... 83'EWL BPExpjoratlon(Alaska) 3 4 . . IØ ITUBlNG SUMMARY RK¡ DOVON,. Date 11130/2001 I weLL_ 0$ Y·Ui TUBING 3.5" L.aO NSCT \ T80 WT. 9.211 ¡ j ! 432 JT8 ON RACK 401 JTS RAN 22,10 OKS TO SF ! , I 133ft.'1 fIT ON RACK 1238153 FT RAN I , ITEM De.mtltion includ..: SIZE, TVPE, CONNECTION (JTS ...) ID OD UNGTH TOP BOTTOM UNIOUE CUSTOM OVERSHOT 3.1124 I.tf 7.32 12112.48 12819.81 PUP JOINT 2.'37 UI .... 12102..3 12812.49 1 JOINT L-80 3 112" NSeT TUBING 2.t37 :UI 30.20 12572.43 12102.63 pup JOINT (3 112" L·80 NSCT) 2.937 3.96 9.88 UI562.5.$ 12512.43 )(IN NIPPLE 2.'1'5 3.M 1.13 12561.42 12562.55 PUP JOINT (3 112" L·80 NSCT) 2.137 3.9. t.11 1255U5 12561.42 1 JOINT L-60 3 112" NSCT TU81NG 2.937 3.'. 30.40 12521.25 l2lt1.8. PUP JOINT 13 112" L·aO NSCT) 2.937 u. 9.'. 12111.3t 12521.25 )(10 (4112" NSeT BOX x 31/2" NSCT fl N) 2.931 3.98 1.90 usot."" 12511.39 9 5Ær' 5-3 PACKeR 2.9514.0 8.25 4.64 12504.85 12509.49 XlO 131fT NSCT BOX x 4 112" NSCT P1N) 2.937 3.16 1.80 U503.05 12504.85 XIO (3 1f2" elÆ BOX x 3 112" NOCT PIN I 2.131 3." 1.70 12501. J& 12103.05 901"0 PeR :) I 13.'1 124'7.7" 12101.35 124.7.7.. 12481.14 (2) JTS RUN ABOVE SHOWN IN 5-3 ASSEMBLY TALLY 12487.74 124'7.14 12487.74 12481.74 SEAL ASSEMBI. V (SEAL UNIT 11.$' LONG) 2.95 4.5 .37 12"17.n 12487.74 X10 2.'37 U. 1." 1241.,41 12487.37 TUBING PUP un )," '.n 1247'." 1248"" XlO PUP (L-eO FOX BOX ~ NSCT PIN) Utn 3." t,33 12470.21 124rU4 XlO PUP (L-80 NSCT SOX JC FOX PIN) 2.fM12 U. SU7 124S0.&4 12470.21 3.5" ~ 2.7'5* HES 'X' NIPPLE WI HP RHC-M 2.TS 3.96 1.00 1245'.14 124S0.14 TUBING pup (L-80 NSeT) :l.Itn 3.98 9.71 1244.... 124".14 339 JTS I.·eo 3 112" NSCT TUBING (JT S 1 THRU 339) 2.187 :1.18 1CM¡¡.30 201.." 1244.." .. XJO PUP (L·eo FOX SOX x NSCT P1N) 2.1912 :US '.25 2001.31 201U6 3.5" \2.15" !-IES "X08'" wlPACKOFF, 1.7'5" ID (FOX B)(P) 2.TS 4.795 3.22 2004.09 2001,31 \ XIO PUP (1.-80 NSCT BOX x FOX P1N) 2.992 ;1.91 9.56 1"".53 2004.09 61 JT$ I.-SO 3 1f2" NSCT T~NG IJTS 340 THRU 4(0) 2.'11I7 ¡.96 1t21.00 73.13 '"4.53 SPACER PUPS ,111I7 3.96 '4.79 58.74 13.53 JT L-BO 3 112" NSCT TU81NG IJT " 401 j 2.'81 3.88 32.03 28.71 58,"4 C¥J (3 m"NSCT PIN )( 4 112" NSCT BOX) 2...7 5 1.80 24.81 B.11 \ 41/r' NSCT PUP 3..5 4.5 1.30 23.51 24.81 TUBING HANGER - 22.70 3.1'5 4,5 .81 23.51 \ DOYON 16 R!<8 22.70 22.70 \ \ Correction --- From the PDS Caliper survey there are only 338 full joints between the SSSVN and the X Nipple above the PBR. . 5 ¡:)¡:!iÍ 6 7 4 1 · ' REC OCT 1. 0 2006 1 0/06/06 Sc~IuIß~8rg8r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth u:r:c... (1~0 - 113 N~pïl&Á~= CQmml.1 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Loa Description Date BL Co or C 3-29/J-32 11414759 SBHP SURVEY 09/04/06 1 L4-10 11285941 MEM PROD PROFILE 09/15/06 1 L2-21A 11421023 LDL 09/11/06 1 C-18A 11285934 MEM PROD & INJECTION 07/29/06 1 Y-24 N/A INJECTION PROFILE 09/03/06 1 Z-31 11414379 INJECTION PROFILE 09/04/06 1 S-27B 11285940 MEM PROD PROFILE 09/14/06 1 P-13 11414277 INJECTION PROFILE 09/03/06 1 X-33 11421024 LDL 09/12/06 1 Z-19A N/A MDT 09/08/06 1 A-17 11414381 USIT 09/07/06 1 X-01 11422961 USIT 09/09/06 1 H-04A 11285942 SCMT 09/17/06 1 15-39A 11212888 SCMT 09/16/06 1 C-09A 11209608 MCNL 06/16/06 1 1 C-18A 11285934 MCNL 07/29/06 1 1 Z-14B 40013765 OH EDIT OF MWD/LWD 07/31/06 1 1 D . . Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 "....If' "!r..~~~r;:n {1:VNJ";,¡' \1__- Q "" "2DD5 v,, - Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~; }~ ¿?7>~ì . , H_ f ,:: ,I DATE: Tuesday, October 03, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC ¥-24 PRUDHOE BA ¥ UNIT ¥-24 Src: Inspector \\~ \, r¡, 'I!/' Reviewed By: P.I. Suprv_~n;j2 Comm FROM: John Spaulding Petroleum Inspector NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT Y-24 API Well Number 50-029-21608-00-00 Inspector Name: John Spaulding Insp Num: miUS061001101240 Permit Number: 186-113-0 Inspection Date: 9/30/2006 Rei Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -~ - , i -- Well ¥·24 Type Inj. f N'TVD 8426 IA I 860 i 3000 2980 i 2975 i i ITypeTest I SPTi Test psi í I P.T. 1861130 2J 06.5 OA I 0 I 0 0 ¡ 0 I I , ~L I -.-- -- Interval OTHER PfF p Tubing i 0 ! 0 0 0 I I ~--- I i -- Notes The well had a suspected tubing leak - not verified this test. The OA had a positve but undetectable pressure. The tubing was on a vacumn. V , ~ Tuesday, October 03, 2006 Page 1 of I Y-24 (PTD #1861130) IA Repressurization All, Well Y-24 (PTO #1861130) has been found to have confirmed IA repressurization. The TIO pressures were 1500/1550/320 on 9/8/06. . The plan forward for this well is as follows: 1. OHO: Bleed lAP - Confirmed Repressurization 2. WOE: Have well shut-in and freeze protected - Request made 9/10 3. WAV: AOGCC MITIA SCAI\!NfD SEP 2 tl 2DDB A wellbore schematic has been included for reference. «Y-24.pdf» The well has been classified as a Trouble well. Please call if you have any questions. Thank you, jInna (j)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 . 1 of 1 9/11/2006 11 :22 AM TREE = 3-1/8" MCEVOY WB..LHEAD = MCEVOY A GTUA TOR = OTIS KB. ELEV = 88.85' BF. ELEV = 51.35' KOP = 1050' Max Angle - 58 @ 6900' DatumMD= 13138' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 7" LNR-CMT'D, 26#, L-80,ID = 6.276" . Y-24 . 5800' Minimum 10 = 2.28" @ 12844' CEMENT SHEATH INSIDE TBG FROM PKR SQZOF 05/19/96; MILLED OUT BY COILED TUBING 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" I 9-5/8" X 7" BOTLNR HGRWITIEBACK 2-7/8" TBG, 6.4#, L-80, .0058 bpf, ID = 2.441" I BTMOF CMT SHEATH (C1M) 9-518" CSG, 47#, L-80, D = 8.681" I 12869' 2038' 3171' 12464' 12492' 12510' 12567 12625' 12743' 12795' 12824' 12844' 12927 SAFEfY NOTES: PKR R8'>AIR SQZ 12700' -12905'. HOLE DRlD ID = 2.28". CAUTION: ASHONBTM. LASTTD@ 13434' W A 2.2" OD CENTRALlZER- 03/27/00.3-1/2" HE5 XN NIP MILLED TO 2.74" ID BY CTU 01/02102. 3-1/2" HES XDB SSSVN, ID = 2.75" 9-518" X 7" BKR ZXP A<R/HGR, D = 6.31" 3-1/2" HESX NIP, ID = 2.75" BKR 80/40 PBR, ID = 2.95" UNIQUE CUSTOM OVERSHOT 3-1/2" OTIS SLIDING SLV, ID= 2.750" 9-518" X 3-1/2" TIW HBBP-R A<R 3-1/2" X 2-7/8" XO, ID= 2.441" 2-718" OTIS X NIP, ID =2.313" 2-718" OTIS X NIP, ID = 2.313" 12896' HELM) TT ()ð.TENOT AVAILABLE I 2-718" 18G TAIL 13138' PERFORATION SUMlAA RY REF LOG: SWS - BHCS ON 07/12/86 ANGLEATTOPPERF: 43@13138' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz ()ð. TE 2-1/8" 6 13138 - 13153 0 02/19189 2-1/8" 4 13262 - 13364 0 09/10188 7" LNR, 26#, L-80 TC4S, 0.0383 bpf, ID = 6.276" ()ð.TE 07/18186 02/28/01 03107/01 06105101 12104101 REV BY COMlAENTS ORlGINA.L COMPLETON SIS-QAA CONVERTED TO CANVAS SS-LG FINA.L CI-VKAK CORROCTONS ROO 13508' 13550' DATE 01/07/02 REV BY COMflÆNTS CHffP CORREC1l0NS 13200' 13432' 13434' 7" NIð. RKER JOINT 2-118" X 8" PERF GUN/BUlLNOSE CENTRALIZER SPRING 34' X 2-1/8" PERF GUN, & CCl TOP PRUDHOE BAY UNrr WELL: Y-24 PERMrr No: 186-1130 AA No: 50-029-21608-00 SOC 34, T11 N, R13E 1349' SNL, 83' EWL BP Exploration (Alas ka) ( (' State of Alaska MEMORANDUM TO: Alaska Oil and Gas Conservation Commission THRU: Jim Regg P.I. Supervisor ~rlft 7;{ /5'ILA DATE: Wednesday, March 10, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC FROM: Chuck Scheve Petroleum Inspector Y-24 PRUDHOE BAY UNIT Y-24 Src: Inspector NON-CONFIDENTIAL API Well Nnmbe 50-029-21608-00-00 InspN mitCS040305 I 52323 Inspection Date: 3/5/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: Y-24 Type Inj. N TVD 8426 IA 0 4000 3940 3930 P.T. 1861130 TypeTest SPT Test psi 2106.5 OA 0 0 0 0 Interval Other (describe in P/F Pass Tn bing 0 0 0 0 nnT"'~ Notes: Pre Wag swap MIT. Type INJ. Fluid Codes F =FRESH WATER IN]. G=GAS INJ. S=SALT WATER INJ. N=NOT INJECTING Type Test M=Annulus Monitoring P=Standard Pressure Test R=Intemal Radioactive Tracer Survey A=Temprature Anomaly Surve D=Differential Temprature Test Interval 1=lnitial Test 4=Four Year Cycle. V=Required by Variance W=Test during Work over O=Other (describe in notes) Wednesday, March 10, 2004 Page I of 1 SCA~!~E[} MA~~ 1 {f 2004 STATE OF ALASKA ALASKA ~IL AND GAS CONSERVATION COMM~c,$1ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 88.85' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1349' SNL, 83' EWL, SEC. 34, T11 N, R13E, UM Y-24i 9. Permit Number/ Approval No. At top of productive interval 186-113 301-008 1747' NSL, 397' EWL, SEC. 04, T10N, R13E, UM 10. APl Number At effective depth 50-029-21608-00 1606' NSL, 227' EWL, SEC. 04, T10N, R13E, UM 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 1578' NSL, 191' EWL, SEC. 04, T10N, R13E, UM Pool 12. Present well condition summary Total depth: measured 13550 feet Plugs (measured) true vertical 9207 feet Effective depth: measured 13478 feet Junk (measured) Fill at 13478' MD; Fish at 13434' MD and at 13342' MD true vertical 9151 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 8 cu yds. Concrete 110' 110' Surface 3015' 13-3/8" 4000 cu. ft. Permafrost 3053' 2672' Intermediate 13100' 9-5/8" 575 cu. ft. Class 'G' 13138' 8889' Production Liner 681' 7" 349 cu. ft. Class 'G' 12869' - 13550' 8688' - 9207' Scab Liner 2629' 7" 483 cu ft Class 'G' 3171' - 5800' 2743' - 4294' Perforation depth: measured 13138'- 13153' (Sag River); 13262'- 13364' (5 Intervals Ivishak) true vertical 8889' - 8900' (Sag River); 8984' - 9063' (5 Intervals Ivishak) Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 to 12488'; 3-1/2", 9.2#, L-80 12484 to 12625'; 3-1/2", 9.3#, L-80 12623' to 12795' with 2-7/8" tailpipe to 12927' Packers and SSSV (type and measured depth) 9-5/8" TIW Packer at 12795'; 9-5/8" Baker 'S-3' packer at 12510'; 7" Scab Liner Baker 'ZXP' packer at 3171'- 3-1/2" HES 'XDB' SSSV Nipple at. 2004' 13. Stimulation or cement squeeze summary i-'~ ~'~i ~r. :. Intervals treated (measured) ..!ii"" '! Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: W~_er.~. ~ ~ ~,,~ I"1 Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service Produced ' [] Daily Report of Well Operations 17. I hereby certify that the fore, going is t.~ to the best of my knowledge Signed Terrie Hubble '"'~~,/~" /(~~---~ Title Technical Assistant Date 0 ~,~. r~. ~ f~, i i'.. f ~-',~ ~ Prepared ByName/Number: Terrie Hubble, 564-4628 ~ , ,~ ,_ ,-.. .... i~__~ Form 10-404 Rev. 06/15/88 ORiGii' AL Submit In Duplicate Report Legal Well Name: Y-24i Common Well Name: Y-24i Spud Date: 11/21/2001 Event Name: WORKOVER Start: 11/22/2001 End: 12/4/2001 Contractor Name: DOYON Rig Release: 12/4/2001 Rig Name: DOYON 16 Rig Number: ~te ? ~From- T~ HOarslActivitY COde Ii NPT ~i Phase Description of Operations 11/22/2001 19:00 - 23:00 4.00 MOB P DECOMP PREP RIG FOR MOVE TO Y-24i, LAY OVER DERRICK. 23:00 - 00:00 1.00 MOB P DECOMP MOVE RIG F/A-24 TO Y PAD. 13 MILE MOVE, PHASE 1 CONDITIONS. 11/23/2001 00:00 - 07:30 7.50 MOB P DECOMP MOVE RIG FROM A PAD TO Y PAD, PHASE 1 CONDITIONS. 07:30 - 09:30 2.00 MOB P DECOMP PJSM, RAISE DERRICK / RIG FLOOR TUGGERS, BRIDLE BACK & LIFT SUB DOORS. 09:30 - 14:00 4.50 MOB P DECOMP PJSM, SPOT RIG OVER WELL, LEVEL & SHIM. 14:00 - 19:00 5.00 MOB P DECOMP CONTINUE RIG UP.THAW & REPAIR STEAM HEATERS IN CELLAR .... FROZE UP DURING MOVE. TAKE ON SEAWATER. ACCEPT RIG @ 1700 HRS, 11/23/2001. 19:00 -22:30 3.50 KILL P DECOMP RIG UP MANIFOLD ON TREE. PICK UP LUBRICATOR & PULL BPV. 250 PSI ON 3 1/2" TBG, 250 PSI ON 3 1/2" x 9 5/8" ANNULUS, 50 PSI ON 9 5/8" x 13 3/8" ANNULUS. 22:30 - 00:00 1.50 KILL P DECOMP PJSM, RIG UP TO CIRCULATE & REV CIRCULATE DIESEL OUT OF TUBING, PUMPING SEAWATER, TAKING RETURNS THRU CHOKE & HOLDING 200-300 PSI BACK PRESSURE TO GOOD CLEAN RETURNS, (NO GAS). CIRCULATE DOWN TUBING TAKING RETURNS THRU CHOKE TO GOOD CLEAN RETURNS. 11/24/2001 00:00 - 06:00 6.00 KILL P DECOMP CIRCULATE DIESEL OUT OF 9 5/8" ANNULUS TO CLEAN RETURNS. MONITOR WELL, PENCIL STREAM OUT OF ANNULUS, MAYBE 4 BBLS/HR OUT OF TUBING. SHUT IN & RECORD PRESSURES, 25-50 PSI ON TUBING, NOTHING ;ON ANNULUS. OPEN UP & MONITOR, FLOW SLOWED BUT !DID NOT STOP TOTALLY. WEIGHT UP TO 8.7+ PPG WHILE PUMPING @ 6 BPM / 800 PSI, (1) COMPLETE CIRCULATION. 06:00 - 07:00 1.00 KILL P DECOMP MONITOR WELL, WELL IS DEAD. SET 2 WAY CHECK & PT TO 2500 PSI, OK. 07:00 - 08:30 1.50 BOPSUF~ P DECOMP PJSM. BLOW DOWN MANIFOLD LINES & R/D SAME. N/D TREE. CHECK THREADS IN TUBING HANGER, GOOD. 08:30 - 17:00 8.50 BOPSUF~ P DECOMP N/U 13 5/8" x 5M BOPE. 17:00 - 22:00 5.00 BOPSUR P DECOMP TEST BOPE, TEST WITNESSED BY AOGCC REP LOU GRIMALDI. 22:00 - 23:00 1.00 BOPSUF P DECOMP PULL 2 WAY CHECK, TUBING DEAD, BOLD's, SCREW INTO TBG HANGER. 23:00 - 00:00 1.00 PULL P DECOMP PJSM. PULL TO 125K, HANGER FREE. SLACK OFF & WORK UP IN 5 K INCREMENTS TO 160K, (150 + 10K F1 BLOCKS), PULLED FREE. PULL TBG HANGER TO FLOOR, 105K UP WT. RIG UP TO CIRCULATE. 11/25/2001 00:00 - 03:30 3.50 PULL P DECOMP PJSM. CIRC BTMS UP, BUILD VOLUME & CONDITION TO 8.7+ PPG. RIG UP CAMCO SPOOLER. 03:30 - 16:00 12.50 PULL 3 DECOMP POOH W/3 1/2" L-80 9.3~ 8 RND TBG & LAY DOWN SAME. RECOVERED (36) CLAMPS & (4) BANDS W/CONTROL LINE. L/D CAMCO SPOOLER & CONTINUE CCH. 390 JTS OF TUBING OUT, HOLES NOTED IN #s 274, 291,292, & PERFS IN #389.3.93' STUB, CUT IS CLEAN. 16:00 - 17:00 1.00 PULL ~ DECOMP CLEAN RIG FLOOR. 17:00 - 19:00 2.00 CLEAN ~ DECOMP SET TEST PLUG, TEST LOWER PIPE RAMS, PULL TEST PLUG. LOAD & STRAP 3 1/2" DP IN PIPESHED. 19:00 - 20:30 1.50 CLEAN P DECOMP SLIP & CUT 57.5' OF DRILLING LINE. SERVICE RIG. 20:30- 22:30 2.00 CLEAN P DECOMP CONTINUE LOADING PIPESHED, 399 JTS TOTAL LOADED Printed: 12/10/2001 11:18:00AM OPerationSlsummary Report Legal Well Name: Y-24i Common Well Name: Y-24i Spud Date: 11/21/2001 Event Name: WORKOVER Start: 11/22/2001 End: 121412001 Contractor Name: DOYON Rig Release: 12/4/2001 Rig Name: DOYON 16 Rig Number: :~::: ~::~:~:~: :~; ~:~ ~ ~ I::~: ~ x ~Activity:: :: :~'t' t ~:~Dat~/[ro~- To ~HOu[$: :Code: NP-I- I :Phase I Description of Operations I I i1/25/2001 i20:30- 22:30 2.00 CLEAN P DECOMP & STRAPPED. 22:30 - 23:30 1.00 CLEAN P DECOMP M/U BHA FOR DRESSING 3 1/2" TBG STUB & 9 5/8" SCRAPER. !23:30 - 00:00 0.50 CLEAN P DECOMP PJSM. PICK UP 3 1/2" DP & RIH. 11/26/2001 !00:00 - 13:30 13.50 CLEAN P DECOMP CONTINUE TO PICK UP 3 1/2" DP WITH TUBING STUB DRESSOUT BHA & CASING SCRAPER. TAG @ 12,538', (FILL), L/D (2) JTS DP & P/U KELLY. 13:30 - 15:30 2.00 CLEAN P DECOMP WASH DOWN TO STUMP & TAG @ 12,622' DPM. 15:30 - 16:00 0.50 CLEAN P DECOMP MILL STUMP F/12,622'-12,623'. 40 RPM, 3-4K WOB. 16:00- 19:30 3.50 CLEAN P DECOMP CIRCULATE HI-VIS/DIRT MAGNET AROUND, LOTS OF PARAFIN BACK. SPOT HI VIS PILL ON BOTTOM & PUMP DRY JOB. 19:30- 00:00 4.50 CLEAN P DECOMP PJSM, STAND BACK KELLY, MONITOR WELL, WELL STABLE. POOH F/RTTS. 11/27/2001 00:00 - 02:30 2.50 REST P DECOMP RIH w/HALLIBURTON Rl-rS ON 3 1/2" DP TO 3,018'. 02:30 - 03:30 1.00 REST P DECOMP HELD PJSM. SET R'I-I'S @ 3,018'. BLED OFF 13 3/8" x 9 5/8" CA AND KEPT VALVE OPEN. TESTED 9 5/8" ANNULUS ABOVE R-I-I'S TO 3,000 PSI f/30 MINUTES, OK. NO INDICATION OF COMMUNICATION TO CA. 03:30 - 04:30 1.00 REST P DECOMP BLED DOWN PRESSURE, RIH AND SET R-I-rS AT 4,005'. 04:30 - 06:30 2.00 REST P DECOMP TESTED ANNULUS, NOT HOLDING. INJ RATE OF 2 BPM @ 350 PSI w/COMMUNICATION TO CA, 2 BBLS PUMPED AWAY. PUMPED DOWN DP AND TESTED BELOW RTTS, NOT HOLDING. INJ RATE OF 3.5 BPM @ 1,800 PSI NO INDICATION OF COMMUNICATION TO CA. 2 BBLS PUMPED AWAY, SHUT DOWN PUMP & OBSERVED WELL. PRESSURE BLED DOWN TO 900 PSI. 06:30 - 07:30 1.00 REST P DECOMP POOH AND SET RTTS AT 3,306'. 07:30 - 10:00 2.50 REST P DECOMP PRESSURE TESTED ANNULUS TO 3,000 PSI f/30 i MINUTES, OK, NO CA COMMUNICATION. RIH SET RTTS @ 3,495' ATTEMPTED TO TEST, TEST FAILED, POOH 30' TO ;3,465' AND TESTED ANNULUS TO 3,000 PSI f/30 MINUTES, OK. 9 5/8" CASING INTEGRITY GOOD FROM 3465' TO SURFACE. 10:00-11:00 1.00 REST P DECOMP RIH AND SET RTTS AT 6,488'. 11:00 - 12:00 1.00 REST P DECOMP PRESSURE TESTED BELOW RTTS FROM 6,488' DOWN TO 3,000 PSI f/30 MINUTES, OK. 12:00 - 12:30 0.50 REST P DECOMP POOH 5 STANDS TO 6,003', SET RTTS. 12:30 - 14:30 2.00 REST P DECOMP PRESSURE TESTED BELOW R'I-I'S FROM 6,003' TO 3,000 PSI f/30 MINUTES, OK. POOH TO 5,532', SET R-I-rS, PRESSURE TESTED BELOW R'n's FROM 5,532' TO 3,000 PSI f/30 MINUTES, OK. 14:30 - 16:30 2.00 REST P DECOMP POOH TO 5,055', SET R-I-rS. PRESSURE TESTED BELOW R'I-rS FROM 5,055', PRESSURE BLED OFF FROM 1,500 PSI. RIH TO 5,245' SET R'I-I'S. PRESSURE TESTED BELOW RTTS FROM 5,245', PRESSURE BLED OFF AT 1,500 PSI. RIH TO 5,341', SET R'I-rS. PRESSURE TESTED BELOW RTTS FROM 5,341' TO 3,000 PSI f/30 MINUTES, OK. ALL TESTS CHARTED. 9 5/8" CASING FROM 3465'-5341', (1876'), WOULD NOT TEST. 16:30 - 19:30 3.00 REST P DECOMP MONITORED WELL, WELL STABLE, PUMPED SLUG. POOH w/RTTS. BROKE OUT AND L / D RTTS. 19:30 - 20:00 0.50~ REST P DECOMP R / U TO RUN PACKER ASSEMBLY. Printed: 12/10/2001 11:18:00AM SUmmary Report Legal Well Name: Y-24i Common Well Name: Y-24i Spud Date: 11/21/2001 Event Name: WORKOVER Start: 11/22/2001 End: 12/4/2001 Contractor Name: DOYEN Rig Release: 12/4/2001 Rig Name: DOYEN 16 Rig Number: ;!~::;:Date:~ ~:~From - T~ ~HOurs ActiVity Code 1: NPT :i phase Description of Operations 11/27/2001 20:00 - 21:00 1.00 RUNCOF, F' COMP P / U AND M / U PACKER ASSEMBLY AS FOLLOWS: ITEM OD ID LENGTH OVERSHOT 8.25" 3.5625" 7.32' PUP JT 3.96" 2.937" 9.86' FULL JT 3.96" 2.937" 30.20' PUP JT 3.96" 2.937" 9.88' X/N 2.75" 3.96" 1.13' PUP JT 2.937" 3.96" 9.77' FULL JT 2.937" 3.96" 30.40' PUP JT 2.937" 3.96" 9.86' X/O 2.937" 4.97" 1.90' S-3 PKR 3.875" 8.375" 4.64' X/O 2.937" 4.5" 1.8' X/O 2.937" 4.5" 1.7' 80/40 PBR 2.95" 8.25" 13.61' X/O 2.937" 3.96" 1.96' PUP JT 2.937" 3.96" 5.87' I I X/O 3" 5" 1.20' 21:00 - 00:00 3.00 REST P DECOMP RIH wi BAKER S-3 PACKER ASSEMBLY ON 3-1/2" DP 11/28/2001 00:00 - 03:00 3.00 RUNCOr~P COMP HELD PJSM. RIH wi BeT S-3 PACKER ASSEMBLY ON 3-1/2" DP TO 12,600'. 03:00 - 03:30 0.50 RUNCOF, F~ COMP R / U TO CIRCULATE. 03:30 - 04:00 0.50 RUNCOItl~ COMP STARTED PUMP, PUMP RATE 3 BPM, 400 PSI. SWALLOWED TUBING STUB, PRESSURE INCREASED TO 700 PSI. SHUT DOWN PUMP. LANDED OUT ON TOP OF STUB w/OVERSHOT, SET DOWN w/15,000~. PICKED UP 3'. 04:00 - 04:30 0.50 RUNCOr P COMP DROPPED BALL / ROD AND ALLOWED TO FALL. PUMPED ON DRILL STRING, PRESSURE INCREASED. INCREASED PRESSURE TO 2,500 PSI TO SET PACKER, INCREASED PRESSURE TO 3,500 PSI, PBR SHEARED AT 3,300 PSI. BLED DOWN PRESSURE. PICKED UP 10', SET DOWN 13' TOOK WEIGHT, CONFIRMED PACKER SET. PACKER ASSEMBLY SET AS FOLLOWS: ITEM LENGTH DEPTH eVE RS H eT 7.32' 12,624.00' PUP JT 9.86' 12,606.82' FULL JT 30.20' 12,576.62' PUP JT 9.88' 12,566.74' X/N 1.13' 12,565.61' PUP JT 9.77' 12,555.84' FULL JT 30.40' 12,525.44' PUP JT 9.86' 12,515.58' X/O 1.90' 12,513.68' S-3 PKR 4.64' 12,509.04' X/O 1.80' 12,507.24' X/O 1.70' 12,505.54' 80/40 PBR 13.61' 12,491.93' 04:30 - 05:30 1.00 RUNCOF, IC COMP MIXED, PUMPED AND SPOTTED 50 BBL 12 ppg HI-VIS, 80 Printed: 12/10/2001 11:18:00AM operatj°ns Summary Report Legal Well Name: Y-24i Common Well Name: Y-24i Spud Date: 11/21/2001 Event Name: WORKOVER Start: 11/22/2001 End: 12/4/2001 Contractor Name: DOYON Rig Release: 12/4/2001 Rig Name: DOYON 16 Rig Number: :~Date;;~: ~Fro~- TO~ Hours~ Activity COde ~NPT ~i:~i~;~i:~ ~ :~~ ~; ~ii: ;;; ~ ::~; : ;: : Phase Description of Operations 1112812001 04:30 - 05:30 1.00 RUNCOI~ COMP YP, PILL ON TOP OF PBR. PUMP RATE 5 BPM, 500 PSI. 05:30 - 06:00 0.50 RUNCOI~ COMP R / D LINES AND CIRCULATING HEAD, POOH TO 11,822'. 06:00 - 08:30 2.50 RUNCOI~S COMP R / U CIRCULATING HEAD AND LINES. PUMPED AND SPOTFED 418 BBLS 12 ppg MUD, 25 YP. 08:30 - 10:30 2.00 RUNCOI~C COMP R / D LINES AND CIRCULATING HEAD. POOH TO 6,155'. 10:30 - 12:00 1.50 RUNCOI~C COMP R/U CIRCULATING HEAD AND LINES. MIXED, PUMPED AND SPOTTED 50 BBL 12 ppg HI-VIS, 80 YP, PILL AT 6,155'. PUMP RATE 5 BPM, 450 PSI. R / D LINES AND CIRCULATING HEAD. 12:00 - 14:00 2.00 RUNCOr~IC COMP HELD PJSM. POOH FROM 6,155' TO SURFACE. 14:00 - 14:30 0.50 RUNCOr~'IC COMP BROKE OUT AND L / D PACKER RUNNING TOOL. 14:30 - 15:30 1.00 CASE C COMP HELD PJSM. R / U TONGS AND EQUIPMENT TO RUN LINER. 15:30-21:00 5.50 CASE C COMP MIUANDRIHw164JTS7"26~IBTSCABLINER. MIU TORQUE 8,500 ft/Ibs FILLED LINER EVERY 5 JTS. 7" LINER ASSEMBLY SET AS FOLLOWS: ITEM LENGTH DEPTH: WIRELINE GUIDE 1.80' 5,800.00' FLOAT COLLAR 1.20' 5,797.00' 2 JTS 7" 26# IBT LNR 81.72' 5,715.28' LANDING COLLAR INSERTED 5,714.28' 62 JTS 7" 26# IBT LNR 2,524.35' 3,190.93' LINER HANGER 6.56' 3,184.37' ZXP PACKER 13.66' 3,170.71' 21:00 - 22:00 1.00 CASE C COMP CIRCULATED LINER VOLUME, 100 BBLS. R / D 7" CASING EQUIPMENT. 22:00 - 00:00 2.00 CASE C COMP RIH w/7" SCAB LINER ON 3 1/2" DP, FILLED DP EVERY 11 STDS. STRING WEIGHT UP 98,000#, STRING WEIGHT DOWN 63,000#. AT SETTING DEPTH OF 5800'. 11/29/2001 00:00 - 01:30 1.50 CASE C COMP HELD PJSM w/DRILL CREW, HOWCO, BAKER AND PEAK. M / U CEMENT MANIFOLD. CIRCULATED BOTTOMS UP TO COOL AND CLEAN THE HOLE. PUMP RATE 5 BPM, 600 PSI. 01:30 - 03:00 1.50 CASE C COMP SHUT DOWN RIG PUMP, SWITCHED OVER TO HOWCO. PUMPED 5 BBLS WATER AT 2.75 BPM, 100 PSI. TESTED LINES TO 4,000 PSI, OK. PUMPED 5 BBLS WATER AT 2.0 BPM, 60 PSI. MIXED & PUMPED 86 BBLS (400 SX) 15.8 PPG PREMIUM CEMENT w/0.20% BWOC CFR-3 FRICTION REDUCER, 0.30% BWOC HALAD-344, .25~ / SK SUPER CBL AND 0.20% BWOC HR-5 RETARDER. PUMPED CEMENT AT THE FOLLOWING RATES: PUMPED RATE PRESSURE 20.0 BBLS 4.00 BPM 600 PSI 40.0 BBLS 3.50 BPM 380 PSI 60.0 BBLS 5.00 BPM 780 PSI 86.0 BBLS 4.50 BPM 600 PSI : DROPPED DP DART AND DISPLACED w/5 BBLS WATER Printed: 12/10/2001 11:18:00 AM operatiOnS Summary Report Legal Well Name: Y-24i Common Well Name: Y-24i Spud Date: 11/21/2001 i Event Name: WORKOVER Start: 11/22/2001 End: 12/4/2001 'Contractor Name: DOYON Rig Release: 12/4/2001 Rig Name: DOYON 16 Rig Number: ~ ~Dat~ ~ro~ T~: Ho~rs:~ Acti~it,~; ~ Phase Description of Operations 11/29/2001 01:30 - 03:00 1.50 CASE C COMP AT 5.50 BPM, 200 PSI. DISP~CED CEMENT W/115 BBLS SEAWATER AT THE FOLLOWING ~TES: PUMPED ~TE PRESSURE 10.0 BBLS 8.50 BPM 710 PSI 15.0 BBLS 8.50 BPM 700 PSI Slw'd Pmps ~ 18 bbls 2.00 BPM 50 :PSI. DRILL PIPE DART ~TCHED UP w/22.5 BBLS PUMPED, PRESSURE INCR~SED TO 550 PSI, WIPER PLUG SHEARED, PRESSURE DECREASED TO 50 PSI. INCREASED PUMP ~TE 40.0 BBLS 4.00 BPM 155 PSI 60.0 BBLS 4.00 BPM 230 PSI 80.0 BBLS 4.00 BPM 500 PSI 100.0 BBLS 4.00 BPM 780 PSI 110.0 BBLS 4.00 BPM 1,025 PSI ~SIw'd Pmps ~ 115 bbls 2.00 BPM 680 PSI WIPER PLUG BUMP'D w/ 119.5 BBLS PUMPED. PRESSURED UP TO 1,200 PSI TO TEST PLUG, OK. CEMENT IN P~CE AT 0245 HRS. 03:00 - 03:30 0.50 CASE C COMP INCREASED PRESSURE TO 2,800 PSI TO SET BAKER LINER HANGER, SET DOWN 20,00~ TO CONFIRM HANGER SET. INCREASED PRESSURE TO 4,000 PSI TO ACTIVATE PUSHER TOOL AND SET ~P PACKER. OBSERVED PUSHER TOOL SHEAR AT 3,100 PSI AND PACKER SHEAR AND SET AT 3,600 PSI. HELD F/5 MINUTES, NO BLEED OFF. BLED OFF PRESSURE & CHECKED FLOAT, FLOAT HELD. ROTATED DP TO THE RIGHT 18 TURNS, GOT 3 BACK. PRESSURED UP DP TO 1,000 PSI, PICKED UP ON DRILL STRING, 50,00~ NEW UP WEIGHT. PRESSURE DROPPED TO 0 PSI, INDICATING TOOL RELEASED FROM LINER HANGER, OK. CIRCUITED 10 BBLS TO CONTAMINATE CEMENT AND MOVE CEMENT UP HOLE. PICKED UP ON DRILL STRING AND REVERSE CIRCUITED 2 x BOSOMS UP. PUMP ~TE 9 BPM, SPP 1,700 PSI. CIRCUITED BACK 10 BBLS OF CEMENT. 03:30 - 04:00 0.50 CASE C COMP BROKE OUT AND L / D CEMENT MANIFOLD AND 20' PUP JOINT. 04:00 - 05:30 1.50 CASE C COMP POOH FROM 3,170' TO SURFACE. 05:30 - 06:00 0.50 CASE C COMP CLEANED, BROKE OUT AND L / D LINER RUNNING TOOL. 06:00 - 06:30 0.50 CLEAN C COMP M / U HTC 6-1/8" AT J-4 MT BIT, SER~ H99JN AND BHA. 06:30 - 08:00 1.50 CLEAN C COMP RIH w/BIT AND BHA ON 3-1/2" DP TO 3,140'. 08:00 - 08:30 0.50 CLEAN C COMP M / U KELLY AND BROKE CIRCU~TION. PUMP ~TE 5 Printed: 12/10/2001 11:18:00AM ; op rati°ns SUmmary Report Legal Well Name: Y-24i Common Well Name: Y-24i Spud Date: 11/21/2001 Event Name: WORKOVER Start: 11/22/2001 End: 12/4/2001 Contractor Name: DOYEN Rig Release: 12/4/2001 Rig Name: DOYEN 16 Rig Number: i Date i From_iTel, Hours iActi~itY Code :NPTi Phase Description of Operations 11/29/2001 08:00 - 08:30 0.50 CLEAN C COMP BPM, SPP 350 PSI. TAGGED TOP OF LINER AT 3,172'. WASHED DOWN TO 3,182'. PUMP RATE 6.5 BPM, SPP 550 PSI. PULLED UP 40', SHUT DOWN PUMP. 08:30 - 09:00 0.501 CLEAN C COMP CLOSED UPPER PIPE RAMS AND PRESSURE TESTED TOP OF LINER TO 3,000 PSI f/30 MINUTES, OK. BLED DOWN PRESSURE, OPENED PIPE RAMS. 09:00 - 10:00 1.00 CLEAN C COMP CIRCULATED BOTTOMS UP, PUMP RATE 6 BPM, SPP 500 PSI. 10:00 - 11:00 1.00 CLEAN C COMP HELD PJSM. BROKE OUT AND L / D 21 JOINTS OF 3-1/2" DP. 11:00 - 12:00 1.00 CLEAN C COMP RIH w/6-1/8" BIT AND BHA ON 3-1/2" DP TO 5,549' 12:00 - 12:30 0.50 CLEAN C COMP M / U KELLY, WASHED AND REAMED FROM 5,549' TO 5,698'. PUMP RATE 5 BPM, SPP 600 PSI. TAGGED CEMENT AT 5,698'. 12:30 - 15:00 2.50 CLEAN C COMP DRILLED CEMENT, PLUGS AND LATCH COLLAR FROM 5,698' TO 5,720'. WeB 10,000# - 25,000#, RPM 55 - 100, PUMP RATE 7 BPM, SPP 1,000 PSI. 15:00 - 17:00 2.00 CLEAN C COMP DRILLED OUT SHOE TRACK FROM 5,720' TO 5,795'. WeB 15,000# - 20,000#, RPM 75, PUMP RATE 7 BPM, SPP 1,000 PSI. 17:00 - 18:00 1.00 CLEAN C COMP PUMPED AND CIRCULATED AROUND 25 BBL HI-VIS SWEEP. 18:00 - 18:30 0.50 CLEAN C COMP DRILLED CEMENT AND FLOAT COLLAR FROM 5,795' TO 5,796'. WeB 5,000# - 10,000#, RPM 100-110, PUMPE RATE 7 BPM, SPP 1,100 PSI. 18:30 - 19:00 0.50 CLEAN C COMP WASHED DOWN F/5,796' TO 5,825'. TAGGED LOW SIDE CEMENT AT 5,825', SET DOWN 10,00C~ - 15,000#. 19:00 - 21:00 2.00 CLEAN C COMP DRILLED CEMENT F/5,825' TO 6,079', WeB 2,000# - 5,000#, RPM 110, PUMP RATE 8 BPM, SPP 1,350 PSI. CIRCULATED 1-2 MINUTES BETWEEN CONNECTIONS. DRILLED THROUGH LOWSIDE CEMENT @ 6,079'. 21:00 - 22:00 1.00 CLEAN C COMP WASHED DOWN F/,6079'-6,334', PUMP RATE 8 BPM, SPP 1,400 PSI, NO RESISTANCE. 22:00 - 23:00 1.00 CLEAN C COMP PUMPED AND CIRCULATED AROUND 25 BBL HI-VIS SWEEP, ROTATED AND RECIPROCATED PIPE WHILE CIRCULATING. PUMP RATE 8 BPM, SPP 1,400 PSI. CIRCULATED UNTIL RETURNS OVER SHAKER WERE CLEAN. 23:00 - 00:00 1.00 CLEAN C COMP BRK OFF KELLY & LINED UP TO TEST. 450 PSI ON 13 3/8" O/A, DIESEL BACK, (FLUID PACKED). PRESSURE TESTED LOWER PART OF LINER TO 3,000 PSI f/30 MINUTES. PRESSURE LOSS OF 50-60 PSI IN FIRST 15 MINUTES @ VERY SLOW RATE, PRESSURE HELD CONSTANT f/ .SECOND 15 MINUTES. NO INCREASE ON 13 3/8" O/A. BLED DOWN & OPENED PIPE RAMS. CHARTED TEST. 11/30/2001 00:00 - 02:30 2.50 CLEAN C COMP PJSM. POOH W/3 1/2" DP. 02:30 - 03:00 0.50 CLEAN C COMP BROKE OUT AND L / D 4-3/4" D.C. 03:00 - 03:30 0.50 CLEAN C COMP M/U POLISH MILL ASSEMBLY. 03:30 - 07:00 3.50 CLEAN C COMP RIH w/POLISH MILL ASSEMBLY ON 3 1/2" DP TO 7,740'. 07:00 - 07:30 0.50 CLEAN C COMP R / U AND BROKE CIRCULATION. PUMP RATE 2 BPM, SPP 600 PSI. TOTAL PUMPED 5 BBLS. SHUT DOWN AND ALLOWED FLUID TO EQUALIZE. 07:30 - 09:00 1.50 CLEAN C COMP RIH w/POLISH MILL ASSEMBLY ON 3 1/2" DP TO 12,480' Printed: 12/10/2001 11:18:00AM Operations Summary Report Legal Well Name: Y-24i Common Well Name: Y-24i Spud Date: 11/21/2001 Event Name: WORKOVER Start: 11/22/2001 End: 12/4/2001 Contractor Name: DOYON Rig Release: 12/4/2001 Rig Name: DOYON 16 Rig Number: ~Date ~ From~~°urs ActiVity iC°de~ ~ iI~:Np-l-ll ~ :l Phase Description of Operations 11/30/2001 09:00 - 10:30 1.50 CLEAN i C COMP M/U KELLY AND BROKE CIRCULATION. PUMP RATE 3 BPM, SPP 1,700 PSI. STRING WEIGHT DOWN 87,000#, STRING WEIGHT UP 177,000#, STRING WEIGHT ROTATING 117,000~. STUNG MILL INTO PBR, CLEANED OUT AND POLISHED PBR. WOM 2,000#, RPM 25, TORQUE 210 AMPS. 10:30 - 14:00 3.50 CLEAN C COMP DROPPED BALL TO OPEN CIRCULATING SUB. PUMP RATE 5 BPM, SPP 2,500 PSI. BALL HIT PRESSURE DROPPED TO 1,900 PSI. PUMPED 25 BBL HI-VIS SWEEP. PUMPED AND DISPLACED MUD IN HOLE w/8.6+ ppg SEAWATER. PUMP RATE 8 BPM, SPP 2,000 PSI. 14:00 - 15:30 1.50 CLEAN P COMP BROKE DOWN AND RACKED BACK KELLY. 15:30 - 20:00 4.50 CLEAN P COMP POOH, L / D 390 JTS 3-1/2" DP TO 7645' 20:00 - 21:00 1.00 CLEAN P COMP PJSM SLIP & CUT 120' OF DRILLING LINE. 21:00 - 00:00 3.00 CLEAN P COMP POOH & L/D 3 1/2" DP, 7645'-2459'. 12/1/2001 00:00 - 02:30 2.50 CLEAN P COMP HELD PJSM. POOH L / D 3-1/2" DP. 02:30 - 03:00 0.50 CLEAN P COMP BROKE OUT AND L / D POLISH MILL. 03:00 - 03:30 0.50 BOPSUF P COMP M / U RETRIEVING TOOL, PULLED WEAR BUSHING. L / D i~ RETRIEVING TOOL. 03:30 - 04:00 0.50 RUNCO COMP RIGGED UP FLOOR TO RUN 3 1/2" COMPLETION. RIGGED UP GATOR HAWK EQUIPMENT. 04:00 - 04:30 0.50 RUNCOI~ ;COMP HELD PJSM w/DRILL CREW, CASING CREW AND GATOR / HAWK CREW. 04:30 - 19:00 14.50 RUNCOI¥~ COMP M / U SEAL ASSEMBLY & X NIPPLE ASSEMBLY. M / U AND RIH wi 3-1/2" 9.3~ NSCT L-80 TUBING. TORQUE TURNED TO 2,850 fi/lbs, HYDRO TESTED EACH CONNECTION TO 4,000 PSI w/GATOR HAWK. HELD PJSM w/CASING CREW, GATOR HAWK AND DAYLIGHT DRILLING CREW AT 1200 HRS. 200 JTS 6,155' RUN. 19:00 - 20:30 1.50 RUNCOI~ COMP M / U HEAD PIN & CIRCULATED 350 BBLS HEATED TREATED SEAWATER, (150 deg), 102 deg COMING OUT. CIRC @ 6 BPM, 600 PSI SPP. FOUND BAD SPOT IN i DRILLING LINE, SLIPPED & CUT 392' WHILE RUNCOI~ CIRCULATING. 20:30 - 00:00 3.50 ',P COMP CONTINUED TO RIH WI 3-1/2" COMP STRING, TORQUE I TURNED & PRESSURE TESTED EACH CONNECTION TO I 4,000 PSI WI GATOR HAWK. 12/2/2001 00:00 - 05:30 5.50 RUNCOP~ COMP HELD PJSM. RIH w/3-1/2" 9.3# NSCT L-80 TUBING TO JOINT #339. TORQUE TURNED TO 2,850 fi/lbs, HYDRO TESTED EACH CONNECTION TO 4,000 PSI w/GATOR HAWK. 05:30 - 06:00 0.50 RUNCOI~ COMP P / U AND M / U SSSV ASSEMBLY. 06:00 - 07:00 1.00 RUNCOI¥~ COMP R / U CAMCO CONTROL LINE EQUIPMENT. M / U CONTROL LINES TO SSSV. TESTED CONTROL LINES TO 5,000 PSI. OK. 07:00 - 13:30 6.50 RUNCOI~ COMP RIH w/3-1/2" 9.3# NSCT L-80 TUBING. TORQUE TURNED TO 2,850 fi/lbs, HYDRO TESTED EACH CONNECTION TO 4,000 PSI w/GATOR HAWK. MADE UP CONTROL LINES TO TUBING w/STEEL CLAMPS. 13:30 - 14:00 0.50 RUNCOI~P COMP R / U CIRCULATING HEAD AND HOSES. DEPTH NOW IS ! 12,490'. 14:00 - 14:30 0.50 RUNCO~P COMP BROKE CIRCULATION AND WASHED DOWN. PUMP RATE Printed: 12/10/2001 11:18:00AM ;27 :: Operati°ns::Summary Report Legal Well Name: Y-24i Common Well Name: Y-24i Spud Date: 11/21/2001 Event Name: WORKOVER Start: 11/22/2001 End: 12/4/2001 Contractor Name: DOYON Rig Release: 12/4/2001 Rig Name: DOYON 16 Rig Number: ~¢t:~Date~}~ Fr°~To }HbCrs;ActNitY C°deNpT Phase ': Description of Operations 12/2/2001 14:00 - 14:30 0.50 RUNCO~ COMP 2 BPM, 8PP 250 PSI. PUMP PRESSURE INCREASED A8 S~L ASSEMBLY ENTERED PBR. 8HUT DOWN PUMPS. WORKED SEAL ASSEMBLY IN PBR SEVE~L TIMES. 14:30 - 17:30 3.00 RUNOO~ OOMP DISP~CED IA w/150 deg TREATED SEAWATER. PUMP ~TE 5 BPM, SPP 750 PSI. 110 K UP ~, 55K DOWN. 17:30- 19:00 1.50 BUNCO DPRB COMP A~EMPTEDTO RE-ENTER PBR W/ SEAL A88EMBLY W/ NO SUCCESS, w/ & w/OUT PUMP. A~EMPTED TO REVERSE CIROU~TE, PIPE PLUGGED OFF, PICKED UP & OVERPULL 40K TO 150K, LINED UP & PUMPED LONG WAY, PIPE UNPLUGGED & TUBING FREE. 19:00 - 21:00 2.00 RUNCO[~ DPRB OOMP PICKED UP 1' ABOVE PBR & CIRCUITED ~ HIGH ~TE, 8 BPM, 1,700 PSI 8PP. A~EMPTED TO REVERSE OIROU~TE, PIPE PLUGGED. PICKED UP 10' TO 11' ABOVE PBR, OIROU~TED LONG WAY f/5 MINUTES, LINED UP AND REVERSE CIRCUITED, TUBING STARTED TO PLUG OFF THEN CLEARED. REVERSE CIRCUITED BTMS UP, 7.5 BPM 1,400 PSI. OIRCU~TED UP 1/2 GALLON OF OEMENT. 21:00 - 23:00 2.00 RUNOO~ DPRB COMP S~CKED OFF 2.5' AND A~EMPTED TO REVERSE OIRCU~TE, PIPE PLUGGED OFF. PICKED UP 1'AND OIROU~TED THE LONG WAY ff 5 MINUTES, LINED UP AND REVERSE CIRCUITED ~ 6.5 BPM, 2,200 PSI. PICKED UP OEMENT CHUNK8 WHILE REVERSE OIROU~TING, CEMENT CHUNKS BROKE UP, PRESSURE DROPPED UNTIL PUMPING ~ 8 BPM, 2,000 PSI. CEMENT RETURNS WHEN BOSOM8 UP. CONTINUED TO TAKE 1' - 2' BITES AFTER EACH BOSOM8 UP, REVERSE CIROU~TED ~CH TIME UNTIL RETURNS CLEANED UP. CLEANED TO THE TOP OF THE PBR IN THIS MANNER. 23:00 - 00:00 1.00 RUNCO~ DPRB OOMP LINED UP & CIRCUITED LONG WAY ~ 2 BPM, 300 PS1 SPP. STABBED INTO PBR AND OBSERVED INCREASE IN PRESSURE TO 500 PSI, SHUTDOWN PUMP & OBSERVED PRESSURE HOLDING. OPENED BLEED OFF VALVE AND LEFT OPEN. S~OKED OFF 2' - 3' BEFORE OBSERVING PIPE TAKING WEIGHT. S~OKED OFF TO 30,000~, (25,00~ SET DOWN). PICKED UP & PRESSURED TUBING TO 200 PSI BEFORE PULLING OUT OF PBR. PRESSURE DID NOT BLEED OFF, INDICATION OF PLUGGED TUBING. PRESSURED UP CLEARED PLUG OUT OF TUBING. CIROU~TED LONG WAY f/5 MINUTES AND CLOSED BAG. REVERSE CIRCUITED, OBSERVING PRESSURE INOREASE & SUBSEQUENT DROP OFF & PIPE ~LE. INDICATION OF CEMENT CHUNK COMING UP PIPE. REVERSE CIRCUITED 2x BOSOM8 UP ~ 8 BPM, 2,100 PSI. 12/3/2001 00:00 - 00:30 0.50 RUNOO~ DPRB OOMP HELD PJSM. REVERSE OIROU~TED BOSOM8 UP. OIROU~TED BAOK 8MALL AMOUNT OF OEMENT. PUMP ~TE 7 BPM, 8PP 2,200 PSI. OIROU~TED UNTIL RETURNS OVER SHAKER WERE CLEAN. 00:30 - 04:00 3.50 RUNCOk~ DPRB COMP LINED UP AND PUMPED DOWN TUBING, PUMP ~TE 2 BPM, SPP 300 PSI, 8TABBED INTO TOP OF PBR, PRESSURE INCREASED TO 500 PSI. SHUT DOWN PUMPS, PRESSURE HELD. BLED OFF AND LOWER TUBING Printed: 12/10/2001 11:18:00AM operations SUmmary Report Legal Well Name: Y-24i Common Well Name: Y-24i Spud Date: 11/21/2001 Event Name: WORKOVER Start: 11/22/2001 End: 12/4/2001 Contractor Name: DOYEN Rig Release: 12/4/2001 Rig Name: DOYEN 16 Rig Number: ii~ Date~ ~i~rom~~: Hours 'ActiVity C°de:l NpT:i Phase Description of Operations 12/3/2001 00:30 - 04:00 3.50 RUNCO~I~I DPRB COMP STRING. TUBING STACKED OUT 3' INTO PBR, SET DOWN 25,000#. PICKED UP ABOVE PBR AND REVERSE CIRCULATED BO'I-I'OMS UP @ 8 BPM, 2,100 PSI. FLUID OVER SHAKER WAS CLEAN. CONTINUED TO A-I-I'EMPT TO WORK SEAL ASSEMBLY DEEPER IN PBR w/NO SUCCESS WHILE WAITING ON HOWCO SLICKLINE UNIT. 04:00 - 06:00 2.00 RUNCO~ I~1 DPRB COMP HELD PJSM. R / U HOWCO SLICKLINE EQUIPMENT AND SHEAVES. 06:00 - 07:00 1.00 RUNCO~I DPRB COMP RIH wi SLICKLINE TO LATCH AND PULL DUMMY SLEEVE IN SSSV AT 2,070'. LATCHED UP ON SLEEVE, WEIGHT INDICATOR POD MALFUNCTIONED. 07:00 - 10:30 3.50 RUNCOr~I SFAL COMP WAITED ON PARTS AND CHANGED OUT WEIGHT INDICATOR POD. 10:30 - 11:30 1.00 RUNCON~ DPRB COMP PULLED DUMMY SLEEVE TO SURFACE. 11:30 - 13:30 2.00 RUNCO~I DPRB COMP RIH wi SLICKLINE TO LATCH AND PULL RHC SLEEVE IN X NIPPLE AT 12,460'. COULD NOT LATCH UP ON SLEEVE AFTER SEVERAL ATTEMPTS. POOH w/SLICKLINE AND TOOLS. FOUND PIN ON RETRIEVING TOOL SHEARED. M / U NEW TOOL w/STEEL PIN AND KNUCKLE JOINT. 13:30 - 15:30 2.00 RUNCOI~I DPRB COMP RIH w/SLICKLINE TO LATCH AND PULL RHC SLEEVE IN X NIPPLE AT 12,460'. LATCHED UP ON RHC SLEEVE AND POOH. RECOVERED RHC SLEEVE. 15:30- 17:30 2.00 RUNCOI~IN DPRB COMP RIHw/SLICKLINEAND BAILERTO 12,490'WLM, WORKED THROUGH OBSTRUCTION & TAGGED UP @ 12,512' WIRELINE DEPTH. SLICKLINE APPROXIMATELY 15' DEEPER THAN TUBING DEPTH, 12,512' CORRELATES TO 12,492', PLUGGED AREA IN THE PBR. WORKED BAILER i FOR 30 MINUTES, NO MOVEMENT DOWN, POOH, BAILER CLEAN. 17:30 - 19:30 2.00 RUNCOkl~I DPRB COMP RIH w/SLICKLINE AND 2.5" LEAD IMPRESSION BLOCK. TAGGED UP @ 12,512' WLM, POOH, NO IMPRESSION. 19:30 - 22:00 2.50 RUNCOI~I DPRB COMP RIH w! SLICKLINE AND SET DUMMY SLEEVE IN SSSV AT 2,070'. PRESSURE TESTED CONTROL LINES, OK. POOH w/SLICKLINE, R/D SLICKLINE EQUIPMENT, RELEASED SLICKLINE UNIT. 22:00 - 23:30 1.50 RUNCO~ I~1 DPRB COMP CIRCULATED @ 2 BPM, 300 PSI SPP. SLACKED OFF & ATTEMPTED TO STAB INTO PBR, STACKED OUT @ TOP OF PBR w/5,000# -10,000#. PICKED UP 1' & REVERSE CIRCULATED BOTTOMS UP, CIRCULATED BACK SMALL AMOUNT OF DEBRIS, PUMP RATE 7 BPM, SPP 1,700 PSI. STAGED DOWN 'FO TOP OF PBR & REVERSE CIRCULATED 1-1/2 TUBING VOLUMES, CIRCULATED UNTIL RETURNS OVER SHAKER WERE CLEAN. BLED PRESSURE, OPENED BAG & CIRCULATED LONG WAY, PUMP RATE 2 BPM, SPP 300 PSI. STABBED INTO PBR AND OBSERVED PRESSURE INCREASE. STOPPED AND MARKED PIPE WHERE SEALS HELD WITH PUMP OFF. BLED PRESSURE & SLACKED OFF APPROXIMATELY 2' BEFORE TAKING WEIGHT. STACKED 35,000# - 40,000~ ON OBSTRUCTION, PICKED UP OUT OF PBR & REVERSE CIRCULATED, PUMP RATE 7 BPM, SPP 1,550 PSI, RETURNS OVER SHAKER WERE CLEAN. BLED PRESSURE, OPENED BAG & STABBED INTO PBR. Printed: 12/10/2001 11:18:00AM operations Summary Report Legal Well Name: Y-24i Common Well Name: Y-24i Spud Date: 11/21/2001 Event Name: WORKOVER Start: 11/22/2001 End: 12/4/2001 Contractor Name: DOYON Rig Release: 12/4/2001 Rig Name: DOYON 16 Rig Number: ~ Date From-T° Hours Act!vity G°del NP'I' i phase Description of Operations 12/3/2001 22:00 - 23:30 1.50 RUNCOI~IN DPRB COMP SPUDDED HARD ON OBSTRUCTION w/45,000#, SEAL ASSEMBLY SUCCESSFULLY PUSHED THRU OBSTRUCTION. LOCATED OUT. PICKED UP TO TOP OF PBR & SLACKED OFF, LOCATED OUT WITH NO INDICATION OF OBSTRUCTION. STRING WEIGHT UP 108,000#, STRING WEIGHT DOWN 58,000#. 23:30 - 00:00 0.50 RUNCOI~IN DPRB COMP PRESSURE TESTED TUBING & SEAL ASSEMBLY, TO 3,000 PSI, f/15 MINUTES, OK. LEFT 200 PSI ON TUBING & PULLED OUT OF PBR, STOPPED TUBING WHEN SEALS CLEARED & PRESSURE DUMPED. REVERSE CIRCULATED 2 TUBING VOLUMES, PUMP RATE 7 BPM, SPP 1,500 PSI. SPACED OUT. 12/4/2001 00:00 - 00:30 0.50 RUNCO~!:) COMP HELD PJSM. PRESSURE TESTED SEALS IN PBR TO 3,000 PSI f/15 MINUTES. 00:30 - 01:00 0.50 RUNCOr F' COMP REVERSE CIRCULATED 2 x TUBING VOLUME, PUMP RATE 7 BPM, SPP 1,500 PSI. RETURNS OVER SHAKER CLEAN. 01:00 - 04:00 3.00 RUNCOr~ COMP SPACED OUT TUBING STRING wi 3 PUP JOINTS. M / U TUBING HANGER AND LANDING JOINT. M / U CONTROL LINE TO HANGER AND TESTED TO 5,000 PSI, OK. R / U CIRCULATING HOSE. 04:00 - 05:00 1.00 RUNCOI~!:) COMP HELD PJSM. PRESSURE TESTED LITTLE RED's HOSES AND CONNECTIONS TO 3,000 PSI. OK. HEATED AND PUMPED 150 BBLS OF DIESEL FREEZE PROTECT DQWN IA, PUMP RATE 2 BPM, 500 PSI. 05:00 - 06:30 1.50 RUNCOI~I:' . COMP ALLOWED DIESEL TO U-TUBE FROM IA TO TUBING. SUCKED DIESEL LINES DRY, R / D LITTLE RED. 06:30 - 08:30 2.00 RUNCOI~IN DPRB COMP ATTEMPTED TO STING INTO PBR, NO SUCCESS. RATCHETING MULE SHOE MALFUNCTIONED. 08:30 - 09:00 0.50 RUNCOI~i~I DPRB COMP PULLED TUBING HANGER ABOVE FLOOR. BLED DOWN AND DISCONNECTED CONTROL LINES. SET SLIPS AND ROTATED TUBING STRING 3-1/2 TURNS, LET OUT TORQUE, GOT BACK 1-1/2 TURNS. RECONNECTED CONTROL LINES, TESTED CONTROL LINES TO 5,000 PSI, OK. LOWERED TUBING STRING AND STUNG INTO PBR. LANDED TUBING HANGER. COMPLETION EQUIPMENT SET AT THE FOLLOWING DEPTHS: ITEM LENGTH DEPTH SEAL ASSEMBLY NO-GO .37' 12,487.74' X / O 1.96' 12,485.41' 3-1/2" 9.3# NSCT PUP JT 5.87' 12,479.54' 3-1/2" 9.3~ NSCT x FOX PUP JT 9.33' 12,470.21' 3-1/2" 9.3~ NSCT x FOX PUP JT 9.57' 12,460.64' iX NIPPLE 1.00' : 12,459.64' '3-1/2" 9.3~ NSCT PUP JT 9.78' Printed: 12/10/2001 11:18:00AM Summary Report Legal Well Name: Y-24i Common Well Name: Y-24i Spud Date: 11/21/2001 Event Name: WORKOVER Start: 11/22/2001 End: 12/4/2001 Contractor Name: DOYEN Rig Release: 12/4/2001 Rig Name: DOYEN 16 Rig Number: il~Date: i! From~ iH0urs Activity ~ode' NPT! Phase Description of Operations 12/4/2001 08:30- 09:00 0.50 RUNCOI~IN DPRB COMP 12,449.86' !339 JTS 3-1/2" 9.3# NSCT TBG 10,433.30' 2,016.56' 3-1/2" 9.3# NSCT PUP JT 9.25' 2,007.31' SSSV 3.22' 2,004.09' 3-1/2" 9.3# NSCT PUP JT 9.56' 1,994.53' 61 JTS 3-1/2" 9.3# NSCT TBG 1,921.00' 73.53' 3 PUP JTS 3-1/2" 9.3# NSCT 14.79' 58.74' 1 JT 3-1/2" 9.3~ NSCT TBG 32.03' 26.71' TUBING HANGER 4.01' 22.70' 09:00 - 09:30 0.50 RUNCOI~ COMP RAN IN LOCK DOWN SCREWS. R / U TEST LINES. 09:30 - 11:30 2.00 RUNCOI~ COMP PRESSURE TESTED IA TO 3,000 PSI f/30 MINUTES, OK. BLED DOWN. R / U AND PRESSURE TESTED TUBING TO I 3,500 PSI f/30 MINUTES. OK. BLED DOWN. R / D TEST LINES. 11:30-12:00 0.50 BOPSU P COMP BROKE OUT AND L / D LANDING JOINT. SETTWCIN TUBING HANGER. 12:00 - 16:00 4.00 BOPSUF~ P COMP HELD PJSM. N / D BOP STACK. 16:00 - 18:00 2.00 WHSUR P COMP FMC DRESSED CONTROL LINES, N / U TBG HEAD ADAPTOR, N / U TREE. 18:00 - 19:30 1.50' WHSUR P COMP PRESSURE TESTED TREE TO 3,500 PSI f/30 MIN, FMC ;TEST TBG HEAD ADAPTOR AND NECK SEAL RINGS TO 5,000 PSI f/10 MIN, L/D KELLY AND SWIVEL. 19:30 - 21:00 1.50 WHSUR P COMP PULL TWC, FMC SET BPV, SECURED WELL. RELEASED RIG AT 2100 HOURS 12 / 4 / 2001 Printed: 12/10/2001 11:18:00AM STATE OF ALASKA ALASK~ ,JIL AND GAS CONSERVATION COMN,.oSION 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 99519-6612 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 4. Location of well at surface ,,/ 1349' SNL, 83' EWL, SEC. 34, T11N, R13E, UM At top of productive interval 1747' NSL, 397' EWL, SEC. 04, T10N, R13E, UM At effective depth 1606' NSL, 227' EWL, SEC. 04, T10N, R13E, UM At total depth 1578' NSL, 191' EWL, SEC. 04, T10N, R13E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service RECEIVED JAN 1 1 2001 Alaska 0il & Gas 0ohs. Commission Anchomg¢, 12. Present well condition summary Total depth: measured 13550 feet ~/ true vertical 9207 feet k/ Effective depth: measured 13478 feet true vertical 9151 feet Casing Length Size Structural Conductor 110' Surface 3015' Intermediate 13100' Production Liner 681' Plugs (measured) Junk (measured) 6. Datum Elevation (DF or KB) KBE = 88.85' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number Y-24i 9. Permit Num. ber 186-113 v 10. APl Number ,./" 50- 029-21608-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Fill at 13478' MD; Fish at 13434' MD and Junk at 13342' MD Cemented MD TVD 20" 8 cu yds. Concrete 110' 110' 13-3/8" 4000 cu. ft. Permafrost 3053' 2672' 9-5/8" 575 cu. ft. Class 'G' 13138' 8889' 7" 349 cu. ft. Class'G' 12869'-13550' 8688'-9207' Perforation depth: measured true vertical 13138'- 13153' (Sag River); 13262'- 13364' (5 Intervals Ivishak) 8889' - 8900' (Sag River); 8984' - 9063' (5 Intervals Ivishak) Tubing (size, grade, and measured depth) 3-1/2", L-80 EUE 8RD Mod Tubing to 12795' with 2-7/8" tailpipe to 12927' Packers and SSSV (type and measured depth) 9-5/8" TIW Packer at 12795'; 3-1/2" SSSV Landing Nipple at 2252'. 13. A~achments [] Description Summary of Proposal 4. Estimated date for commencing operation January 24, 2001 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Barbara Holt, 564-5791 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: []Oil [] Gas [] Suspended Service Produced Water Injector Prepared By Name/Number: Sondra Stewman, 564-4750 17. I hereby ce~.'fy that the foregoing is~true end correct to the best of my knowledge S,~.~,.: ../~'ZZ ¢~'b/c ' - .,/ ir:,, ....... n.:uin,-:l: ..... "r i i i :~i: f:-'i;:i: i: ; i ~i: : CommiSSion :Use Only Conditions of Approval: Notify Commission so representative ma,y, fitness Plug integrity__ BOP Test"~ Location clearance Mechanical Integrity Test .. }i:;JGii'-'4AL :SIGi''ii--C' .-,v Approved by order of the Commission Date IApproval No. ,.~O[ - E.bO~ Commissioner Date ~///¢,~,/-~/~// Submit In Triplicate lIP AI. ASKiI DRILLING &WELI. S RECEIVED JAN 1 1 ZOO1 Alaska Oil & Gas Cons. Commission Ancflorage To: From: Date: Subject: PBU Well Operations Team Leaders Barbara M. Holt PBU WO Engr. Ph: 564-5791, Cell: 240-8044 January 9, 2001 Y-24 Pre Rig Memo and RWO Summary AFE 4P9061 This procedure outlines the pre-rig operation for the Y-24 Rig Workover. The scope includes replacing the existing 3 Y2" L-80 completion and replacing it with 3 1/2" L-80 tubing and a 7" tieback string back to surface to isolate the leaking 9 5/8" casing. A leak detection log was run on 5/12/00 and identified 3 leaks in the tubing: 10700', 9320', and 5350' MD. A leak was also found in the casing at 3600'. A Kinley caliper survey in 7/98 shows the tubing to be in poor mechanical condition with an almost continuous line of corrosion between joints #1 and #239. The deepest body penetration recorded was 62% wall loss. A cement packer squeeze was performed in 1996 to repair a leaking TIW packer. The estimated workover start date is January 2001. Last Test Max Deviation Perforation Deviation 42° at 13100' to 39° at 13400' Minimum ID Last TD Tag Last Down hole Ops Latest H2S value NOTES Last injection -2000 bwpd at 1000 psi in 1998 58° at 6900'MD 2.313" at 12860' and 12893' (Otis 'X' nipples) 13434' 3/27/00 - set plug at 12723' in ss 5/12/00- Leak Detect NA for injectors Pad Engineer is John Petty (564-5893 wk. or 243-0944 hm.) Planned Pre-Ri~7 Work O 1. Test the 9 5/8" mandrel packoff and tubing hanger (through test port) to 5000 psi. If the 9 5/8" packoff tests, completely back out and check each 9-5/8" and 5-1/2" lock down screw for breakage (check one at a time). If tested recently, e-mail or fax in test report. S 2. Drift 3-1/2" tubing to 12900'. S 3. Pull bottom Gas lift valve. Circulate to seawater. E 4. Run cement bond log to determine cement top behind 3-1/2" tubing. E 5. Set an IBP just below the sliding sleeve at 12650' MD. Top with 50' of carbolite for barrier. E 6. Chemical cut 3-1/2" tubing 100 ft above top of cement. O 7. Set a BPV in preparation of the rig move. Assure annuli are freeze protected. Ri.q Workover Procedure 1. MIRU. ND tree, NU and test BOPE. Circulate out freeze protect fluid and circulate well to clean seawater. 2. Latch tubing and POH. LD 3-1/2" tubing string to chemical cut. 3. RIH w/3-1/2" overshot assembly and 9-5/8" test packer. Locate 9-5/8" casing leak and confirm swallowing the cut 3-1/2" stub with the overshot assembly. 4. RIH with the 3 1/2" seal bore and 9 5/8" x 3 1~,, production packer on drill pipe. Set the packer. . . 9. 10. 11. 12. RU slickline and drift the stub. RIH with the 4000' 7" 26 #/ft scab liner assembly (1000' of CR-13 across 9-5/8" leak interval). Circulate corrosion inhibitor between 7" and 9-5/8" casing. Set the bottom 7" x 9-5/8" packer. Pull tension. Set the top 7" x 9 5/8" packer. Test to 3000 psi. Run new 3-1/2" L-80 completion with 3 1/2" x 1" GLMs and 3 ½" seal assembly. Stab into seal bore and test to 3000 psi for 10 minutes. Circulate corrosion inhibitor. Freeze protect to below permafrost. Continue testing to 3000 psi for 30 minutes. Set BPV, ND BOPE, NU and test tree. Tree is carbon steel. RDMO. Post Riq Procedure 1. Install flow line and Reset wellhouse. 2. RU slickline and retrieve RHC sleeve. 3. Run live gas lift valves. RECEIVED JAN J_ J. 2001 Alaska Oil & Gas Co~s. Commission, Anchorage Barbara M. Holt Drilling Engineer cc: Well File TREE: 3" McEVOY WELLHEAD: McEVOY ACTUATOR: OTIS NEEDS SMALL OTIS FUSIBLE CAP CMT'd 13 318", 72#/ft, L-80, BTRS KOP: 600' MAX ANGLE: 58° @ 6900' 3 1/2", 9.3#/ft, L-80, EUE 8RD MOD TUBING TUBING ID: 2.992" CAPACITY: 0.0087 BBL/FT Packer Repair Squeeze Top of Cement at 12700' Y-24 KB. ELEV = 88.85' BF. ELEV = 51.35' SSSV LANDING NIPPLE I (OTIS)(2.750" ID) 2252' GAS LIFT MANDRELS ( OTIS w/RA LATCH) N°I MD(BKB) TVDss I DEV 9 I 3579' I 2903, 153° 2I 12,332'I 8210' 145° 3 1/2" SLIDING SLEEVE (OTIS) (2.750" ID) 112,743' Top of cement plug placed inside tubing was 12844' CTMD TOP OF 112,869' [ 7" LINER 95/8"'47#/ft' I 1 38' J L-80, BTRS 3~'1 Packer Repair Squeeze ~' Bottom of Cement Sheath at 12905' CTMD. Hole drilled 2.28" dia. ~ 9-5/8" PACKER (TIW)( "ID) I 12,795' 2 7/8", 6.5#/ft, L-80 TAILPIPE 2 7/8" "X" NIPPLE (OTIS) (2.313" ID) '12,860' 2 7/8" "X" NIPPLE (OTIS) (2.313" ID) '12,893' 2 7/8" TBS TAIL 1'12'927' I (BOT SOS) (ELMD) I 12,896' MARKER JOINT I 13,200' I PERFORATION SUMMARY REF LOG: SWS- BHCS 7-12-86 INTERVAL :DPEN/SQZ'D 13,138- 13,153' 13,262- 13,364' OPEN OPEN RESTRICTION: Approx 3.5" I.D. restriction seen on inj. survey 5/31/96 13,340'- 13,352' PBTD 1'13,508' I ~ 7",26#/ff, L-80, TC4S 113,550' J -- i DATE ~ REV. BY I 7-17-86 6-9-89 A. REED 5/20/96 ] PPA ! 5/31/96 I RLV COMMENTS INITIAL COMPLETION PUT ON MAC Packer repair sqz added Restriction JUNK: 2 1/8" x 8"L PERF GUN BULLNOSE & CENTRALIZER BOW SPRINGS AT 13,342'. FISH: 34'X 2 1/8" PERF GUN & CCL. TOP AT 13,434'. LOST ON1-1-87. PRUDHOEBAYUNIT WELL: Y-24 (13-04-10-13) APl NO: 50-029-21608 SEC 34; TN 11N; RGE 13E BP Exploration (Alaska) BPX Prudhoe Bay Y-24i Rig Workover Post on Rig Floor Brine Program: · Workover fluid: 8.5 ppg brine (Brine wt plus diesel cap) Disposal: · No annular injection on this well. · All used completion fluids and all other Class II wastes will go to Grind & Inject. Tubing Program: · The scope includes replacing the existing 3 %" L-80 completion and replacing it with 3 %" L-80 tubing and a 7" tieback string back to surface to isolate the leaking 9 5/8" casing. Well Control: · BOP diagram (Nabors 4ES stack on file) · Pipe rams, blind rams tested to 300 psi and to 3500 psi. · The annular preventor will be tested to 300 psi and 3500 psi. Hazards · Latest H2S value: 60 ppm (Injection gas concentration) · Surface Offset well H2S readings o Y-29 11/5/00 10ppm o Y-20 No data in database (shouldn't be more than 10 either) Reservoir Pressure Reservoir pressure is estimated to be 3512 psi at 8800 TVD with 7.7-ppg fluid. Maximum surface pressure with gas (0.10 psi/fi) to surface is 2632 psi. MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATER/AL IS PAGE HOWARD Attn. ALASK~A OTL + G~S 3001 PORCUPINE DRIVE ~CHO~GE AK, 99501. Date: 7 June 1996 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam~ Enclosed,D~ease .... zznc the dana as described below: WELL ~~S~R~P~ION FINAL BL+RF ! PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 GR/CCL FINAL BL+RF ! PLS FINAL BL+RF 1 PLS FINAL BL+RF 1PLS FINAL BL+RF 1 PDK FINAL BL+RF Run ~ 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 2189.06 2597.04 4952.04 5770.05 6084.05 6168.04 6624.04 6689.00 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services ~ B ~reet Suite 201 Anchora. ge, D~K 99518 ~¢~t/ Or F~/~,X//t~ (/907) 563-7803 :. ~ Date: JUN 2 1 ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501° USA Date: 23 April 1994 RE: Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION '~ ~ I'~ M-03 (43-02-11-12) 1 PLS INJ. FINAL BL /d~PLS INJ. RF SEPIA i~PLS INJPROF.FINAL BL ~1 PLS INJPROF.RF SEPIA LPLS INJ. FINAL BL //1PLS INJ. RF SEPIA ~/ PLS INJPROF.FINAL BL /1 PLS INJPROF.RF SEPIA ~-~lyd~ ~<-03 (31-04-11-14) 1CN/GR FINAL BL ~/CN/GR FINAL RF SEPIA 1 CN/GR FINAL BL ~CN/GR FINAL RF SEPIA 9~-'~-5 H-32 (42-20-11-13) w-os (12-26-11-12) 1 PFC/PERF FINAL BL 1 PFC/JEW-L FINAL BL /~ PFC/PERF RF SEPIA ~ PFC/JEWL RF SEPIA 1 CCL/PATCH FINAL BL '~ CCL/PATCH RF SEPIA 1 PFC/PERF FINAL BL /i PFC/PERF RF SEPIA %G-~O c-38 (41-18-11-14) i2.--ic~, R-34 (13-34-12-13) 1PFC/GR/CCL FINAL BL /r~PFC/GR/CCL RF SEPIA 1 PFC/PERF FINAL BL z--'l PFC/PERF RF SEPIA ECC No. Run # 1 4742.02 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 2597.02 4123.01 Run ~ 1 5971.01 Run # 1 Run # 1 6183.00 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 585.04 6170.02 5752.01 5607.03 5785.03 6083.04 Cont/ G-14 (12-12-11-13) 1 PFC/GR/CCL FINAL BL Run # 1 5653.05 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: · Date: Please sign and return to: Sonya Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: RECEIVED APR 2 9 I~,94 .41aska Oil & ~'as Cons. Commission Anchorage '~ STATE OFALASKA 0 R I '~'J~ ,~ JL ~.~ SKA OIL AND GAS CONSERVATION COMM~ .~N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing Repair well__ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance.__ Perforate __ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1349' SNL, 83' EWL, SEC. 34, T11N, R13E, UPM At top of productive interval 1750'NSL, 413'EWL, SEC. 04, TION, R13E, UPM (Sag R) At effective depth 1600' NSL, 343' EWL, SEC. 04, TI ON, T13E, UPM At total depth 1582' NSL, 208' EWL, SEC. 04, TION, R13E, UPM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X 12. Present well condition summary Total depth: measured true vertical 13550 feet BKB 9207 feet Effective depth: measured 13478 feet true vertical BKB 9151 feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) KBE = 88.85 AMSL feet 7, Unit or Property name Prudhoe Bay Unit 8. Well number Y-24 (13-04-10-13) PBU 9. Permit number 86-113 10. APl number 50- 029-21608 11. Field/Pool Prudhoe Oil Pool fill at 13478' MD (02/89) Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 110 20 8 c.y. 148 148 Surface 3015 13 3/8 4000 c.f. 3053 2672 Intermediate 13100 9 5/8 575 c.f. 13138 8889 Production -- Liner 681 7 349 c.f. 12869-13550 8688-9207 .Perforation depth: measured 13138'-13153' (Sag R) 13262'- 13364' (Ivishak) true vertical subsea R'E CEIVED Tubing (size, grade, and measured depth) 3 1/2"L-80 EUE to 12795'with 2 7/8"tai/pipe to 12926' ~..j'~',~ I 7 ~39~ Packers and SSSV (type and measured depth) 9 5/8" TIWpacker at 12795'; 3 1/2" SSSVat 2252' A~asi<a 0JJ & GaS C01'IS. C0tlltl!.i$~- Anchorage 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch X 14. Estimated date for commencing operation December 31,1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service Produced Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~C/~/,~ Title Supervisor Waterflood/Miscible Flood FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness BOP. Test __ Plug integrity Test ~/~5-'--. Mechanical Integrity Approved by order of the Commission Form 10-403 Rev 06/15/88 Date Location clearance Subsequent form required 10-~=~."" . ir' tF I Approval ~.2 - ~ No. ., ;"'..':~,/:~ Commissioner' Date ~--(~/--~',~ SUBMIT IN TRIPLICATE WELL Y-24 (13-04-10-13) Injection Pr0po~lll Well Y-24 was converted from a Prudhoe Bay prodution well into a water injection well for Hurl State Development Zone 4 on December 31, 1991. Perforations at 4 's.p.f., 90 phasing and oriented at 60 from the low side of the hole over the following intervals. Interval (MD) 13138'- 13153' 13262'- 13364' 4/09/92 fjh BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP CASED HOLE FINALS DATE: 04/16/92 T# 83419 Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. s-03 Y-10 8!'~GAS LIFT SURVEY 03/22/92 #1 INJ 03/23/92 #1 Y-24~-1/3 INJ 03/25/92 #1 D-27 ~-$3 PROD-F 04/01/92 #1 Z-07fO--~2GAS LIFT SURVEY 03/25/92 #1 a-16~-fZ~ MISC GAS INJ 03/31/92 #1 A-03g/-3~ MISC GAS INJ 03/31/92 #1 F-37~--~_ LEAK DET 03/19/92 #1 N-11~'/Z~ GAS LIFT SURVEY 03/20/92 #1 F-48 ~/--~ TEMP 03/22/92 #1 U-02~'/~GAS LIFT SURVEY 03/20/92 #1 Y-27~~'~ INJ 03/23/92 #1 S-32~-/g~ PITS 03/24/92 #1 S-0~Z-~/ GAS LIFT SURVEY 03/22/92 #1 A-11 ~l_~ MISC GAS INJ 03/26/92 #1 2500.00-12104.00 CAMCO 2 " 9200.00-10123.00 CAMCO 5 " 13100.00-13430.00 CAMCO 5 " 9350.00- 9644.00 CAMCO 5 " 2500.00-12738.00 CAMCO 2 " 10520.00-11084.00 CAMCO 5 " 11600.00-11915.00 CAMCO 5 " 8600.00-10400.00 CAMCO 2 " 2500.00-10200.00 CAMCO 2/5" 0.00- 3000.00 CAMCO 5 " 2500.00- 9920.00 CAMCO 2 " 12900.00-13247.00 CAMCO 5 " 10100.00-10548.00 CAMCO 5 " 2500.00-10674.00 CAMCO 2 " 9750.00-10050.00 CAMCO 5 " Information Control Well Records Adrian J. Martin RECEIVED APR 2 4 199 . Alaska 0ii & Sas Cons. Commission Anchorage STATE OF ALASKA AL. .-:;A OIL AND GAS CONSERVATION COMMIS,._ ,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator BP Exploration (Alaska)/nc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1349' SNL, 83' EWL, SEC. 34, T11N, R13E, UPM At top of productive interval 1750' NSL, 413' EWL, SEC. 04, TION, R13E, UPM (Sag R) At effective depth 1600' NSL, 343' EWL, SEC. 04, TI ON, T13E, UPM At total depth 1582' NSL, 208' EWL, SEC. 04, TI ON, R13E, UPM 5. Type of Well: Development Exploratory Stratigraphic Service X 6. Datum elevation (DF or KB) KBE = 88.85 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Y-24 (13-04-10-13) PBU 9. Permit number/approval number 86-113/9-092 10. APl number 50- 029-21608 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13550feet BKB 9207feet 13478feet BKB 9151feet Plugs (measured) Junk (measured) fill at 13478' MD (02/89) Casing Length Size Cemented Measured depth Structural -- Conductor 110 20 8 c.y. 148 S u rface 3015 13 3/8 4000 c.f. 3053 Intermediate 13100 9 5/8 575 c.f. 13138 Production -- Liner 681 7 349 c.f. 12869-13550 Perforation depth: measured 13138'- 13153' (Sag R) 13262'- 13364' (Ivishak) True vertical depth BKB 148 2672 8889 8688-9207 true vertical subsea Tubing (size. grade, and measured depth) 3 1/2" L-80 EUE to 12795' with 2 7/8" tailpipe to 12926' Packers and SSSV (type and measured depth) 95/8" TlWpacker at 12795';31/2" SSSV at 2252'R ~ C EIVEO 13. Stimulation or cement squeeze summary 12/31/91 Convert well to water injection. Intervals treated (measured) Treatment description including volumes used and final pressure Alaska 0ii & Gas Cons. 6omm'~ss'~o~ Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 22O 264 4O 85O N/A N/A N/A N/A Tubing Pressure 230 N/A 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended ServicePrcduced Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed - Title Supervisor Waterflood/Miscible Flood Form 10-404 Rev 06/15/88/ Date SUBMIT IN DUPLICATE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 /' // DATE: 01/03/92 T# 83152 BP CASED HOLE FINALS Enclosed is your copy of the materials listed questions, please contact BP Well Records at 12/08/91 #1 GAS LIFT SURVEY PITS PROD-F INJ INJ CCL INJ Y-34,// LIFT SURVEY B-1 --3 ~ ~~,J, TEMP 8~'Z~ Z-32 ~/~ TE~ e,-I~& P-15 ~ ~ PROD-F ~r'~ N-21J % CL ~l~e S-03V~ TEMP ~*'r~ W-16~ ~. PROD-F qt-~6 Y-31~~ GAS LIFT SURVEY ~-~ Y-153~ GAS LIFT SURVEY ~.)~~ · GAS ENTRY 5 " ~/~%-20 ~ GAS ENTR~ G~S ENTRY 5 12/07/91 #1 12/07/91 #1 12/09/91 #1 12/04/91 #1 12/08/91 #1 12/06/91 #1 12/07/91 #1 12/09/91 #1 12/08/91 #1 11/08/91 #1 11/05/91 #1 11/09/91 #1 11/06/91 #1 12/06/91 #1 11/21/91 #1 11/24/91 #1 11/24/91 #1 12/08/91 12/05/91 12/05/91 Information Control Well Records Adrian J. Martin below. If you have any (907) 564-4004. 2000.00-11539 9450.00- 9710 9150.00- 9520 10586.00-10935 9800.00-10080 8758.00-10259 9350.00- 9850 100.00- 9130 10500.00-10867 12850.00-13445.00 10000.00-11010.00 9900.00-11038 12000.00-12337 9750.00-11270 11095.00-12076 5300.00-11200 0.00- 2840 0.00- 9860 #1 9950 · 00 CAMCO 2/5" · 00 CAMCO 5 " · 00 CAMCO 5 " · 00 CAMCO 5 " · 00 CAMCO 5 " · 00 CAMCO 5 " · 00 CAMCO 5 " · 00 CAMCO 2 " · 00 CAMCO 5 " CAMCO 5 " CAMCO 5 " .00 CAMCO 5 " .00 CAMCO 5 " · 00 CAMCO 5 " · 00 CAMCO 5 " · 00 CAMCO 5 " · 00 CAMCO 2/5" · 00 CAMCO 2 " · 00-10240.00 CAMCO #1 11100.00-11450.00 CAMCO #1 9850.00-10200.00 CAMCO RECEIVED JAN 0 8 1992 Alaska 011 & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 21, 1989 klaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 kttention: Mr. C. V. Chatterton Well Y-24 (13-04-10-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. Yours very truly, /' B. J. Policky Supervisor Waterflood & Miscible Flood BJP:JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown .. Pull tubing Alter casing "2. Name of Operator BP Exploration (Alaska) Inc. ~. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Stimulate Plugging Repair well 5. Type of Well: Development ~ Exploratory Stratigraphic Service 13550feet BKB 9207feet 4. Location of well at surface 1349'SNL, 83' EWL, SEC. 34, T11N, R13E, UPM At top of productive interval 1750'NSL, 413'EWL, SEC. 04, TION, R13E, UPM (Sag R) At effective depth 1600' NSL, 343' EWL, SEC. 04, TION, T13E, UPM At total depth 1582' NSL, 208' EWL, SEC. 04, TION, R13E, UPM 12. Present well condition summary Total depth: measured true vertical Perforate X Other 6. Datum elevation (DF or KB) KBE = 88.85 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Y-24 (13-04-10-13) PBU 9. Per,mit number/approval number 86-113 / 9-092 10. APl number 50- 029-21608 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 13478feet true vertical BKB 9151feet Junk (measured) fill at 13478'MD (02/89) Casing Length Size Structural -- Conductor 110 20 Surface 3015 13 3/8 Intermediate 13100 9 5/8 Production -- Liner 681 7 Perforation depth: measured 13138'- 13153' (Sag R) 13262' 13364' (Ivishak) true vertical Cemented Measured depth 8 c.y. 148 4000 c.f. 3053 575 c.f. 13138 349 c.f. 12869-13550 subsea 8800'-8811' (Sag R) 8894'- 8974' (Ivishak) Tubing (size, grade, and measured depth) 3 1/2" L-80 EUE to 12795' with 2 7/8" tailpipe to 12926' True vertical depth BKB 148 2672 8889 8688-9207 Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 12795'; 3 1/2" SSSV at 2252' 13. Stimulation or cement squeeze summary Intervals treated (measured) see attachment 14. Treatment description including volumes used and final pressure .. ~/aS~,~3,0il &' Gas Col~ Fleoresentative Daily Average Production or In!~ion D~t~ "~ ~l¢I'10ra[itj"' OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 500 2342 13 1169 209 520 2188 14 1287 217 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended.. Service 17, I hereby certify that the foregoi, p~ is ~ue and correct to the best of my knowledge. Signed ~ .~'~'~-z~--~ Title Supervisor Waterflood/Miscible Flood Form 10-404 Rev 06/15/88 " SUBMIT IN DUF~ICATE WELL Y-24 (13-04-10-13) P]3U ADD'L. PERFORATION OPERATIONS The following intervals were perforated February 19, 1989 using Schlumberger 2 1/8" carrier guns: Add Sag perf @ 6 spf: 13138'- 13153' MD BKB (8800' - 8811' TVDss) Repeff Ivishak @ 4 spf: 13332'- 13364' MD BKB (8949'-8974' TVDss) All depths are referenced to BHCS, 7/12/86. A lubricator was installed and tested to 3500 psi for all well work. The well was returned to production immediately following perforating operations, then tested. jm 3/15/89 ;laska. it &' Cons. co . BP EXPLORATION HOUSTON ARCO CHEVRON E~TON TEXACO ; MOBIL PHILLIPS STATE OF ALASKA GEOSC IENCES BP Exploration (Alaska) Inc. 900 East Benson 8ouievard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907} 561-5111 INDEXED Date: 02-22-89 79838 RESF~KVOIR REFERENCE: AIIC~-IVES ~ cis~ ~o~?. ~r~An ~OGS The following material Is being submit-~,ed herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: C-12 ' PROD-F #1 11300-11985 02-16-89 Sch 5" .X-06 I PERF #2 11960-12308 02-17-89 Sch 5" X-'10 PROD-F #1 10400-10960 02-13-89 Sch 5" X-26 PERF #1 8900-9400 02-19-89 Sch 5" Y-24 Completion #1 12700- 02-18-89 Sch 5" Received Date Shirley R. McCurry INFORMAT I ON CONTROL Wel I Reccrds LR2-1 Standard Alaska Production Company 900 East Benson Boulevard. P.O. Box 196612 Anchorage, Alaska ~99519-6612 (907) 561-5111 February 1, 1989 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well Y-24 (13-04-10-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. Yours very truly, B. J. P~licky; S~ervisor Waterflood & Miscible Flood BJP:JAM Enclosures (9) L. Burke (MB12-1) Well File A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. .Oil & Gas Cons. '~' .,- .... ' · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well .__ Alter casing ~ Repair well ~ Plugging ~ Time extension Stimulate __ Change approved program ~ Pull tubing ~ Variance ~ Perforate. X Othe~ 2. Name of Operator Standard Alaska Production Company 3. Address P. O, Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1349'SNL, 83'EWL, SEC. 34, T11N, R13E, UPM At top of productive interval 1695' NSL, 350' EWL, SEC. 04, TION, R13E, UPM At effective depth 1674' NSL, 324' EWL, SEC. 04, TION, T13E, UPM At total depth 1582' NSL, 208' EWL, SEC. 04, TION, R13E, UPM 5. Type of Well: Development x Exploratory ~ Stratigraphic ~ Service Datum elevation (DF or KB) KBE--88.85 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Y-24 (13-04-10-13) PBU 9. Permit number 86-113 10. APl number 50- 029-21608 11. Field/Pool Prudhoe Oil Pool 12, Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13550 feet BKB 9207 feet 13338 feet BKB 9043 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural -- Conductor 110 20 8 c.y, Surface 3015 13 3/8 4000 c.f. Intermediate 13100 9 5/8 575 c.f. Production -- Liner 681 7 349 c,f. Perforation depth: measured 13262'- 13332' true vertical subsea 8894'- 8949' fill at 13338'MD (09/88) Measured depth True verticalde~h BKB 148 148 3053 2672 13138 8889 Tubing (size, grade, and measured depth) 3 1/2" L-80 EUE to 12795' with 2 7/8" tailpipe to 12926' Packers and SSSV (type and measured depth) 9 5/8" TIWpacker at 12795'; 3 1/2" SSSV at 2252' 12869-13550 8688-9207 Sqzd: 13332'-13364' ~ao:-~,_: Oil & Gas Cons. ' gr~chora~e 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation February 1989 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 for .e~:~in_cl is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Mechanical Integrity Test Approved by order of the Commissio~ Form 10-403 Rev 06/15/88 Commissioner Approved Uopy Returned Date//~?/~ ?- .WELL Y-24 (13-04-10-13) PBU ADDtL. PERFORATION PROPOSAL We propose to perforate the following Sag River interval during February 1989: 13128'- 13153' MD BKB (Ref. BHCS, 7/12/86) A lubricator will be installed and tested to 3500 psi for all well work. The well will be returned to production immediately following perforating operations, then tested. jm 1/30/89 FLOW TUBES & PACKOFF BOWEN PACKOFF I-.,- HAND GREASE SEAL FLOWTUBE PUMP FLOWLINE VALVE FLOWLINE GREASE LINE GREASE 'MANIFOLD GREASE PUMP RISER -..,,-GREASE RESERVOIR ,/ B OP Standard Alaska Production Company. 900 Eas~ I~n~on Boule P.O. Boz 196612 Anchorage. Alaska 99.519.661~ {907) 564-51 I I INDEXED HOUSTON ,~co STANDARD CHEVKON ALASKA PRODUCTION EIQiON Date: 01/25/89 TEXAC 0 7 9 7 6 9 TO: T~: MOBIL pHILLIPS STATE OF ALASKA AKCHIVES REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: G-11 Statia Gradient 01/08/89 Camco M- 04 Static Gradient 01 / 16 / 89 Camco N- 15 Sta~ic Gradient 01 / 16 / 89 Camco N- 1 9 Static Gradient 01/I 4/89 Camco R- 1 3 Sta~ic Gradient 01 / 15 / 89 Camco S- 08 Static Gradient 01 / 15 / 89 Camco W- 01 Flowing Gradient 01/I 0/89 Camco W- 20 Flowing Gradient 12 / 28 / 88 Camco W-27 Sta~ic Gradient 01/I 3/89 Camco W- 34 Flowing Gradient 12/21/88 Camco W- 39 Static Gradient 01 / 09 / 89 Camco Y-24 Sta~c Gradient 01/17/89 Camco Y-25 Static Gradient 12/30/88 Camco Z- 20 Static Gradient 12 / 30 / 88 Camco Alastm Oil & C~.~s Co~. Ccmmissio~ Rece I ved Date A unit of Ihe o¢,gmn~l $,ondord Od Company Founded ,n Clevelond. 0~,,o. in 1870 Jennifer Dietz INFORMATION CONTROL Wel I Records LR2-1 Stc~ndard Alaskc~ Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION November 21, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well Y-24 (13-04-10-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of performing a cement squeeze and reperforation of the well. Yours very truly, JAB:JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Y-24 Well File A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate . Plugging Perforate Pull tubing Alter casing. Repair well Other X 2. Name of Operator Standard Alaska Product/on Company ~1. Acl'dres;s ' ' ' P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1349' SNL, 83' EWL, SEC. 34, T11N, R13E, UPM At top of productive interval 1695' NSL, 350' EWL, SEC. 04, TION, R13E, UPM At effective depth 1674' NSL, 324' EWL, SEC. 04, TION, T13E, UPM At total depth 1582'NSL, 208'EWL, SEC. 04, TION, R13E, UPM , 12. Present well condition Summary Total depth: 5. Type of Well: Development Exploratory Stra~graphic. Service 6. Datum elevation (DF or KB) KBE = 88.85 AMSL feet '7. unit Or Property name ' Prudhoe Bay Unit 8. Well number Y-24 (13-04-10-13) PBU 9. Permit number/approval number 86-113 / 7-590 num~e'r.., ' . . 10. APl 50- 029-21608 11. Field/Pool Prudhoe Oil Pool measured 13550feet true vertical BKB 9207feet Plugs (measured) Effective depth: measured 13338feet true vertical BKB 9043feet Junk (measured) fill at 13338'MD (09/88) Casing Length Size Cemented Structural -- Conductor 110 20 8 c.y. Surface 3015 13 3/8 4000 c.f. I nte rm ed late 13100 9 5/8 575 c.f. Production -- Liner 681 7 349 c.f. Perforation depth: measured 13262'- 13272' Measured depth True vertical depth BKB 148 148 3053 2672 13138 8889 12869-13550 8688-9207 Sqzd: 13272'-13364' true vertical subsea 8894'- 89O3' Tubing (size, grade, and measured depth) 3 1/2" L-80 EUE to 12795' with 2 7/8" tailpipe to 12926' Packers and SSSV (type and measured depth) 95/8" TlW packer at 12795,; 3 1/2" SSS V at 2252' 13.' Stimulation or cement squeez~ summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 360 306 673 1666 213 Subsequent to operation 1'5. Attachments ..... Copies of Logs and Surveys run Dally Report of Well Operations X 54O 3O6 46 1177 16. Status of well classification as: Oil X Gas . _ Suspended Service 212 17. I hereby certify that the fore/~oi.~is true and correct to the best of my knowledge. Signed (~~~~ =~~.~~ Title Mana~7erProductionEn. gi. neerin~7 Form lf¢4 Rev 06/~ 5/88 ~/'~ SUBMIT IN DUPLICATE WELL Y-24 (13-04-10-13~ PBU CTU CEMENT SOUEEZE/HYDRAULIC FRAC OPERATIONS A coiled tubing cement squeeze of existing perforations was performed as detailed below: 10/2/87 Rigged up coiled tubing unit and pressure tested BOP's to 4000 psi. Performed mud acid perforation wash and sump cleanout. 10/5/87 Performed a cement squeeze on existing perforations. Contaminated cement; WOC 10/7/88 Reversed out contaminated cement and tested squeeze. 10/24/87 Reperforated the following interval using Schlumberger 2 1/8" Hyperdome carrier guns at 4 spf: 13262' - 13364' MD BKB Returned the well to production; well would not flow 11/23/87 Reperforated the above interval using Dresser Atlas 2" NCF Jumbojet III guns at 4 spf. Would not sustain flow. 11/26/87 Performed a perforation acid wash; would not sustain flow. 3/11/88 Performed a tubing/perforation acid wash. Returned well to production and tested. Performed resqueeze to eliminate a channel below the perforations. Reperforated the following interval using Schlumberger 2 1/8" carrier guns at 4 spf. 13262' - 13272' MD BKB Attempted to return well to production; would not flow. Reperforated the following interval using Schlumberger 2 1/8" carrier guns at 4 spf: 13262' - 13332' MD BKB Returned well to production and tested. 3/26/88 4/24/88 9/10/88 jm 11/3/88 .S la r, da*'d Alas, La P~ o4JuC lion Company' ~ [01.1 J~"n%On J~.OuJe.o. (9071 S64.S I I I I NOEXED TO: HOUSTON ARCO CHEVRON E~XON TEXACO MOBIL PHILLIPS STATE OF ALASKA ARCHIVES STANDARD x\L ASKA PRODLJC'T ION Date: 10-28-88 Ti: 79476 REFERENCE: SAPC FINAL 'DATA - PRESSURE SURVEY DATA The following material Is being submitted herevlth. Please acknowledge receipt by signing a copy of thls letter and returning it to fhls office: W-38 Pressure Buildup 10-09-88 Gearhart A-21 Static Gradient 10-17-88 Camco B-07 Static Gradient I0-15-88 Camco B-23 Static Gradient 10-12-88 Camco E-15 Static. Gradient 10-14-88 Camco E-28 Static' Gradient 10-14-88 Camco F-13 Static Gradient 10-12-88 Camco ~ Static Gradient 10-17-88 Camc~ J-26 Static Gradient 10-16-88 Camce,-- K-11 Static Gradient 10-15-88 Camco M-03 Static Gradient 10-18-88 Camco M-10 Static Gradient 10-18-88 Camco M-11 Static Gradient 10-18-88 Camco S-15 Static Gradient 10-19-88 Camco S-19 Static Gradient 10-19-88 Camco W-35 Static Gradient 10-20-88 Camco Y-14 Static Gradient 10-14-88 Camco Y-24 Static Gradient 10-17-88 Camco Y-24 Static Gradient 10-20-88 Camco Rote I ved Shirley R. McCurry II',IFOR,U.~T I ON CONTROL We I I Records LR2- I founded ,n Cle-elond. Cl~;o. ,n 18)'0 Produ¢lion Compa. 900 [:o,,1 8enson Boule.o~d PO ~. 196612 An(ho~oge. Ah~o 99519061~ ~907'. 564 511 t INDEXED HOUSTON ARCO CHEVRON EXXON TEXACO TO: FIOBIL T#: 79300 PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR STANDARD AI_A.q,/..A. i~P''-) )i :~. Date: 09/14/88 REFERENCE- ARCHIVES SAPC CASED HOLE FINAL LOGS The fei lowing material is being submitted herewith. Please acknowledge receipt by signing a copy of this fetter and returning it to this office: W-17 CET 09/10/88 #1 11050-11917 Sch W-17 CBT 09/10/88 #1 11050-11890 Sch 5" W-17 Perf-R 09/10/88 #1 11096-11870 Sch 5" Y-24 Perf-R 09/08/88 #1 12650-13314 Sch 5" Race i red Da te A un,I of Ibc Or,~,nOI ~u~do,d C),I (o,-,;~,~,,r Jennifer Dietz [NF0~MAIION CONIRCR_ Wel I Records LR?-I INOEXED TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA ARCHIVES STANDARD ALASKA PRODUCTION 06/08/88 Date: 78928 TI: REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returnlng It to this office: Y-20 Y-24 Pulse Test 05/23/88 Camco Pulse Test 05/23/06/01/88 Camco Rece i JUt',.! i 3 igii ,~,aska C;:,i & O:~:c Cons. gqmmission Anchorage A u,,~,, of I'he o,,g,--ol ,~l'o,',do,d C)d re"hr/cd '" Cle--Io",t 0',,o ,r, 1870 Jennifer Dietz I NF(])RMAT I ON CONTROL Wel I Records LR2-1 DALLAS ARCO CHEVRON EXXON TEXACO rD: REFERENCE: PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PPODUCTION Date: 06/24/88 TI: 79008 The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to thls office: A-27I ~ G-12 5[-16 ~Y-24 CCL/Perf 05/29/88 ~1 8700-9200 GO 5" CCL/Perf 05/24/88 #1 10800-11154 GO 5" CCL/Perf 05/25/88 #1 9550-10100 GO 5" CCL/Perf 05/29/88 01 8100-9600 GO 5" CCL/Perf 05/08/88 #1-4 2900-5250 GO 5" Temp/Su~vey 05/20/88 #1 10150-10500 GO 5" CCL 05/21/88 #1 10430-10500 GO 5" CCL/Perf 05/25/88 #1 8700-9400 GO 5" CCL/Pref 05/11/88 01 12910-13330 GO 5" Alaska Oil & Gas Cons. Commission Anchorage Rece i ved Date A urdt of the ofigi~ol 5,ondo,d O,I Co,-pcs~ Founded in Cle-elond. Oh;o. ,n 1870 Jennifer Dietz INFORMATION CONIROL Well Records LR2-1 Slandard Alasl~a Producllon Company 900 Eo$! Benson 8<>ulevord P.O. Bo= 196612 Anchorage. AIo$1~a 99.519-6612 (907) .564-51 ! ! DALLAS ARCO CH.F. VRON FXXON TEXACO lO: · MOBIL PHILLIPS STATE OF ALASKA ARCHIVES INDEXED STANDARD ALASKA PRODUCTION Date: 06/03/88 TI: 78897 REFERENCE: ~APC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by slgnlng a copy of this lea-for and returning it to this office: A-6 05/05/88 GO Static A-10 05/05/88 .GO " .B-I~ 05/04/88 GO " B-i5 65/04/88 GO " U-2 05/20/88 GO " X-5 05/06/88' GO " X-14 05/05/88 GO " Y-24 05/11/88 GO " Rece I ved Date Jennifer Dietz I NFO~HAT I ON CONTROC Wel I Records LR2-1 A un;t o! the o,;g;-ol .~'ondo,d O~1 Co,t, pon Founded ;n Cle-elo.d C~;e ,. 1870 Stando~'d P,,:,~u¢ lion Company 900 Ea',~ Se, re, on BOuN PO Bo, 196612 Anchorage. Alaska 99519.66l~ 1907l 564-511 I INDEXED DALL~\S ARCO CHEVRON STANDARD ALASKA PRODUCTION TEXACO Date: 05/03/88 ?0: MOBIL Il: 78788 GEOSC IENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: A-17 A-22 E-17 E-24 K-ii M-18 ~,X~ 10 Z-08 Water Injection Profile 04/25/88 H1 9885-10216 Sch 5" Production 04/23/88 H1 11350-12122 Sch 5" Cont. Flow Temp. 03/18/88 HI 10700-11181 GO 5" Cont. Flow Temp. 03/19/88 H1 10300-10660 GO 5" Cont. Flow Temp. 03/18/88 HI 11300-11620 GO 5" Perf. Record 04/27/88 #1 8252-9469 Sch 5" Temp/pump-in 03/23/88 H1 10600-10950 GO 5" Completion Record 04/24/88 H1 13095-13319 Sch 5" Temp. 03/28/88 Hi SURF-7765 GO 2" /" / ~aska Oil & ~as Cons. I;ornmi~lorl Rece i ved Date A u,,h ot She o, ig;not 5;ondo,d O,I Comll:N'lny Founded ;,',, Cle-elond. C~;o. ,, 1870 Victoria Aldridge I NFC~RMAT I ON CONTROl_ Wel I Records LR2-1 Stonda,d Ala$1~a Produc ~ion Company 900 [o',! Ben,,on Boul(',,,o,. PO Bo,, 196612 An(ho,oOe' Al(,,,I,o 9'9.519 6612 1907! .564-511 I INDEXED DALLAS ,~co STANDARD CHEVRON ALASKA PRODUCTION E~XON Date: 03/31/88 TEXACO TI: 78702 FIOBIL PHILLIPS ~ATE OF ALASKA ~ REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of thls letter and returning It to this office: E-23 E-24 G-16 K-10 K-II Y-lO Y-21 Y-22 Static 03/20/88 GO Static 03/14/88 Camco Static 03/20/88 GO Static 03/19/88 GO Static 03/14/88 Camco Flowing Gradient 03/12/88 Camco Static 03/09/88 Camco Flowing Gradient 03/09/88 Camco Static 03/19/88 GO Race I red Date Bas C0nm G0mm!ssi~n Anch0ra~e Vic toria Aldridge I NFORMAT I ON CONTROL Wel I Records LR2-1 A un;l ot the o,;g;nol S'ondo,d O,I Co,.nponr Founded ;n Cle,,,elond. C~,o. ,n 1870 INDEXED DALLAS A~C0 s-rANDARD CHEVRON ALASKA PRODUCTION E >LXON Dote: 03/31/88 TEXACO 78702 TO: TI: MOBIL PHILLIPS ~STATE OF ALASKA~ ~ REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returnlng It to thls office: E-23 E-24 G-16 K-10 K-11 Y-10 Y-21 Y-22 Y-24 Static 03/20/88 GO Static 03/14/88 Camco Static 03/20/88 GO Static 03/19/88 GO Static 03/14/88 Camco Flowing Gradient 03/12/88 Camco Static 03/09/88 Camco Flowing Gradient 03/09/88 Camco Static 03/19/88 GO Received Dote 0il & Gas Cons. 6omro!¢si~n Anchorage Vic toria Aldridge I NFOR~T I ON CONTR~ Well Records LR2-1 a u-,, ol ,he o,;gin, ol S"ondo,d O,I lrou~ded ;n Cley¢lond O~,o ,o 1870 INDEXED DALLAS ARCO CHEV~0N STANDARD ALASKA PRODUCTION E>2XON TEXACO Dote: 03/26/88 TO: MOBIL Ti: 78685 PHILLIPS ~ STATE OF ALASKA.) GEOSCIENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following materlal Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returnlng it to thls office: A-13 Collar 11/14/87 B-9 " 02/26/88 C-4 " 12/13/87 C-J4 " 01/07/88 C-27 " 11/15/87 C-21 DTL 03/11/88 C-34 CBT 03/17/88 D-9 Collar 01/09/88 D-13 " 01/08/88 D-17 " 11/25/87 D-22 " 01/10/88 E-25 Collar/GR 03/06/88 F-9 Collar 11/04/87 F-24 Perf. Record 03/15/88 K-10 CCL/Perf. 03/09/88 K-12 Collar 12/25/87 M-13 Fullbore Spinner 03/15/88 R-12 Production Logs 03/16/88 U-04 PFC 02/29/88 X-10 Prod log 03/20/88 .':Y-24 Collar 11/22-23/87 [/1 8400-9770 Atlas 5" [/1 8500-9824 Atlas 5" ¥/1 10250-10681 Atlas 5" ~/1 10000-11859 Atlas 5" ~/1 11000-11244 Atlas 5" ~]1 8800-9210 GO 5" ~/1 8300-9615 Sch 5" ~/2 10150-10450 Atlas 5" ~]2 11200-11446 Atlas 5" ~1 8800-10392 Atlas 5" ~/2 9000-9443 Atlas 5" //1 8500-10050 GO 5" //1 9750-10100 Atlas 5" [~1 11800-12289 Sch 5" //1 9050-10050 GO 5" //1 8200-9353 Atlas 5" ~3 9300-9640 Sch 5" ~2 10550-10950 Sch 5" ~/1 10765-11586 Atlas 5" ~/1 10600-10900 Sch 5" ~/1 12820-13441 Atlas 5" Received "] '] Victoria Aldridge INFORMAIION CONTROL Date Alaska Oil & Gas Cons. Commission Well Records LR2-1 Standard Alaska Pr o.,d u¢ l;on Company ~ Eo~ B~-~on 8o~1~ PO ~- 19661~ An( hot O~c. AIo~LO ,~7, 564-511 I INDEXED DALLAS ARCO CHEVRON ST~ND~RD AL ASKA PRODUCTION F.]C---~ON TEXACO Date: 01/26/88 TO: MOBIL T#: 78486 PHILLIPS STATE OF ALASKA GEOSCIENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: A-12 A-13 B-3B D-3 D-18 D-18 F-8 F-19 H-9i J-28 K-I2 K-13 K-14 Y-24 CCL/Perf. 12/23/87 #1 8100-9230 GO 5" Caliper Toot(Multifinger) 01/10/88 #2 100-8650 Sch 5" Spinner/Hydro/Temp. on coil tubing 12/17-18/87 #1 9500-11055 Production Profile 01/08/88 #1 10400-10660 Camco 5" Cont. Flow Survey 12/27/87 #1 10900-11200 GO 5" Temp. 12/27/87 #1 10800-11200 GO 5" Production Profile 01/16/88 #2 10950-11250 Camco 5" CCL/Perf. 12/25/87 #1 12200-12830 GO 5" Injection Profile 01/10/88 #1 9500-10000 Camco 5" Production Profile 01/12/88 #1 10790-11030 Camco 5" Production Profile 01/08/88 #1 9150-9370 Camco 5" Production Profile 01/18/88 #1 11800-12100 Camco 5" CCL/Perf. 12/22/87 #1-4 10950-11730 GO 5" PIT/Flowmeter 01/09/88 #1 12828-13450 Camco 5" co 5"/2" _.~ / ~ - · ~' ~ Victoria Aldridge / / ~, ;~ GBs Gons._C~T~t~'s .... i NFOR~T I ON CONTRCX. Date L_~// , _.]~ U~ ~ ~CC~[~' We I I Records LR2- I A un,~ al th~ o~,g~l ~rondo~d ~1 Founded ,n ~l~eto~. ~,o. ,n 1~70 DA I. I,A S ARCO CHEVRON EXXON TEXACO TO: biO B I L PIt ILLIPS STATE OF ALASKA GEOSC I ENC I-;S INDEXED STANDARD Date: 11/05/87 r#: 78296 REFERENCE: SAPC CAStSD ttOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: C-27 GR/ccl J-23 Completion x-08 Perforating Y-24 Completion 10/26/87 #I !0936-11100 Sch. 5" 10/26/87 #2 8653-9825 Sch 5" 10/26/87 #3 9400-10184 Sch 5" 10/26/87 #1 12844-13472 Sch 5" ~ AlaSk-,, u. a Gas Cons. Commission Anchorage Rece i ved Date t( ...... f,.,! I...,.I,,.,,i , u:. Id' Celina Plack I NF OI~MAT I ON CONTROL Wel I ~ecords LR2-1 Standard Alosl~o Produc Iqon Compal 900 Eos~ Ben,.on Bo~ ,d PO Bo, 196612 Ancho,oge. Alosl, o 99519-66 ~907i 564-5 I I I TO: DALLAS ARCO CHEVRON EBLXON TEXACO MOBIL PHILLIPS STATE OF ALASKA INDEXED ST.~iN D.~ R D AL ASKA PRODU.C ]_0/27/87 Date: 78280 T#: REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by slgning a copy of this letter and returning it to this office: Y-24 Static Gradient Camco 09/30/87 Recelved Date A un,i o| ih,i, Or,cl,nul ~'0,~(|(,,,I 0,1 Founded ,,, Cle*eln,,d (~,~,~ ,,, IH/C,~ Victoria Aldridge I t;FORMATION CONTf?0{ Wel I Records LI?2-1 Standard Alaska Production Compar 900 East Benson Bou,_ _ rd P.O. Box 196612 Anchorage, Alaska 99519-6612 i907~ 56!-5111 STANDARD ALASKA PRODUCTION September 3, 1987 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well Y-24 (13-04-10-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perform a cement squeeze and reperforation of the well. Yours very truly, JAB:JAM~ Enclosures (g) cc: J. L. Haas (MB12-1) Y-24 Well File J. A~. Bragg - Supervisor Production Operations A unit of the original Standard Oil Company Founded in Cleveland, Ohio n 1870 RECEIVED SEP 0 Alaska 011 & Gas Cons. Commission Anchorage STATE OF ALASKA ALA,..,A OIL AND GAS CONSERVATION COk .... ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown i~ Re-enter suspended well ~ Alter casing L3 Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate~ Other 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 88.85 feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 1349' SNL, 83' EWL, Sec. 34, TllN, R13E, UPM At top of productive interval 1695' NSL, 350' EWL, Sec. 04, T10N, R13E, UPM At effective depth 1598' NSL, 228' EWL, Sec. 04, T10N, R13E, UPM At total depth 1582' NSL, 208' EWL, Sec. 04, T10N, R13E, UPM 7. Well number Y-24 (13-04-10-13) PBU 8. Permit number 86-113 9. APl number 50--029-21608 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 13550 feet Plugs (measured) 9207 feet BKB Effective depth: measured true vertical 13508 feet Junk (measured) 9175 feet BKB Casing Length Structural -- Conductor 59 ' Surface 3002 ' Intermediate 13087 ' Production -- Liner 681' Perforation depth: measured 13262 ' Size Cemented Measured depth True Vertical depth BKB 20" 8 cu. yds. 110' 110' 13 3/8" 4000 c.f. 3053' 2672' 9 5/8" 575 c.f. 13138' 8889' 7" 349 c.f. 12869'-13550' 8688'-9207' - 13364' true vertical (ss) 8894' - 8974' Tubing (size, grade and measured depth) 3 1/2" L-80 EUE to 12795' with 2 7/8" tailpipe to 12926' Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 12795'; 3 1/2" SSSV at 2252' RECEIVED SEP 0 12.Attachments Description summary of proposal [] Detailed operations programAl~sk~~tifc¢:~l~. Commisslo; Anchorage 13. Estimated date for commencing operation September 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Sig'"~d '~~.~ Title Supervisor Production OperationsDate c~'-o:~~~ J. A. Bragg Commission Use Only Conditions of approval Notify commission so representative may witness I Ap [] Plug integrity [] BOP Test [] Location clearanceI Approved by . . Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Well Y-24 (13-04-10-13) CTU CEMENT SQUEEZE PROPOSAL A coiled tubing unit cement squeeze of existing perforation and confirmed channel to the OWC is proposed. The existing perforated interval is as follows: 13,262 - 13,364 ft. MD BKB (102') (Depths ref. BHCS/GR 7/12/86) This work is outlined below: 1. Perform pre-workover surveillance, including static pressure survey. 2. Attempt to remove fish (2-1/8" perforating gun and CCL). 3. Rig up CTU and support equipment. 4. Perform perforation mud acid wash, flow well. 5. Clean out sump to top of fish, if present. 6. Lay sand to cover fish and provide clean well bottom, if necessary. 7. Cement squeeze all perforations and channel. 8. Contaminate cement. WOC. 9. Clean out contaminated cement. Pressure test squeeze. 10. Perforate as follows: 13,262' - 13,364' MD BKB (Depths ref. BHCS 7-12-86) 11. Return the well to production. Coiled Tubing Blow-Out-Preventers Coiled Tubing Pack-Off Blind Rams Cutter Rams Chicksan (Kill Line) Slips Pipe Rams Pump-In Sub (Circula te/R e turns) W ell Head Swab Valve 0ii & Gas Cons, commissio~ P,oduction Compa, 900 I}osl Be-son Bo, ;d P.O Box 196612 Ancho,oge. Alosl, a 99519.6612 ¢907l 564-51 I I TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSC IENCES INDEXED STANDARD ALASKA PRODUC'rlON 04/29/87 77853 . REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submiffed herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: F-18 Per f. Record 01/05/87 #1 11693-1 2313 Sch 5" H-17 Cc~p le tion Record 12/20/86 #2 10258-10804 Sch 5" J-2 Perf. Record 01/05/87 #2 10000-10278 Sch 5" M-28 Conap le tion Rec Qrd 12/05/86 #1 8000-9194 Sch 5" S-6 Perf. Record 12/23/86 #3 10200-10615 Sch 5" Y-24 Perf. Record 01/01/87 #2 12700-13451 Sch 5" G-24 CBT 01/23/87 #1 9060-10392 Sch 5" G-24 CET 01/23/87 #1 9060-10398 Sch 5" G-24 GCT 01/23/87 #1 0-10350 Sch 5" G-29 CET 10/15/86 #1 8920-10076 Sch 5" Recb, ved V~ ~,~~7' `% O,te / /~ln;ka 0il & Commission Cons. · ..,, o, ,~. ~.s,~.o/o, co,.,o., ~ounded . C~~m 1870 INFORMAT ION CONTROL Wel I Records LR2-1 $1andard Alaska Production Company P.O. Bo~ 196612 Anchorage, AIo,,ko 99519-6612 (907t 564-5111 DALLAS ARCO CHEVRON EXXON INDEXED STANDARD ALASKA PRODUCTION TEXACO Date: 03/31/87 TO: MOBIL TI: 77804 PHILLIPS STATE OF ALASKA REFERENCE: GEOSCIENCES SAPC CASED HOLE FINAL LOGS The following material Is being submit-fed herewith. Please acknowledge receipt by signing a copy of this let-far and returning It to this office: B-7 Perf. Record 03/17/87 #1 C-38 Production Profile 03/12/87 #1 D-3 WOPITS 03/03/87 #1 G-1 Flowmeter/Temp. 03/18/87 #1 G-19 . Fullbore Spinner 03/15/87 #1 H-13 P~-oduction Profile 03/15/87 #1 H-17 Production Profile 03/11/87 #1 J-2 Completiom Record 03/12/87 #2 J-5 Perf. Record 11/16/86 #1 K-5 Perf.-Record 10/03/86 #1 M-14 Step Rate/Injection Profile 03/21 Q-5 Perf. Record 10/01/86 #2 S-13 Production Profile 02/25/87 #1 Y-22 Perf. Record 09/06/86 #1 Y-24 WOPITS 03/14/87 #1 Y-24 Perf. Record 10/28/86 #1 11500-11848 Sch 5" 10825-11137 Camco 5" 10300-10660 Camco 5" 9750-10079 Camco 5" 11250~11500 Sch 5" 9200-9520 Camco 5" 10250-10600 Camco 5" 10000-10283 Sch 5" 9990-10360 Sch 5" 8800-9740 Sch 5" /87 #1 10200-10750 Camco 5" 10000-10333 Sch 5" 10800-11201 Camco 5" 10500-11374 Sch 5" 13150-13531 Camco 5" 12700-13462 Sch 5" F~ecb i red ~- ,,- r' t~ \ ! ~,~ ~ · A un;! el Ihe or,CJinol 5~ondo,d J~ld...Co,rjl~ony . Founded ,~, Cle-elond. Ohio. i,,~e"~-~' O1'~.rln Victoria Aldridge INfORMAT ION CONTROL Wel I Records hR2-1 Production Company 900 Eosl ~n~on Boulevo, P.O. Box 196612 Anchoroge. Alosko 99519-6612 1907) 564-51 I I TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSC IENCES INDEXED STANDARD ALASKA PRODUCTION Date: 02/20/87 77727 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. signing a copy of this letter and returning It ?o thls office: B-23 F-17 F-17 H-13 H-26 J-1 N-3 N-3 N-8 S-18 T-7 Y-7 Y-13 Completion Record 09/23/86 #2 MWP-Measurement While Perf. 02/05/87 Perf. Record Completion Record Completion Record Junk Basket Tubing Puncher Collar Record EPL Completion Record Completion Record Completion Record 02/05/87 01/31/87 09/13/86 09/30/85 09/28/86 10/11/86 07/10/86 09/26/86 09/25/86 05/14/86 Completion Record 09/14/86 #1 Prod. Logging 02/02/87 #1 3100-13416 Please acknowledge receipt by 8340-9966 Sch 5" #1 10800-11374 Sch #1 10800-11374 Sch 5" #1 9200-9651 Sch 5" #1 9462-9989 Sch 5" #1 8900-9128 Sch 5" #1 9145-9600 Sch 5" #1 8172-9331 Sch 5" #1 9595-9970 Sch 5" #1 11200-12003 Sch 5" #2 8900-9600 Sch 5" #1 8450-9845 Sch 5" 9590-10620 Sch 5" Dres 5'" 5II Rece t ved Date A unit of the orig;~ol Standard C~I Company Founded in Cle-elond. Ohio. ;n 1870 Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 Stondard Alosl~a Production Compony 900 Eosl Ek"nson Boul¢-,o, j P.O Box 19661'2 An(horoge. Alosko 99.519-6612 (907) 564-.5 I I I INDEXED DAggAS .~co STANDARD CHEVRON ALASKA PRODUCTIOIN 02/20/87 EXXON Date: TEXACO 77730 TO: TI: MOBIL PHILLIPS STATE OF ALASKA REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following materlal Is belng submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and returning it to thls office: Y-24 Pressure Survey-Prod. Logging Services 02/05/87 #1 13100-13416 Dres Recelved Date Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 Standard Alaska Production Compaf 900 East Benson Bou. ,Jrd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907j 561-5111 January 19, 1987 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well Y-24 (13-04-10-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating and stimulating the well. Yours very truly, JAB: J~~ upervisor Production Operations Enclosures (4) cc: J. L. Haas, MB12-1 Well Records, LR2-1 w/10 Y-24 Well File ,~ unit of the or,gino! Standard Oil Company Founded in Cle~e!ond Ohio ,n 1870 STATE OF ALASKA ALASK, :L AND GAS CONSERVATION COMMa ON REPORT OF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown -- Stimulate ~ Plugging ~ Perforate ,~ Pull tubing Alter Casing - Other _-- 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 88.85 Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 1349' SNL, 83' EWL. Sec. At top of productive intervar 1695' NSL, 350' At effective depth 1598' NSL, 228' At total depth 1582' NSL, 208' EWL, 11. Present well condition summary Total depth: measured true vertical 34, TllN, R13E, UPM EWL, Sec. 04, T10N, R13E, UPM EWL, Sec. 04, T10N, R13E, UPM Sec. 04, T10N, R13E, UPM 13550 feet Plugs (measured) 9207 feet BKB 7. Well number Y-24 (13-04-10-13) PBU 8. Approval number 607/676 9. APl number 50-- 029-21608 10. Pool Prudhoe Oil Pool Effective depth' measured 13508 feet Junk (measured) true vertical 9175 feet BKB Casing Length Size Cemented Structural -- Conductor 59' 20" 8 cu.yds. Surface 3002' 13 3/8" 4000 c.f. Intermediate 13087' 9 5/8" 575 c.f. Production -- Liner 681' 7" 349 c.f. 12. Measured depth True Vertical depth BKB 110' 110' 3053 ' 2672 ' 13138 ' 8889 ' 12869 ' -13550 ' 8688' -9207 ' Perforation depth: measured 13262' - 13364' true vertical (subsea) 8894' - 8974' Tubing (size, grade and measured depth) 3 1/2" L-80 EUE to 12795' with 2 7/8" tailpipe to 12926' Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 12795'... 3 1/2" SSSV at 2252' Stimulation or cement squeeze summary Mud acid stimulation Intervals treated (measured) 13262' - 13364' Treatment description including volumes used and final pressure See attachment 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 250 642 6 0 194 Subsequent to operation 1560 1330 332 1445 196 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge /:_.~,~ · Title Supervisor Production Operations Signed Form 10.404¢~v. 12-1-85 Submit in Duplicate Well Y-24 (13-04-10-13) PBU ADD'L. PER~ORATING/STIMULATION OPERATIONS 1/1/87 Installed and tested lubricator to 3500 psi. Rigged up Schlumberger and performed the following perforating using 2 1/8" Hyperdome guns at 4 spf: Reperf: Add. perf: 13302' - 13342' MD BKB 13342' - 13364' MD BKB Put well back on production and tested. 1/9/87 Performed a mud acid stimulation of the perforated interval 13262' - 13364' MD as follows: ~ Stage 1 - 800 gal. 15% HC1 1600 gal. 12% HC1 - 3% HF 1600 gal. 3% NH4C1 brine 400 gal. 3% gelled NH4C1 brine w/diverter Stage 2 - 1200 gal. 15% HC1 2400 gal. 12% HC1 - 3% HF 2400 gal. 3% NH4C1 brine 600 gal. 3% gelled NH4C1 w/diverter Stage 3 - 2000 gal. 15% HC1 4000 gal. 12% HC1 - 3% HF 4000 gal. 3% NH4C1 brine 500 gal. diesel The treatment fluids were displaced to the perforations with 115 bbls. dead crude. Put well back on production and tested. jm 1/12/87 Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907i 561-5111 December 17, 1986 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well Y-24 (13-04-10-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Approvals, for the above-named well. This stimulate the well. Application contains our for Sundry proposal to Yours very truly, JAB:JAM~ Enclosures cc: J. L. Haas (MB12-1) Y-24 Well File //J/. A. Bragg ~upervisor Production Operations A unit of the or,ginal Standard Oil Company Founded in Cle~e!and Ohic ,n 1870 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMb ;ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend -- Operation Shutdown '_- Re-enter suspended well - Alter casing ' Time extension -- Change approved program % Plugging '- Stimulate X Pull tubing -- Amend order ' Perforate -- Other ' 2. Name of Operator STANDARD ALASICA PRODUCTION COMPANY 3. Address P. O. BOX 196612,. Anchorage, Alaska 99519-6612 4. Location of well at surface 1349' SNL, 83' EWL, Sec. 34, TllN, R13E, gPM At top of productive interval 1695' NSL, 350' EWL, Sec. 04, T10N, R13E, UPM At effective depth 1598' NSL, 228' EWL, Sec. 04, T10N, R13E, UPM At total depth 1582' NSL~ 208' EWL, Sec. 04, T10N, R13E, UPM 11. Present well condition summary Total depth: measured 13550 feet Plugs (measured) true vertical 9207 feet BKB 5. Datum elevation (DF or KB) KBE = 88.85 6. Unit or Property name Prudhoe Bay Unit 7. Well number Y-24 (13-04-10-13) PBU 8. Permit number 86-113 9. APl number 50-- 029-21608 10. Pool Prudhoe Oil Pool feet Effective depth: measured 13508 feet Junk (measured) true vertical 9175 feet BF,.B Casing Length Size Cemented Structural ,- Conductor, 59' 20" 8 cu.yds. Surface 3002' 13 3/8" 4000 c.f. 13087' 9 5/8" 575 c.f. Intermediate Production 681' 7" 349 c.f. Liner Perforation depth: measured 13262' - 13342' true vertical (subsea) 8894' - 8956' ~bing(size, grade and measured depth) 3 1/2" L-80 EUE to 12795' with 2 7/8" tailpipe to 12926' Packers and SSSV(type and measured depth) 9 5/8" TIW packer at 12795'; 3 1/2" BVN at 2252' Measured depth 110' 3053' 13138' 12869'-13550' True Vertical depth BKB 110 ' 2672 ' 8889 ' 8688 ' -9175 ' 12.Attachments Description summary of proposal ~- Detailed operations program ,% BOP sketch ;x 13. Estimated date for commencing operation December 1986/January 1987 14. If proposal was verbally approved Name of approver Date approved 15. ,1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ /~'~~/~_~._ Title Supervisor Production Operations Date _¢/¢v/ n. Bragg ~U Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. ~ ~ Plug integrity ~ BOP Test ~ Location clearance 7 g .~ Subsequent Wo~h Reported ' :':: I~,~ ~ .~¢~ on Form No./-~~ Dated _J,,//~l~-'~. ~ -. : ::,,.. ............ by order of _ ,., ~_/ I · .... ; ":"~" Commissioner the commission Date/¢'~'-'2' 5"d~' I Approved by Form 10-403 Rev 12-1-85 Submit in triplicate Well Y-24 (13-04-10-13) PBU REPERFORATING/STIMULATI ON PROPOSAL Further to our Sundry Application of 11/24/86, we propose to reperforate the interval 13300' - 13342' MD at the time we perforate the additional interval 13342' - 13364' MD. Following the perforating operations, the intervals will be treated with a mud acid stimulation in three stages as follows: 1st stage: 800 gal. 15% HCl 1600 gal. 12% HC1 - 3% HF 1600 gal. 3% NH4Cl brine 400 gal. 3% NH4C1 brine w/diverter 2nd stage: 1200 gal. 15% HC1 2400 gal. 12% HC1 - 3% HF 2400 gal. 3% NH4C1 brine 600 gal. 3% NH4C1 brine w/diverter 3rd stage: 2000 gal. 15% HC1 4000 gal. 12% HC1 - 3% HF 4000 gal. 3% NH4C1 brine 500 gal. diesel The~treatment fluids will be displaced to the perforations with dead crude. The well will be returned to production immediately after the treatment and tested. jm 12/16/86 Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907i 561-5111 November 25, 1986 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well Y-24 (13-04-10-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. Yours very truly, Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 Y-24 Well File P. F. Barth, Supervisor Reservoir/Production Surveillance Unit I A unit of the or,ginol Standard C~l Company Founded in Cle~e!ond Ohio in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMb ;ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown © Stimulate ~ Plugging ? Perforate % Pull tubing '- Alter Casing ___ Other L% 2. Name of Operator STANDARD ALASKA PRODUCTION COMPANY 3. Address P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 1349' SNL, 83' EWL, Sec. 34, T11N, R13E, UPM At top of productive interval 1695' NSL, 350' EWL, Sec. 04, TION, R13E, UPM At effective depth 1598' NSL, 228' EWL, Sec. 04, TION, R13E, UPM At total depth 1582' NSL, 208' EWL, Sec. 04, TION, R13E, UPM 5. Datum elevation (DF or KB) KBI; = 6. Unit or Property name Prudhoe Bay Unit 7. Well number Y-24 (13-04-10-13) PBU Feet 8. Approval number 468 9. APl number 50--029-21608 10. Pool Prudhoe 0il Pool, 11. Present well condition summary Total depth: measured true vertical 13550 feet Plugs (measured) 9207 feet BKB Effective depth: measured 13508 feet Junk (measured) true vertical 9175 feet BKB 12. Casing Length Size Cemented Structural -- Conductor 59 ' 20" 8 cu. yds. Surface 3002' 13 3/8" 4000 c.f. Intermediate 13087' 9 5/8" 575 c.f. Production Liner 681 ' 7" 349 c.f. Perforation depth: measured 13262' - 13342' true vertical (subsea) 8894' - 8956' Tubing (size, grade and measured depth) 3 1/2" L-80 EUE to 12795' with 2 7/8" tailpipe to 12926' Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 12795'; 3 1/2" $SSV at 2252' Stimulation or cement squeeze summary Measured depth ~ue Verticaldepth BKB 110' 110' 3053' 2672' 13138' 8889' 12869'-13550' 8688'-9175' Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 200 168 2 0 208 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run 15. I hereby certify that_the foregoing is true and correct to the best of my knowledge ,---~"~J-- S'gn'i-~d .~'~'.~,~ '~,~~,~_.. Title Supvr. Res/Prod, Surveillance I Form 10-404 Re~. 1'2-1-85 Submit ir~ Dul~licate PERFORATING DATA - Well Y-24 (13-04-10-13) PBU 10/26/86 Pressure tested tubing and inner annulus. 10/28/86 Installed and tested lubricator to 3500 psi. Rigged up SChlumberger and perforated the following interval for initial production using 2 1/8" carrier guns at 4 spf: 13262' - 13342' F~D BKB (8894' - 8956' TVDss) Ref. BHCS/GR, 7/12/86. Attempted unsuccessfully to flow. 11/3/86 Ran Amerada pressure surveys at 8800' TVDss. Well currently on production pending additional perforating operations as proposed in Sundry Notice to follow. jm 11/21/86 Standard Alaska Production Compa 900 East Benson Bou,_ _ord P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 25, 1986 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well Y-24 (13-04-10-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Approvals, for the above-named well. proposal to perforate the well. Application for Sundry This contains our Yours very truly, PFB:JAM~ Enclosures (9) cc: J. L. Haas (~B12-1) Y-24 Well File sAor Reservoir/Production Surveillance Unit I A unit of the or,gino', Standard Oil Company Founded in Cle~eJon0 Ohio in 187C. STATE OF ALASKA ALASK )IL AND GAS CONSERVATION COMb' ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation Shutdown -- Re-enter suspended well - Alter casing -' Time extension _- Change approved program- Plugging ~- Stimulate- Pull tubing- Amend order- Perforate ix Other ' 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 88.85 feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 1349' SNL, 83' EWL, At top of productive interval 1695' NSL, 350' EWL, At effective depth 1598' NSL, 228' EWL, At total depth 1582' NSL, 208' EWL, Sec. 34, T11N, R13E, UPM Sec. 04, TION, R13E, UPM Sec. 04, TION, R13E, UPM Sec. 04, TION, R13E, UPM 7. Well number Y-24 (13-04-10-1:3) PBU 8. Permit number 86-113 9. APl number 50--029-21608 10. Pool Prudhoe 0il Pool 11. Present well condition summary Total depth: measured true vertical 13550 9207 Effective depth: measured 13508 true vertical 9175 Casing Length Size Structural -- Conductor, 59' 20" Surface 3002' 13 3/8" Intermediate 13087 ' 9 5/8" Production -- Liner 681 ' 7" Perforation depth: measured 13262' - 13342' true vertical (subsea) 8894' - 8956' feet Plugs (measured) feet BKB feet Junk (measured) feet BKB Cemented Measured depth ~ue Verticaldepth BKB 8 cu.yds. 110' 110' 4000 c.f. 3053' 2672' 575 c.f. 13138' 8889' 349 c.f. 12869'-13550' Tubing (size, grade and measured depth) 3 1/2" L-80 RUE to 12795' with 2 7/8" tailpipe to 12926' Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 12795", 3 1/2" BVN at 2252' 8688 '-9175' 12.Attachments Description summary of proposal ~ Detailed. operations program" BOP sketch 13. Estimated date for commencing operation November/December 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~. (~..~ ~c ¢~). ~¢"~2~--TitleSupvr- Res/Prod. Surveil lance I P. F. Berth v Commission Use Only Date/ Conditions of approval Approved by Notify commission so representative may witness ~ Plug integrity ~- BOP Test .~ Location clearance Commissioner J Approval No. Subsequent '¥Vor~ by order of the commission Date Form 10-403 Rev 12-1-85 -'~ Submit in triplicate Well Y-24 (13-04-10-13) PBU ADDITIONAL PERFORATING PROPOSAL We propose to perforate the following additional interval during November/ December 1986 at 4 spf: 13342' -13364' MD BKB (8956' -8974' TVDss) All depths are referenced to BHCS/GR, 7/12/86. A lubricator will be installed and tested to 3500 psi for all well work. Following perforating operations, a SSSV will be set and tested in the ball valve nipple at 2252'. jm 11/21/86 FLOW TUBES & PACKOFF BOWEN PACr,,OFF ~~,~~~}_.._ HAN D GREASE SEAL FLOWTUBE PUMP FLOWLINE GREASE LINE FLOWLINE VALVE . BOP GREASE MANIFOLD GREASE PUMP RISER ...,-GREASE RESERVOIR S,:o ndard Alaska ' P~oduction Company 900 Eot, t Be'nso- P O ~ 196612 Anchorage. AIo~o ~907} DALLAS ARCO INDEXED CHEVRON EXXON TEXACO Date: 11/21/86 , lO: MOBIL l#: 77539 PHILLIPS STATE' OF ALASKA GEOSC IENCES STANDARD AL ASK~X PRODUCTION REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of thls letter and returnlng it to this office: F-5 G-27 G-27 H-20 J-1 N-7 Y-il Y-24 Collar Log 09/19/86 H1 9436-9659 Sch 5" GR 09/16/86 Hi 6965-10775 Sch 5" Gun Positioning 09/17/86 #2 8250-9025 Sch 5" Production Profile 11/10/86 Hi 9800-10160 Camco 5" Squeeze Gun Record 09/19/86 #1 8800-9100 Sch 5" Production Profile 11/10/86 Hi 10100-10570 Camco 5" Flowmeter il/12/86 #2 9600-10314 Camco 5" Flowmeter 11/15/86 H1 13150-13430 Camco 5" Rece i ved Date A un, I of Ihe o.g,nnl 51~,n~1¢~1 C),I Co,npony Founded ,n (:le.elc)nd. C)~,O. ,n 1870 Victoria Aldridge INFORHAI ION CONIROL We I I Recor0s hR2- I P~oduc tion Compon¥ P.O Bo= 196612 An(ho~oge. AIo¢,o 99519-6612 (g07} .564-5 I I I INDEXED DALLAS ARCO CHEVRON EXXON TEXACO ' Dete: 1i/18/86 TO: biOBIL TI: 77525 PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD AL ASK, A, PRODLJC TION REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to thls office: _ B-18 Perf. Record 07/04/86 #1 8650-9250 Sch 5 B-20 Perf. zRecord 07/05/86 #1 9530-9854 Sch 5" G-30 CET 08/06/86 #1 8762-9766 Sch 5" G-30 CBT 08/06/86 #1 8672-9743 Sch 5" G-32 CBT 08/27/86 #1 8350-9550 Sch 5" J-1 Tubing Cutter Record 08/23/86 #1 8600-9100 Sch 5" J-19 GCT 07/12/86 #1 SURF-1390 Sch 5" J-19 GCT 07/12/86 #2 SURF-1772 Sch 5" M-2 Perf. Record 07/01/86 #1 10000-10334 Sch 5" M-2 Spinner Profile 07/09/86 #1 9695-10300 Sch 5" M-21 Perf. Record 07/04/86 #1 8370-9250 Sch 5" R-I8 Perf. Record 07/06/86 #1 8990-10067 Sch 5" R-23 Perf Record 07/03/86 · ~,1 11240-12174 Sch 5" S-19 GCT 07/21/86 #1 S~F-1498 Sch 5" S-19 CBT 08/13/86 #1 9100-10110 Sch 5" S-20 CBT 08/30/86 #I 871~9774 Sch 5" Y-24 GCT 07/15/86 #1 SU~-13450 Sch 5" Y-24 CBT 07/15/86 #1 12600-13488 Sch 5" ~~¢a Oil & Gas Oo~. Oomm~ss~:n _1 r Rec¢iyed Date A un,I oF lhe o,,g,~l Stund.,d 0,1Co,npony ~o.,,cled ,n Cle-.l¢,nd. C~,,o ,,, 18;(3 Victoria Aldridge I NFOR~b~I ~ ON CONIROL Ws~ Records LR2-~ Standard Alaska. . Production Con' 900 East Bensor, rd P.O. Box 196612 Anchorage, Alaska 99,519-6612 (907i ,561-,5111 October 10, 1986 STANDARD ALASKA PRODUCTION Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 kttention: Mr. C. V. Chatterton Well Y-24 (13-04-10-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. PFB: JAM~ Enclosures (9) cc: J. L. Haas (MB12-1) Y-24 Well File Yours very truly, P. F. Barth, Supervisor Reservoir/Production Surveillance Unit I A unit of the or~g,r'ol Standard Oil Company, Founded in CieseJond Ohio in 1870. STATE OF ALASKA -_ AL/ OIL AND GAS CONSERVATION CO 31ON APPLICA'I ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation Shutdown -- Re-enter suspended well - Alter casing - Time extension- Change approved program _-- Plugging-- Stimulate- Pull tubing- Amend order- Perforate X Other 2. Name of Operator 5. STANDARD ALASKA PRODUCTION COMPANY 3. Address 6. P. O. BOX 196612, ANCHORAGE, AT,ASKA 99519-6612 4. Location of well at surface 7. 1349' SNL. 83' EWL, Sec. 34, TllN, R13E, UPM At top of productive interval (top Ivishak/Sadlerochit) 1695' NSL, 350' EWL, Sec. 04, T10N, R13E, UPM At effective depth 1598' NSL, 228' EWL, Sec. 04, T10N, R13E, UPM At total depth 1582' NSL, 208' EWL~ Sec. 04~ T10N~ R13E~ UPM 11. Present well condition summary Total depth: measured 13550 feet Plugs (measured) true vertical 9207 feet BKB Datum elevation (DF or KB) KBE = 88.85 Unit or Property name Prudhoe Bay Unit Well number Y-24 (13-04-10-13) PBU 8. Permit number 86-113 9. APl number 50-- 029-21608 10. Pool Prudhoe Oil Pool feet Effective depth' measured 13508 feet Junk (measured) true vertical 9175 feet BKB Casing Length Size Cemented Measured depth Structural ,- Conductor. 59' 20" 8 cu.yds· 110' Surface 3002' 13 3/8" 4000 c.f. 3053' Intermediate 13087' 9 5/8" 575 c·f. 13138' Production __ Liner 681' 7" 349 c.f. 12869'-13550' Perforation depth: measured True Vertical depth BK_B 110' 2672 ' 8889' 8688'-9175' true vertical Tubing (size, grade and measured depth) 3 1/2" L-80 to 12795' with 2 7/8" tailpipe to 12926' Packers and SSSV (type and measured depth) 9 5/8" TTW packer at 12795'; 3 1/2" ball valve nipple at. 2252' 12.Attachments Description summary of proposal 13. Estimated date for commencing operation October/November 1986 14. If proposal was verbally approved Name of approver Date approved 15.1 hereby cert/t~ ~ the/~oreg~ng is_true and correct to the best of my knowledge Signed ~,~~"~ Titlesupvr. Res/Prod· Surveillance I P. F. B'~ ~arth Date Commission Use Only Conditions of approval Approved by Notify commission so representative may witness Plug integrity BOP Test ~ Location clearance .' ....... ,,-~ ,, - ~. 4 {'~ ~:,~,,, -.- Commissioner $~bsequ~nt Wo~h l~eport~ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Well Y-24 (13-04-10-13) PBU INITIAL PERFORATION PROPOSAL We propose to perforate the following interval for initial production during October/November 1986 at 4 spf: 13262' - 13342' MD BKB (8894' - 8956' TVDss) BHCS/GR, 7/12/86 A lubricator will be installed and tested to 3500 psi for all well work. An SSSV will be set and tested in the ball valve nipple at 2252' after the well is put on production. jR 10/3/86 FLOW TUBES & PACKOFF BOWEN PAOr,,OFF ~~~..~~]_~__ HA N D GREASE SEAL FLOWTUBE PUMP FLOWLINE ~ FLOWLINE VALVE GREASE LINE GREASE '--'MANIFOLD GREASE PUMP RISER ..~ GREASE RESERVOIR B OP Updated Report 8-29-86 ~A~~¢~~ Original Report 8-18-86 ALASKA~.~,LAND ON C( MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number / Standard Alaska Production Company 86-113 3. Address 8. APl Number P.O. Box 196612, Anchorage, AK 99519-6612 50-029-21608 4. Location of well at surface ,77'~~ --~ 9. Unit or Lease Name 1349' SNL, 5197' WEL, Sec. 34, TllN, R13E ~~S'IvE~,~,;~", Prudhoe Bay Unit At Top Producing Intervalic.._~ ~ ~, I~ ~.,~'" / 10. Well Number 3585' SNL, 4930' WEL, Sec. 4, T10N, R13E t~'~ Y-24 (13-4-10-13) At Total Depth~ 11. Field and Pool 3698' SNL, 5082' WEL, Sec. 4, T10N, R13E 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Field KBE = 88.85'I ADL 47471 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 6-24-86 7-12-86 7-17-86I N/A feet MSLI one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 13,550' MD 13,508' MD YES [~' NO [] 2267 feet MDI 2047 22. Type Electric or Other Logs Run DIL/SFL, BHCS, LDT/EPT-Poro LDT/EPT-RAW, EPT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZEWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Cond~ctor Surface IlO' 8 cu. yds. concrete 13-3/8" 72~ L-80 Surface 3053' 17-1/2" 4000 cu. ft. Permafrost 9-5/8" 47~ L-80NSCC Surface 6580' 12-1/4" 9-5/8" 47~ L-80Butt 6580' 13138' 12-1/4" 575 cu.ft. Class G 1%2FR-2+.08% HR-7 7" 29~ L-80 12869' 13550' 8-1/2" 349 cu.ft. Class G.5% Halad 344+.25%CW] 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) 3-1/2" 9 3# 12927' MD 12823' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9-5/8" x 13-3/8' Downsqueeze annulus with 300 sks. Permafrost C followed by 12S bh]s dry 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~-'- '! ~ ',I ~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. "' '"~ 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, · MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag Ri~ver 13132 ' 8884 ~ Shnhlik_ A 13155 '~ 8902 ' Zone 4 13262' 8984' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Division ~~ ~ Drilling Signed "' -- Title Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 Standard Alaska Production Company 900 East Benson Boulev P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUC-rlON August 15, 1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton: Nell Y-24 (13-4-10-13) PBU Gentlemen: Enclosed in duplicate is Form 10-407, Nell Completion Report, for the above-named well, together with the Daily Drilling Reports and the well logs. The gyroscopic survey is not enclosed. This will be sent to you at a later date along with a revised copy of the Nell Completion Report completing Items #4, 17, 18 and 29 on the report. This well has been completed as a non-perforated oil well. Very truly yours, STANDARD ALASKA PRODUCTION COMPANY R. S. Allan Division Drilling Engineer RSA/MAFI/pm/1050D Enclosure(s) cc' R. H. Reiley Nell File #17 u',..-, 1 8 i996 Alaska Oil & Gz~s Cons. Commission A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA-..~iLAND GAS CONSERVATION C, .... ,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Ccm%oany 86.-113 3. Address 8. APl Number P,O. Box 19'6612, Anchorage., Alaska 99519.-6-612 5o- 029-21608 4. Location of well at surface 9. Unit or Lease Name 1349" SNL, 5197' WEL, Sec,. 34, TllN, R13E Prudhoe Bay Unit At Top Producing Interval 10. Well Number ¥-24 (13-4-10-13) At Total Depth 11. Field and Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. .?rUC~3.O~ Bay Oil Pool KBE = 88.85' ADL 47471 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 1 5. Water Depth, if offshore 116. No. of Completions 6'24-86 7-12-86- 7-17-86 N/A feet MSLI one 17. Total Depth (MD+TVS) 18. PlugBaokDepth(ME)+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 13,550' lVJD 13,5Q8' ~ YES~ NO[]I 2267 feetMD[ 2047 22. Type Electric or Other Logs Run . DZL/SLU-'L, BHCS, LDT/~.~ic~2-Poro'/ LDT/E!'~_-RAW.!.. ~ 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Cond~ Lctor Surface 110' 8 cu. yds. concrete 13-3/8" 72,% L.-80' Surface 3053' 17.-1/2'" 4000 cu,ft, Permafro:~t 9-5/8" 47.~ L-80NSC(! Surface 6580" 12-1/4" 9-5/8" 47~ L-80'But-- 658'0'~' 13138' 12-1/4" 575 cu.ft. Class G 1;~CFR-2+.08% HR-7 7" 29% L-80 12-969" 13550' 8-1/2" 349 cu.ft. Class G . ~% Halad 344 +.252 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) 3-1/2", 9.3# 12927' _MD 12823' 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.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL ~ GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 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 of oil, gas or water. Submit core chips. ECE1VED Alaska Oil & Oa, s Cons. c0mmissi0r' Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ^/ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. I 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my kno~lc, dg¢ DlV3~S]~On Drilling Signed {' ~--~-~ Title Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' ClaSsification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 SAPC Daily Drilling Report -- PBU June 25, 1986 at 0600 hours Rig' AUDI #2 Well' Y-24 (13-4-10-13 ) AFE # 120500 0600 Depth' 900' Day' 1 24-Hour Ftg' 900' Water Used: 1400 Current Opera ti on' Dyna-Drilling. Spud at 1630 hours 6/24/86. Drill to 500'. Trip for bit and BHA. Kick off and drill to 900'. MUD TYPE-Spud WT:8.7 VIS'300 PV-20 YP-51 FL'13.8 SOLIDS'3 TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDI)~TES DLS 1065H' SAPC Daily Drilling Report -- PBU June 26, 1986 at 0600 hours Rig: AUDI //2 Wel!: Y-24 113-4-10-13) AFE # 120500 0600 Depth: 1900' Day: 2 24-Hour Ftg: lO00' Water Used: llO0 Current Operation' Dyna-Drilling. Trip for bit. Dynadrill to 1533'. Trip for bit and BHA: Drill to 1653'. Trip for BHA. Dynadrilling at 1900'. MUD TYPE-SPUD WT:8.9 VIS:ISO PV:15 YP:52 FL:17.4 SOLIDS:4.3 TEMP:49°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 2 1173 8.7 S25.5W 1168 68 65 26 1 ~66 4 1550 16j8 S26.9W 1532 167 153 71 1 il7 6 1827 23~2 S28W 1794 257 231 ll7 3j55 1065H: SAPC Daily Drillin9 Report -- PBU June 27, 1986 at 0600 hours Rig: AUDI #2 Well' Y-24 (13-4-10-13) AFE # 120500 Current Operation: 0600 Depth: 2872' Day: 3 24-Hour Ftg: 972' Water Used: 800 Drilling. Dynadrill to 2189'. ,Trip BHA. r)rilling at 2872 . for bit. Dynadrill to 2753'. Trip for MUD TYPE-SPUD WT:9.3 VIS:180 PV:21 YP:58 FL:17.0 SOLIDS:7 TEMP:~6°F SURVEY MD A)~LE DIRECTION TVD SECTION COORDINATES DLS 7 2016 30.1 S28W 1962 341 306 157 3.57 8 2206 36.4 S30.1W 2121 445 397 208 3.47 9 2394 42.4 S27.3W 2266 564 502 265 3.47 lO 2583 48.6 S27.6W 2399 698 622 327 3.17 ll 2701 52.7 S29W 2474 788 702 370 3.74 1065H: Rig: AUDI #2 Well: Y-24 (13-4-10-13 ) SAPC Daily Drilling Report -- PBU June 28, 1986 at 0600 hours AFE # 120500 0600 Depth: 3070' Day: 4 2~-Hour Ftg: 198' Water Used: 600 Current Operation: Nipple Up B.O.P.'s. Drill to 3070'. Ran 13-3/8" casing to 3050' and cemented with 4731 sNs Permafrost. NU BOPE. MUD TYPE-SPUD WT:9.3 VIS:120 PV:18 YP:38 FL:18.8 SOLIDS:7.5 TEMP:°F SURVEY MD AF~LE DIRECTION TVD SECTION COORDINATES DLS 12 2959 53.6 S26.2W 2629 993 883 446 0.97 1065H: SAPC Daily Dril!in§ Report -- PBU June 29, 1986 at 0600 hours Rig: AUDI #2 Well- Y-24 fl3-4-10-13) AFE # 120500 0600 Depth' 4750' Day' 5 24-Hour Ftg' 1680' Water Used- 900 Current Operation- Drilling. Test BOPE. RIH and test casing to 3000 psi. Drill cement and FS. Ran FIT to .6 psi/ft. Drill to 4297'. Trip for bit and BHA. Drilling at 4750'. MUD TYPE-Gel Water WT:9.0 VIS'32 PV'3 YP'4 FL' SOLIDS'7 TEMP'°F SURVEY ..MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 13 31 97 52.7 S26.9W 2771 1182 1055 551 O. 46 14 3576 52.5 S26.gw 3001 1480 1324 687 0.07 15 3934 54.4 S26.6W 3215 1765 1580 817 O. 55 16 4239 ' 56.3 S26.2W 3388 2014 1805 928 0.57 1065H' SAPC Daily Drilling Report -- PBU June 30, 1986 at 0600 hours Rig' AUDI //2 Well' Y-~_4 {13-4-10-13) AFE # 120500 0600 Depth' 6478' Day: 6 24-Hour Ftg' 1728' Water Used' 1200 Current Operation' RIH with Bit #10. Drill to 5646'. Trip for bit and BHA. Drill to 6478'. Trip for bit and BHA. MUD TYPE-Disp. WT'9.6 VIS:40 PV-9 YP-13 FL'lO.8 SOLIDS'lO TEMP-74°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 17 4616 55.5 S28W 3600 2324 2083 lO71 0.67 18 4906 53.9 S30.4W 3767 2559 2290 1186 0.67 19 5291 53.9 S29.7W 3994 2870 2559 1342 O. lO 20 5582 51.4 S32.6W 4170 3101 2757 1461 1.19 21 6041 52.8 S36.1W 4453 3463 3056 1666 0.58 22 6335 54.6 S35.7W 4627 3700 3248 1805 0.59 1065H' SAPC Daily Drilling Report -- PBU July 1, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 (13-4-10-13) AFE # 120500 0600 Depth: 7855' Day: 7 24-Hour Ftg: 1377' Water Used: 2000 Current Operation- Drilling. Drill to 7510'. Trip for bit and BHA. Drilling at 7855'. MUD TYPE-DISP WT:9.5 VIS:37 PV:ll YP:8 FL:8.0 SOLIDS:8.5 TEMP:76°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 21 6041 52.8 S36.1W 4453 3463 3056 1666 22 6335 54.6 S35.7W 4627 3700 3248 1805 23 6652 55~5 S35.5W 4808 3959 3459 1956 24 7005 56.0 S37.5W 5007 4251 3694 2130 25 7290 56.0 S38W 5166 4487 3881 2274 26 7642 55.5 S40j3W 5365 4777 4106 2458 0.58 0.59 0.32 0.49 0.10 0.56 1065H: SAPC Daily Drilling Report -- PBU July 2, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 (13-4-10-13) AFE # 120500 0600 Depth: 8450' Day: 8 24-Hour Ftg: 595' Water Used: 1600 Current Operation: P/U BHA. Drill to 8348' Trip for bit and BHA. Dynadrill from 8348 to 8450'. Trip fo~ bit and BHA. MUD TYPE-DISP WT:9.5 VIS:42 PV:9 YP:ll FL:6.8 SOLIDS:9 TEMP:80°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 27 7932 54.7 S39.1W 5530 5014 4287 2613 0.30 28 8216 54 S41W 5695 5243 4463 2762 O. 38 29 8385 53.5 S37.5W 5795 5379 4568 2849 1 . 65 1065H: Rig: AUDI //2 Well: Y-24 (13-4-10-13) SAPC Daily Drilling Report -- PBU July 3, 1986 at 0600 hours AFE # 120500 0600 Depth: 9373' Day: 9 24-Hour Ftg: 923' Water Used: 1300 Current Operation: RIH w/Bit #15. RIH. Ream Dynadrill run. Drill to 9373'. Trip for bit and BHA. MUD TYPE-DISP WT:9.6 VIS:42 PV:ll YP:IO FL:5.6 SOLIDS:9.5 TEMP:84°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 30 8682 53.5 S32.6W 5972 5618 4764 2986 31 9155 53.4 S32.2W 6254 5997 5086 3187 DLS 1.35 0.10 1065H: SAPC Daily Drilling Report -- PBU July 4, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 113-4-10-13) AFE # 120500 0600 Depth: 10,152' Day: 10 24-Hour Ftg: 779' Water Used: 1200 Current Operation' Drilling ahead. RIH. Drill to 9953'. POH for bit and BHA. RIH and drill to 10,152'. MUD TYPE-DISP WT:9.7 VIS:48 PV:16 YP:13 FL:5.2 SOLIDS:lO TEMP:76°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 32 9533 52.6 S31 .gw 648l 6299 5342 3348 0.28 34 10006 49.3 S33.3W 6781 6664 5649 3545 O. 53 1065H: Rig: AUDI #2 Well: Y-24 (13-4-10-13) SAPC Daily Drilling Report -- PBU July 5, 1986 at 0600 hours AFE # 120500 0600 Depth: 10,727' Day: ll 24-Hour Ftg: 575' Water Used: 1700 Current Operation: Drilling ahead. Drill to 10,625'. Trip for BHA. Drilling to 10,727'. MUD TYPE-D ISP WT:9.7 VIS:49 PV:19 YP:ll FL:4.8 SOLIDS:lO TEMP:82°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES ,, , 35 10479 50.5 S34.7W 7086 7026 5949 3747 1065H: DLS 0.33 SAPC Daily Drilling Report -- PBU July 6, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 (13-4-10-13) AFE # 120500 0600 Depth: 11,386' Day: 12 24-Hour Ftg: 659' Water Used: 1500 Current Operation: POH for BHA change. Drill to 11,048'. POH for BHA and bit. RIH and ream from 10,232' to bottom. Drill to 11,386' and POH for bit. MUD TYPE-DISP WT:9.8 VIS:48 PV:18 YP:12 FL:4.8 SOLIDS:Il TEMP:78°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS · , , , 36 10762 50.2 S35.7W 7267 7244 6127 3873 0.29 38 11329 44.0 S37.1W 7656 7656 6458 4119 O. 88 1065H: SAPC Daily Drilling Report -- PBU July 7, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 (13-4-10-13) AFE # 120500 0600 Depth: 11,680' Day: 13 24-Hour Ftg: 294' Water Used: 900 Current Operation: RIH. RIH and drill to 11,680'. Pump pill and POH for BHA and bit. RIH. MUD TYPE-D ISP WT:9.8 VIS:40 PV:12 YP:6 FL:4.8 SOLIDS:Il TEMP:78°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 39 11612 48.3 S38.5W 7852 7860 6619 4244 1.50 1065H: Rig: AUDI #2 Well: Y-24 (13-4-10-13) SAPC Daily Drilling Report -- PBU July 8, 1986 at 0600 hours AFE # 120500 0600 Depth: 12,626' Day: 14 24-Hour Ftg: 946' Water Used: 1700 Current Operation: Tripping. RIH and drill to 12,626'. POH to install MWD GR sub in BHA. MUD TYPE-DISP WT:9.9 VIS:43 PV:15 YP:9 FL:4.8 SOLIDS:Il.5 TEMP:84°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 40 11986 48.3 S38.9W 8101 8138 6837 4419 42 12554 43.9 S40.6W 8492 8547 7154 4680 1065H: DLS 0.08 0.96 SAPC Daily Drilling Report -- PBU July 9, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 {13-4-10-13) AFE # 120500 0600 Depth: 13,155' Day: 15 24-Hour Ftg: 529' Water Used: 1200 Current Operation: Ream to bottom. Drill to 12-1/4" T.D. Short trip 75 stands. Washing and reaming 15 stands to bottom before running 9-5/8" casing. MUD TYPE-D ISP WT:9.9 VIS:46 PV:16 YP:9 FL:4.8 SOLIDS:Il TEMP:IOO°F SURVEY MD ANGLE DIRECTION TVD SECTION COORD I NATES DLS 43 12740 43.3 S41.3W 8627 8675 7251 4664 0.38 44 13093 40.3 S46.3W 8890 8907 7421 4927 1.27 1065H: SAPC Daily Drilling Report -- PBU July 10, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 I13-4-10-13) AFE # 120500 0600 Depth: 13,155' Day: 16 24-Hour Ftg: ' Water Used: 300 Current Operation: Run 9-5/8" casing. Circulate and condition mud. Build weighl~-'to lO.1 ppg. POH wi th S.L.M. Running 9-5/8" casing. MUD TYPE-DISP WT:lO.1 VIS:40 PV:14 YP:9 FL:5.8 SOLIDS:12 TEMP: °F SURVEY MD- ANGLE DIRECTION TVD SECTION COORDINATES DLS . 1065H: SAPC Daily Drilling Report -- PBU July l l, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 (13-4-10-13) AFE # 120500 0600 Depth: 13,155' Day: 17 24-Hour Ftg: O' Water Used: 400 Current Operation: RIH. Run 9-5/8" casing and cement with 500 sx Class G cement. Bump plug w/3000 psi. Run packoff and test to 5000 psi. L/D 12-1/4" and P/U 8-1/2" BHA. RIH. MUD TYPE-DISP WT:8.8 VIS:32 PV:2 ¥P:3 FL:13.2 SOLIDS:5 TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1065H: SAPC Daily Dril ling Report -- PBU July 12, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 (13-4-10-13) AFE # 120500 0600 Depth: 13,550' Day: 18 24-Hour Ftg: ' Water Used: 900 Current Operation' Logging. RIH and drill float equipment and cement to 13,060' Test casing to 3000 psi. Drill to 13,550'. CBU and POH for l'ogs. Running #1 wi rel i ne 1 ogs. MUD TYPE-DISP WT:9.0 VIS:39 PV:9 YP:4 FL:ll.3 SOLIDS:7 TEMP:93°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1065H: SAPC Daily Drilling Report -- PBU July 13, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 (13-4-10-13) AFE # 120500 0600 Depth: 13,550' Day: 19 24-Hour Ftg: ' Water Used: 300 Current Operation: RIH w/linerj Finish logging run #1. Run #2 logging. RIH and cleanout for 7" linerj Change top rams to 7" and RIH with 7" liner on drillpipe~ MUD TYPE-DISP WT:9~l VIS:40 PV:9 YP:5 FL:ll.4 SOLIDS:7 TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1065H: SAPC Daily Drilling Report -- PBU July 14, 1986 at 0600 hours Rig: AUDI-#2 Well: Y-24 (13-4-10-13) AFE # 120500 0600 Depth: 13,550' Day: 20 24-Hour Ftg: ' Water Used: 300 Current Operation' POH. Finish running liner and cemented with 295 sx Class "G" cement~ Drill 379' cement to liner top. POH for 6" bit. MUD TYPE-DISP WT:9.1 VIS:40 PV:IO YP:5 FL:13 SOLIDS:7 TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS _ 1065H: SAPC Daily Drilling Report -- PBU July 15, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 (13-4-10-13) AFE # 120500 0600 Depth: 13,508' Day: 21 24-Hour Ftg: ' Water Used: llO0 Current Operation: POH/Lay down D.P. Test liner lap to 3000 psi. OK. Cleanout to 13,508'. Test linerJ OK. Clean pits. Mix 9.6 ppg saltwater and displace. MUD TYPE-NaC1 WT:9.6 VIS:26 PV:l YP:l FL: SOLIDS: TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1065H: SAPC Daily Drilling Report -- PBU July 16, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 (13-4-10-13) AFE # 120500 0600 Depth: 13,$08 PBTD' Day: 22 24-Hour Ftg: ' Water Used: 2500 Current Operation: Logging. POH and L/D drillpipe. R/U to run logs. Logging. MUD TYPE-NaCl WT:9.6 VIS:26 PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS · 1065H: SAPC Daily Drilling Report -- PBU July 17, 1986 at 0600 hours Rig: AUDI #2 Well: Y-24 (13-4-10-13) AFE # 120500 0600 Depth: 13,508' Day: 23 24-Hour Ftg: ' Water Used: 900 Current Operation: Lay down. land it. Finish logginLg~ R/U to run tubing. Run 394 its. of 3-1/2" tubing with 9 GLM. D landing it. and R/D tubing tools. MUD TYPE-NaC1 WT:9.6 VIS:26 PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1065H: SAPC Daily Drilling Report -- PBU July 18, 1986 at 0600 hours Rig' AUDI #2 Well' Y-24 (13-4-10-13) AFE # 120500 0600 Depth: 13,508 PBTD' Day: 24 24-Hour Ftg: ' Water Used: 200 Current Operation' Turnkey move. Install adapter flange and 3" tree and test to 5000 psi. Displace tubing to diesel and set packer.. Rig released ~ 1800 hrs' 7/17/86. MUD TYPE- WT: VIS- PV' YP' FL' SOLIDS' TEMP-°F SURVEY - MD' ANGLE DIRECTION TVD SECTION COORDINATES DLS _ , , 1065H: S. ompc, tm~'ior~s bx,' GREAT LAND DIRECTIONAL DRILLING,INC fo= GYRODATA C ] I erst STANDARD ALASKA PRODLICTrOtg~'"OOMPANY We]] - Y-24 F;YRO -']osuz, e Dtrectior~ - S 33.87 W o;.. .... Clara f J ] e name · Y-.24F.;. DAT REdUNB'; F SURVEY INCORPORATED Compu t ct t or,: Su=vev dote': 8-.13-8d RADIUS OF CURVATURE 7-24-8~ Method'. - GYRO RKB Height.: 88.8 f~ ~EAS DRIFT 7RUVERT SLIBSEA SECTION DIRECTION DEPTH DG MN DEPTH DEPTH DIST ANGLE 0 0 0 0.00 -88.80 0.00 N 0.00 E O0 0 22 100.00 11'20 0.22 S 13.5S E 200 0 23 200.00 :121.20 0.47 S 51.80 E 300 0 24 2~.97 2~1.19 0.~? S 22.20 E 400 0 28 3¢9.99 311.1~ 1.0S S 34.B8 E SOO 0 41 499.~? 411.1~ 1.76 S 16.42 W SO0 2 12 599.~S S11.15 4.]4 S 13.57 W 700 3 ST 699.80 611.00 9.22 S 17.30 W 800 d 15 799.80 710.80 17.83 S 21.37 W 900 8 0 898.63 809.83 29.~5 S 21.~5 W 1000 9 26 997.~7 908.67 44.77 S 21.63 W 1200 10 41 1095.93 1007.13 61.84 S 21.82 W 2200 12 BB 1193.88 1105.08 81.56 S 22.70 W 1300 1~ 43 1291.05 1202.25 104.73 S 23.90 W lz:qO 26 30 1387.36 129fl.56 131.27 S 24.78 W 1500 27 12 1483.07 1394.27 159.93 S 25.85 W 1600 16 56 1578.66 1489.86 189.06 S 27.95 W 1700 18 35 1673.90 1585.10 219.33 S 25.70 W 1800 23 S 2767.33 167fl.53 254.48 S 24.83 W 1900 27 27 1857.75 1768.9G 296.68 S 25.82 W 2000 32 6 2944.~6 1856.16 345.04 S 24.93 W 2200 33 53 2029.30 1940.S0 398.16 S 2S.87 W 2200 37 8 2110.67 2021.89 45S.76 S 27.15 W 2300 40 43 2188.47 2099.67 517.99 S 24.98 W 2400 43 36 2262.60 2273.80 584.32 S 25.23 W RELATIVE COORDINATES FROM WELL-HEAD 0.00 N 0.00 E ,Q,.31 S 0.07 E 0.85 S 0.42 E 1.39 S 0.83 E 2.06 S 1.1P E 3.01 S 1.34 E 5.44 S 0.69 E 10.61 S 0.74 W 19.00 S 3.68 W 30.53 S 8.26 W 44.'60 S 13.88 W 60.82 S 20.35 W 7~.46 S 27.~7 W 101.10 S 37.30 W 125.62 S 48.3~ W 151.82 S 60.78 W 177.99 S 74.06 W 205.21S 87..82 W 237.36 S 103.00 W 275.93 S 121.25 W 320.11 S 142.20 W 368.63 S 165.24 W 420.59 S 191.16 W 477.02 S 218.76 W S37.79 S 247.24 W CLOSURE DISTANCE DG MN S · 0.00 N 0 0 0 E 0.32 S 13 32 60 E 0.95 S 26 20 35 E 1.62 S 30 46 11 E 2.37 S :30 0 49 E 3.30 S 23 58 48 E S.49 S 7 13 25 E 10.64 S 3 SB 23 W 1~.35 S 10 S7 35 W 31. d2 S 1S 8 6 W 46.71 S 17 17 25 W 64.14 S 18 29 4~ W 84.24 S 1~ 23 43 W 107.76 S 20 14 55 W 134.61 S 21 3 58 W 163.53 S 21 49 8 W 192.78 S 22 35 29 W 223.21 S 23 10 9 W 258.74 S 23 27 27 W 301.40 S 23 43 18 W 350.27 S 23 S7 9 W 403.97 S 24 8 42 W 462.00 S 24 26 31 W 524.79 S 24 38 12 W 591.90 S 24 41 24 W DOG'LEO dea/lO0 0.000 0.367 0.017 0.017 0. 067 0.217 I .517 1.750 2.301 1.750 .433 .250 .867 2. 168 .785 0.706 0.322 1.666 4.502 4.372 3. 658 2.798 3.283 3.700 2.886 -24 G',"F~O 8- 13-8~ RECORD OF SURVEY ~EAS DEP7 2500 2'700 - 30 SO00 -':"200 3300 3,4 O0 3500 3600 3700 3800 3900 40O0 4 -, .~, 0 ~.~ J .4300 ,4'40O 4500 46OO 4700 4800 4900 GO00 SlO0 5200 5300 5400 DRIFT IRUVERT H DG MN DEPTt4 46 58 ~°332.93 SO 2 2399.20 53 33 246].04 53 57 2520.]7 53 ? 2579.58 52 39 2339.90 52 52 ~,~00.42 52 40 2760.93 52 24 2822.76 52 22 2888.91 52 22 2944.20 S3 22 3004.82 53 48 3064.33 53 SS 3223.33 S4 28 3282.84 S4 S9 3239.39 SS 42 3296.47 56 1~ ~ 48 56 40 3407.79 56 SO 3462.62 56 24 3517.64 SS 25 3573.6~ SS 0 3630.75 S4 SO 3688.23 53 48 3746.56 53 55 3805.53 SS 42 3864.58 53 45 3923.75 53 38 3982.96 S3 2 4042.69 SUBSEA SECTION DIRECTION DEPTH DIST ANGLE 2244.25 654.62 S 25.82 W 2320.40 728.83 S 26.57 W 2372.24 806.67 S 2S.S7 W 2432,37 886.37 S 24.68 W 2490.78 965.80 ,S 24.90 W RELATIVE COORDINATE9 FROM WELL-HEAD 60~.90 S 277.86 W 669.10 S 310.9:! W 739.67 S 345.43 W 812.69 S 379.67 W 88~..71 S 413.40 W 255~.20 2044.70 S 26.03 W 957.72 S 4~7.70 W 26:12.62 2223.58 S 26.27 W 2029.2~ S 482.72 W ~o7~. 23 2202 42 S 25 57 W 1100 85 S 517.45 W 2732.96 2280.9S S 23.S0 W 1172.47 S SS1.67 W 27~4.21 233~.28 S 26.02 W 2243.73 S 586.05 W 2855.40 :1437.54 S 25.77 W 1314.81 S 620.53 W 29_'16.0'_t 2526.34 S 26.43 W 1386.24 S 655.55 W 2975.53 1595.92 S 25.28 W ]458.58 S 690.53 W 3034.33 2675.84 S 26.42 W IS31.27 S 723.67 W 3093.04 27S6.14 S 23.23' W 1604.26 S 761.02 W 3150.79 1836.91 S 2S.70 W 1677.96 S 796.12 W 3207.67 1918.26 S 25.27 W 1732.24 S 831.44 W 3263.68 2000.18 S 25.47 W ~827.12 S 866.87 W 33~8.~ 2082.48 S 24.38 W 2~02.68 S ~01.~8 W 3373.82 2264.98 S 24.45 W 2978.83 S 936.5S W CLOSURE DISTANCE DG MN S 662.94 S 24 46 46 W 737.81 S 24 SS 22 W 816.36 S 23 I 58 W 897.00 S 25 2 28 W 977.44 S 25 1 14 W 1057.19 S 25 3 25 W 1138.79 S 25 7 39 W 1218.40 S 25 10 33 W 1295.77 S 25 11 52 W 1374.89 S 25 13 48 W 1453.90 S 25 2S S7 W 1533.43 S 25 18 33 W 1613.78 S 25 20 3 W 1694.32 S 23 22 23 W 1773.61 S 25 22 41 W 1837.25 S 25 22 56 W 1939.S0 S 25 23 4 W 2022.33 S 25 22 54 W 2205.63 S 25 21 49 W 2189.26 S 25 19 39 W 3428.84 2247.44 S 23.23 W 2034.60 S 971.63 W 2272.76 S 25 18 35 W 3484.89 2329.55 S 27.67 W 2228.74¢S 2008.51 W 2355.55 S 25 20 59 W 3541.75 2422.22 S 27.78 W 2201.43 S 10q8.72 V 2q37.61 S 25 25 47 W 3599.43 2492.69 S 29.38 W 2273.29 S 1085.87 W 2519.32 S 25 31 55 W 3657.76 25?3.?0 S 30.03 W 2343.84 S 1126.12 W 2600.33 S 25 37 45 W 3716.73 2654.23 S 29.23 W 2414.03 S 2166.03 W 3773.78 2734.73 S 30.32 W 2484.08 S 1206.13 W 3834.95 2815.18 S 29.95 W 2553.80 S ~246.~0 W 3894.16 2895.64 S 31.35 W 2623.06 S 1287.80 W 3953.89 2973.71 S 29.83 W 2692.02 S 1328.73 W 2680.~0 2761.41 2841.82 2922.13 3002.09 S 25 46 SS W S 25 53 SS W S 26 i 7 W S 26 8 56 W S 26 26 22 W DOG LE6 dem/lO0 3.38] B. 098 3.57d 0.702 0.822 0. 873 0 .~3~ 0.427 0.270 0.380 0.156 1.072 1.001 0.819 0.948 0.398 0.719 051 .8'7 0.695 I .920 0.424 1. 082 1.127 0.335 0.736 0.244 1.044 I .257 GYRO 8-23-86 ,.qEAS DRIFT DEPTt4 ElIS MN 5500 51 5600 50 22 5700 50 31 ~0 51 16 b., O0 51 q9 6000 52 58 6100 53 59 6200 54 7 6300 54 S1 6400 SS SS 650O 56 48 6600 56 46 6700 56 51 6800 57 34 6900 57 38 70O0 57 37 7 '0 56 53 7~ 0 56 42 7300 56 44 7400 56 29 7500 SS S9 7600 SS 18 7700 Sq S9 7800 54 S7 7900 S4 16 8000 54 55 8100 54 19 8200 53 50 8300 53 33 8400 53 28 TRUVERT SUBSEA SECTION DEPTH DEPTH DIST 4204.02 4015.22 3054.58 4267.18 4078.38 3132.07 4230. fib 4:142.08 3209.15 4293.96 4205. 16 3286.75 4356. 15 4267.35 3365.05 4427.18 h328.38 3q44.25 4476.69 4387.89 3524.56 6535.40 44~6.60 3605.45 4593.49 450~.69 3686.79 4650.30 4561.50 3769.02 4705.70 4616.90 3852.17 4760.48 4671.68 3935.69 6815.23 4726.43 4019.24 6869.38 4780.58 4103.19 4922.97 q836.17 4187.48 4976.52 4887.71 4271.73 5030.61 q942.81 4355.60 5085.38 ~996.58 4438.98 5240.26 S051.46 4522.11 5195.29 5106.q9 4605.11 S250.87 5162.07 4687.77 5307.31 S228.51 g769.84 5364.46 5275.66 4851.37 5~21.87 5333.07 4932.70 5q79.77 5390.99 5013.73 SS37.72 5~48.92 5094.73 S595.63 5506.83 S175~77 5654.30 SSdS.SO 5256.24 S713.51 S626.71 S336.28 S772.99 5684.19 S416.47 RECORD OF SURVEY DIRECTION ANGLE RELATIVE COORDINATEg FROM WELL-HEAD S 32.00 W 2759.77 S S 32:18 W 2825.46 S S 33.98 W 2890.04 S S 33.92 W 2954.41S S 34.52 W 301E.16 S S 3S.SS,W 3084.03 S S 36.23 W 3149.13 S S 35.92 W 3214.56 S S 36.07 W 3280.42 S S 36.27 W 3346.85 S S 37.27 W 3413.S4 S S 37.08 W 3480.20 S S 36..97 W 3547.01 S S 36.83 W 3614.24 S S 37.S8 W 3681.48 S 1369.31W 1410.S0 W 1432.38 W 1585.42 W 1632.53 W 1680:20 W :1728.03 W 1776.60 W 1826.43 W 1876.98 W 1927.37 W '1977.84 W 2028.90 W S 38.20 W 3748.13 S 2080.77 W S 37.9G W 3814.34 S 2132.64 W S 39.28 W 3879.71 S 2184.85 W S 40.38 W 3943.8~ S 2238.31 W S 39.58 W 4007.69 S 2292.27 W S 40.43 W 4071.37 S 2345.72 W S 39.60 W 4134.39 S 2398.80 W S 41.12 W 4197.11S 2451.93 W S 39.92 W 42S9.3G S 2505.13 W S 40.45 W 4321.64 S 2557.73 W 'S 40.05 W 4383.85 S S 40.23 W 4446.17 S S 40.35 W 4'S07.94 S 'S 40.72 W 4569.19 S S' 34.07. W 4633.02 S 2610.39 W 2662.95 W '2715.32 W, 2767.69 W 28:t6.qBW CLOSURE DISTANCE DG MN S 3080.80 S 26 23 21W 3157.96 S 26 31 44 W 3234.5G S 26 41 S W 3311.54 S 26 51 16 W 3389.21 S 27 2 27 W 3467.68 S 27:12 23 W 3547.13 S 27 24 9 W 3627.18 S 27 35 43 W 3707.72 S 27 46 44 W 3789.16 S 27 57 38 W 3871.45 S 28 8 57 W 3.954.09 S 28 20 22 W 4036.84 S 28 31 7 W 4120.02 S 28 41 21 W 4203.54 S 28 S1 34 W 4286.97 S 29 2 12 W 4370.05 S 29 12 36 W 4452.61 S 29 23 ? W 4534.82 S 29 34 45 W 4616.94 S 29 46 S W 4698.77 S 2.9 56 54 W 4780.07 S 30 7 17 W 4860.84 S 30 17 36 W 4941.44 S 30 27 42 W 5021.81 S 30 37 8 W 5102.18 S 30 46 19 W S182.64 S 30.55 7 W S262 SS S :.3i. '3 44 W ., S342.06 S '31 12 ld W '5421.94 S' 31 17 46 W DOG LEG dea./lO0 2. 152 0. 973 i. 085 0.752 0.663 1.3~5 0.2~7 0.740 1.075 1.127 0.133 0.127 0.723 0.539 0.440 0.754 0.949 0.909 0.739 0.769 0.886 1.065 0.805 0.768 0.703 0.612 0.489 0.370 4.294 GYRO RECORD OF SURVEY 8-23-86 ,4EAS )EPTH 8500 8600 8700 7,0 9000 9200 9300 94O0 9500 9600 9700 9800 9900 tO000 10 "'0 I.O.. 0 [0300 10400 10500 10600 tO700 10800 10900 [1000 t1200' t1200 tlS00 ~2400 DRIFT TRUVERT SUBSEA SECTION DG MN DEPTH DEPTH DIST 53 46 5832.30 5743.50 5496.98 53 45 5892.42 5802.62 5577.62 53 35 5950.67 5862.87 5658.25 53 38 6010.00 5921.20 5738.6~ 53 38 6069.30 5980.50 5829.24 53 32 53 38 53 41 53 40 53 23 52 34 52 46 S0 S0 49 57 48 57 49 26 49 45 50 12 SO 39 50 33 51 4'1 S0 45 49 '12 47 44 45 SS 45 23 44 S1 44 15 45 15 6128.66 6039.86 5899.59 6188.03 6099.23 5980.08 6247.29 6258.49 6060.55 6306.52 6217.72 6141.09 6366.09 6277.29 6222.39 6426.42 6337.62 6301.12 6487.76 6398.96 6380.06 6550.28 6462.~8 6458.07 6624.03 6525.23 6535.10 6679.04 6590.24 6611.07 6744.51 6655.7~ 6686.66 6809.44 6720.64 6762.7~ 6873.76 6784.96 6839.28 6937.48 6848.68 6926.35 7000.95 6912.15 6993.59 7064.06 6975.26 7071.11 7126.39 7037.59 7149.26 7189.02 7200.22 7227.17 7253.33 7164.53 7303.68 7319.64 7230.84 7378.35 DIRECTION RELATIVE COOR'DINATE~ ANGLE FROM WELL-HEAD S 32.83 W 4700.20 S 2860.86 W S 32.27 W 4768.18 S 2904.25 W S 33.25 W 4835.92 S 2947.84 W S 32.67 W 4903.47 S 2992.63 W S 32.67 W 497~.25 S 3035.20 W S 32.05 W 5039.23 S 3078.17 W S 32.95 W 51'07.47 S 3120,81 W S 33.33 W 5275130 S 3164.26 W S 31.78 W 5243.20 S 3207.61 W S 33.50 W 5310.84 S 3250.94 W S 31.72 W 5378.08 S 3293.5~1 W S 32.32 W 5444.~8 S 3335.78 W 'S 32.50'W 5510.87 S 3377.61 W' S 35.95 W '5574.56 S 3420.93'W S 33.25 W. 5637. _10 S .3464.0'8'W S 33.53 W · 5700.21S 3505.68 S 33.88 W 5763.48 S 3547.89 S 34.07 W 5826.97 S 3590.67 S 34.57 W. 5890.63 S 3634.12 S 36.27 W' '5~53'60 S 3678.~0 CLOSURE DISTANCE DG MN S 5502.39 S 31 29 39 W 5583.03 S 31 20 43 W 5663.56 S 31 21 SS W 5744.03 S 31 23 1S W 5824.53 S 32 24 19 W 5904.99 S 31 25 6 W .5985.46 S 31 25 34 W 6065.99 S 31 26 32 W 6146.54 S 31 27 25 W 6226.85 S 31 28 20 W 6306.58 S 31 29 11 W 6385.55 S 31 29 35 W 6463.58 S 31 30 15 W 6540.53 S 31 32 10 W 6616.40 S 31 34 17 W 6691.95 S 31 35 31W 6767.95 S .31 36 56 W 6844.45 S 31 38 31W 6~21.44 S 31 40 29 W 6998.55 S 31'. 42 47 W S 35.85 W 6016,31 S 3724.56 W 7075.g0 S 31 45 39 W S 35.73 W 6079.74 S 3770L30 W 7153.91 S 31 48 17 W S 35.97 W 6142.93 S 3815.~5 W 7231.67 S 31 50 54 W S 36.28 W 6204.78 S 3861.0~ W 7308.03 S 31 53 35 W S 39.35 W 6263.91 S 3906.99 W 7382.48 S 31 57 11 W 7388.06 7299.26 7q51.02 S 37.93 W 6320.86 S 3952.52 W 7457.96 7369.26 7522.36 S 37.58 W- 6377.40 S 3996.32 W 7528.53 7439.73 7593.08' S 37.32 W 6433.65 S ~t039.'3g W 7599.79 7510.99 7663.06 S 38.38. W 6489.04 S 4082.44 W 7670.82 7582.02 7733.12 S 40.53 W 6543.3~ S 4127.18 W 7454.91 S 32 I 6 W 7526.07 S 32 4 22 W 7596.61 S 32 7 22 W 7666.42 S 32 10 31 W 7736.25 S 32 14 28 W DOG LEG dea/lO0 0.857 0. 369 0.658 0. 382 0.000 0.411 O. 119 0.900 1.006 1.190 .299 .882 .940 206 . .832 0.356 0.525 0.447 0.554 1.019 0.698 0.489 0.944 1. 561 2.230 1.958 0.562 0 .SSO 0.794 1.475 · - ,64 GYRO 8-23-86 RECORD OF SURVEY MEAS 3EPTI4 21500 11600 11700 J '00 1_.'00 12000 12100 12200 22300 12400 12500 12600 22700 12800 12900 13000 13"q0 I~ 0 13300 13400 13550 DRIFT DG MN 46 40 48 29 48 59 48 30 TRU\/ERT SUBSEA SECTION DEPTH DEPTH DIST 7740.33 7651.53 7804.6S 7807.78 77:18.98 7878.15 7873.49 7784.89 7953.07 7938.86 7850.06 8028.32 8004.811 79~6.01 81103.01 47 48 807:1.53 7982.73 8177.0S 47 :13 81139.07 8050.27 82S0.41t 46, 28 8207.48 8218.68 8322.93 45 41 8276.85 8188.05 8394.37 44 1t9 8347 . 25 8258 . 45 8464 . 71 43 57 43 3 43 27 ".,2 20 42 7 42:14 42 33 39 37 39 o 39 24 END OF 39 0 8418.71 8329.9~ 8533.99 849:1.25 8402.45 8601.83 8564.09 8475.29 8669.:11 8637.35 8548.55 8736.00 871:1.40 8622.60 8802.04 8786.09 8697.29 8867.27 8860.53 87711.73 8932.59 8935.90 8847.110 8996.33 9013.26 8924.46 9057.:18 9090.8~ 9002.03 92:17.48 GYRO SURVEY DATA 9207.20 9218.40 9207.32 DI S S S S S 'S S S S S RECTION ANGLE 38.53 W 39.82 W 40.32 W 3P.85 W 40.83,W 39.52 W. 39.82 W 40.32 W 41.93 W 41.70 W' 41.83 W 45.33 W 44.~5 W 44.90 W 44.:18 W 45.87 W 45.87 W 49.9O W S0.23 W 5:1.87 W FINAL STATI S S2.50 W RELATIVE COORDINATES FROM WELL-ltEAD 6598.83 S 41,72 66S6.05 S ,42:19 6723.74 S 4268 6771.64 S 4'3:16 682~..93 S 4365 6885".85 S 44:13 6~42'.61S 4460 6998.~3 S 4S07 7052,68 S 4GS4 7105161S' 4'602 .93 W .55 W .08 W .80 W -46 w ..52 W .59 W .54 W .91 W '. 26 W 7157.78 S 4648,85 W 7207.64 S 4696.30 W '7256.30 S 4744.53 W 7304.83 S 4792.25 W 7352.73 S 4839.3~ W 7399.72 S 4886.43 W 7446.2:1S 4934.35 W 7490.27 S 4983.08 W 7530.95 S 5031.67 W 7S70.62 S 5080.75 W ON EXTRAPOLATED' 7628.65 S S1SS.S1 W CLOSURE DISTANCE DG MN S 7807.55 7880.84 7955.55 80.30.56 8105.04 S 32 S 32 S 32 S 32 S ,32 -- -- -- 18 3O W 22 20 W 26 42 W 31 :1W 35 2~ W 8178.88 '8252.07 "8924.42 8395.69 8465.84 S 32 39 29 W S 32 43 ~4 W , ,, S 32'q7 5 W S, 32 51 22 W S 32' SS 51 W 8534.97 S 33 0 11 W 8602.63 S 33 5 ~4 W 8669.74 S 33:10 43 W 8736.48 S 33 1S 59 W 8802.40 S 33 21 7 W 8867.52 S 33 26 20 W 8932.74 S 33 31 52 W 8996.40 S 33 38 5 W 9057.20 S 33 44 53 W 91:17.48 S 33 52 58 W 9207.36 S 34 3 4 W DOC..; L E(~ d e ~/' 11 0 C:' .76£' 929 .73Z 1.OOd 0.60E 0.79E :1. 140 O. 874 0.869 1.862 0.688 :1. 167 0.388 :1. :147 :1.317 3.361 O. SgE 0. 682 0.22E '-24 GYRO 8-13-86 DATA iNTERPOLATED FOR EVEN 100 FEET OF' SUBSEA DEPTH MEAS. D E P 'r FI TRU VERT SUB SEA MD-TVD DEPTH DFPTtt D:IFF. VERTICAL CORRECT 87 89 0 0 0 28? 28? 200 0 0 289 28? 20O 0 0 .... 989 38? 300 '0 0 '489 ~89 400 0 0 589 589 500 0 0 689 689 60O 0 0 789 789 700 0 0 890 88? 800 99] 989 900 2 2093 2195 2298 ]402 1506 2621 - 16 _ ,24 '1936 2052 ~173 2300 Eq37 2584 27q7 1089 1000 4 2 1189 1100 6 2 1289 1200 9 3 1389 :[300 13 4 2489 2400 17 4 1589 :1500 22 1689 1600 27 2789 .1700 35 8 2889 2800 47 12 1989 1900 63 16 2089 2000 84 21 2189 2200 111 27 2289 2200 148 37 2389 ~300 2~5. 47 2489 2400 258 63 2589 2500 326 68 2689 2600 392 66 2789 2700 457 65 2889 2800 521 64 2989 2900 585 64 2915 3082 3246 3410 3574 RELATIVE COOR[jlNATES FROM WELL-ttEAD, 0.21 S O. 13 W 0.80 S 0.37 E 1.11 S 0.97 E 1,98 S 1..14 E 2.52 S '1.90 E 5.05 S 0.'79 E 9:97 S 0.26 W 18.08 S 8.8'1. W 2.9.30 S 7.65 W 43.27 S 13.36 W 59.60 S 19.81W 78.53 S 27.28 W 100.75 S 36,63 W 126.01S 48.57 W 153.42 S 61.55 W 180.75 S 75.51 W 209.87 S 90.06 W. 246.00 S 106.97 W 291.05 S 128.51 W 345.01 S 153.65 W 406.57 S 183.26 W 477.28 S 218.88 W 561.31S 258.27 W 658.68 S 304.94 W 773.84 S 361.62 W 896.80 S 418.53 W 1015.58 S 475.86 W 1133.69 S 533.15 W 1250.55 S 589.38 W 1367.5~ S 645.73 W Y-2~ GYRO INTERPOLATED FOR EVEN 200 FEET OF SUBSEA DEPTH 8-i[3-86 ME DE AS. PTH 3741 3912 4087 ',266 ,448 4626 4801 4972 5475 S68~4 57P2 5954 6122 6292 "469 6836 7023 7206 7388 7567 77~t2 7916 8O88 8258 8]~27 8596 8764 TRU \/ERT DEPTH 3089 °189~ 3289 ~'on9 3~89 3689 3789 388? 3909 089 z~289 ~,589 4689 4789 ~889 ~989 5089 5~89 5289 5389 5489 S589 5689 S789 S889 5989 SUB SEA DEPTH 3000 3100 3200 3300 3400 35OO 3600 3700 3800 3900 4000 z~lO0 4200 ~300 4400 ~500 4600 ~{700 4800 4900 5000 S]O0 5200 5300 SqO0 5500 5600 5700 5800 5900 MD-TVD DIFF. 652 723 798 877 959 1037 1183 12S2 14qS 1303 1703 ]780 1863 1947 203~ 2878 2353 8638 2707 2775 VERTICAL CORREC] 67 75 82 78 75 71 65 58 62 67 71 77 83 Bq 87 '83 88 7~ 75 7~ 72 7O 68 RELATIVE COOROlNATES FROM WELL-HEAD ]488.93 S 704.64 W 1613.1~ S 765.119 W 11742.17 S 826.70 W 1876.62 S 8~0.06 W 20115.10 S 952.90 W 2~48.0~ S 1018.62 W 2273.99 S 1086.26 W 2394.0S S 111G~.81[ W 2512.58 S ]222.7~ W 2G29.77 S ~2~.90 W 2744.0~ S 1357.62 W 2847.66 S 1~2z~.31 W 2949.12 S ~92.35 W 3054.07 S 1563.71 W 3162.59 S 1~2.38 W 3275.18 S 172q.00 W 3393.63 S ]B1[0.48 W 3S]q.7q S 1903.06 W 3638.76 S 1996.12 W 3763.20 S 2092.61 W 3883.75 S 8188.15 W q000.12 S 2286.00 W 4113.83 S 2381.5q W 4223.37 S 247~.~5 W ~331.2~ S 2363.~2 W 4438.9~ S 2656.6~ W 45q3.80 S 27q5.67 W 4650.81 S 2828.44 W 476G.15 S 2902.34 W 487~.28 S 2976.06 W -24 GYRO 8- 13-86 DATA INTERPOLATED FOR EVEN 200 FEET OF SUBSEA DEPTH MEAS. DE PTH TRLI VERT DEPTH SLIB SEA MD-TVD VERTICAL DEPTH DIFF. CORRECT 8933 6089 6000 284'4' 9102 6189 6200 2922 9270 6289 6200 2981 ~38 6389 6300 3049 .602 6489 6400 3113 9760 6589 6500 3171 9915 6689 6600 3226 20068 6789 6700 3279 20=~4 6889 6800 3335 20381 6989 6900 3392 10340 7089 7000 3431 10700 7189 7100 3311 10853 7289 7200 3364 11002 7389 7300 3612 11244 7489 7400 3655 7589 7500 3696 7689 7600 3737 7789 7700 3783 7889 7800 3834 7989 7900 3887 11285 1" "26 2 ?'2 11723 11876 12026 8089 8000 3937 12173 8189 8100 3984 12317 8289 8200 4028 12458 8389 8300 4069 12597 8489 8400 4108 12734 8S89 8S00 414S 12869 8689 8600 4180 13004 8789 8700 421S 13138 8889 8800 4249 13268 8989 8900 4279 68 69 68 64 S8 SS 53 S6 S7 S9 60 S3 48 43 41 41 46 S1, '53 SO 47 44 41 37 3S 35 34 30 RELATIVE COORDINATES FROM WELL-HEAD 49P3.55 s 3049.33 s108.37 s 3121.37 s222.77 s 3194.83 5336.04 S 3267.40 5446.09 S 3336.48 SS50.68 S 3401.96 W 5646. SO S 3470.24 W S743.47 S 3534.22 W 5842.01 S 3600.82 W S942.S0 S 3668.95 W 6041.43 S 3742.70 W 6142.89 S 3815.53 W 6237.56 S 3884.45 W 6321.46 S~ 3952.99 W 6402.02 S 4015.22 W 6481.1S S 4075.02 W 6557.46 S 4139.09 W 6640.41 S 4205.50 W 6727.29, S 4279.S6 W 681S.61 S 4353.03 W 6900.45 S 4425.55 6983.s~ 's 44~4.47 708z.Tz s 4563.0'~ 7z36.o9 s 462~.38 7208.63 S 4691.73 7272.92 S 7338.06 S 7401.39 S 7g63.92 S 7518.30 .S 4760.59 W 4825.09 W ~888.15 w 4,952.13 W SO 16.24 W GYRO MEAS. DEPTH 13397 DATA ZNTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH TRU VERT SUB SEA MD-TVD VERTICAL DEPTIq DEPTH DIFF. CORRECT 9009 9189 9000 4308 29 9100 4337 29 RELATIVE COORDINATES FROM WELL-HEAD 7570.91S 7620.13 S S078.B6 W S]qB.21W 8-13-86 SURVEY REPORT STANDARD ALASKA PRODUCTION .COMPANY PRUDHOE .BAY FIELD WELL NUMBER Y-24 JULY :24, 1986 Gyrodata Incorporated P.O. Box 19049 Houston. Texas 77224 713461-3146 August 14, 1986 Mr. Mike Martin Standard Alaska Production Company P. O. Box 196612 Anchorage, Alaska 99519-6612 RE: 'Prudhoe Bay Field Well Number Y-24 Dear Mr. Martin: Enclosed please find eleven (ll).copies of the completed survey of Well Number Y-24. We would like to take this.opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely, Russ Truby Operations Manager RT: ku Enclosures Gyrodata Services, Inc. Houston, TX/Lafayette, LA/New Orleans, LA/Ventura, CA/Aberdeen, U.K./Calgary, Alberta ~ G yr oda t a D i ~ e c t i o r~ a i S ~.~ r v e y STANDARD ALASKA PRODUCTION COMPANY PRUDHO£ BAY FIELD WELL NUMBER Y-24 Date Rur,: 24-JUL-86 6: 15:0 Job Nu~,'~ber: AKO7868043 Surveyc, r: R. TRUBY / F. SINGLETON Calculatic, r~ Method: RADIUS OF CURVATURE Survey Latitude: 70dew i6~,~ir, 4sec N Sub-sea Cnrrect i,-,r, fr,_-,~,~ Vertical Referer, ce: 88.8 ft Bearir, gs are Relative to, ]-RUE NORTH Pr,-,p,-,sed Well Di'rection: S S4deg 22~,'lir, Osec W Vertical Sect ior, Calculated from Well Head Locati,-,r, Clc, sure Calculated fr,-,m Well Head Locatic, r, H,-,rizor, tal Coc, rdir, ates Calculated fr,-,m L,-,cai H,-,rizorrtal Reference iTANDARD ALASKA PRODUCTION COMPANY 'RUDHOE BAY FIEI_[) IELL I'4UMBER Y-24 rnb Number: AK0786G043 A G y r c, d a t a D i r e c: t i ,-, r, a 1 Survey Pa ge 1 MEA S VER T SUB-SEA DEPTH DEPTH DEPTH f t f t f t · 0 .0 -88.8 100.0 100.0 11.2 200.0 200.0 111.2 300.0 S00.0 211.2 400.0 400.0 311.2 500.0 500.0 411.2 600. ID 600.0 5tl. 2 ];00.0 699.8 61:1.. 0 800.0 799.4 710.6 900.0 898.6 809.8 1000.0 997.5 908.7 ! 100.0 1095.9 1007.1 1200.0 1193.9 1105. 1 1300.0 1291.. 1 ] 202.3 1400.0 I387.4 1298.6 i500.0 1483.1 1394.3 1600.0 1578.7 !489.9 1700.0 1 67S. 9 ! 585. I 1800.0 1767.3 1678.5 1900.0 ! 85'7.7 'i 768.9 2000.0 19.45.0 1856.2 ;-' 100.0 2529. ~ 1 :~,~k:. 5 2200.0 2i 10.7 2021.9 2300.0 2188.5 2:099.7 2400. 0 2262. 6 2173. 8 INCL BORE HOLE VERT DOG-LEG BEARING SECTION SEVERITY deg rain deg rain ft deg/100' H 0 R I Z 0 N T A L CO 0 RD feet 0 0 N 0 0 E .0 .00 .0 N MUL'FISHOT SURVEY RUN INSIDE 3 1/2 iNCH TUBING (AKG043) 0 22 S I3 33 E .2 0 23 S 51 48 E .5 0 24 S 22 12 E .7 0 ;,28 S 34 35 E 1.0 0 41 S i6 '-"= ~-.,~ W 1.7 2 12 S 13 34 W 4.1 3 57 S I'7 18 W 9.2 6 15 S 21 28 W 17.8 8 0 S2i 5'7 W 9 26 S 2i 38 W 44.7 10 4]. S 2]. 49 W 61.7 12 33 S,-,-'-"-' 42 W 81.4 · "' '"~ I~ ' 14. 4. 3 S c.:,~ ,..,,~. W 104.5 i6 30 S ;_=:4 47 W 131.0 17 12 S ~-'"~'=.J 5I W 159.7 16 56 S 27 57 W ].88.8 i8 35 S '-":-- .-,~ 42 W 219.0 23 5 S 2.4 50 W 254. 1 27 27 S. .-_'-"=._, 49 W 296.2 31 6 S 24 56 W 344.5 ,~, ,~,~ S ;-'5,_.~':'-',: W 397.6 37 8 S 27 9 W 455.1 40 43 S 24 59 W 517.3 43 36 S 25 14 W 583.5 .OE .37 .3 S . i E .25 .9 S .4 E .20 1.4 S .8 E .11 2.1 S 1.2 E .53 3.0 S 1.3 E 1.52 5.4 S .7 E 1,,77 10.6 S .7 W ~.~¢. 19.0 S 3.7 W 1.75 30.5 S 8.3 W 1.44 44.6' S 13.9 W .1..24. 60.8 S 20.3 W 1.88 79.5 S 28, 0 W 2.18 10I. 1 S 37.3 W !.80 125.6 S 48.4 W .76 151.8 S 60.8 W · 67 178.0 S 74. I W 1.79 205.2 S 87.8 W 4. ~,0 ;--'~7.4 S 103.0 W 4.39 276.0 S 121.3 W 3.68 320.1 S 142.2 W 2.82 368.6 S 165.3 W 3.3.,"+ 42.0.6 S 19 i. 2 W 3.84 4-7'7.0 S 218.8 W 2.88 537.8 S 247.3 W CLOSURE DISTANCE BEARING ft d e g rn i r, .3 S i3 33 E i.0 S 26 16 E 1.6 S 30 43 E 2.4 S 29 59 E 3 3 S ""~ . ,:~ 59 E 5.5 S 7 15 E 10.6 S 3 58 W 19.4, S 10 57 W 3i.6 S i5 8 W 46.7 S 17 17 W 64.1 S 18 30 W 84.3 S i9 24 W 107.8 S 20 15 W 134.6 S 21 4 W 163.6 S 21 49 W 192.8 S 2:2 35 W .-,-~.~ S ;-'~ 10 W 258.8 S 23 2r 30i.4 S 23 43 ~.~,0.3 S z~ .'.:,7 W 404.0 S 24 9 W 452.0 S 24 27 W 524.8 S 24 38 W 591.9 S 24 4i W ~TANI)ARD ALASKA PRODUCTION COMPANY :'RUDHOE BAY FIELD 4ELL NUNBER Y-24 ]'ob Nur~ber: AKO786G043 A G y r c, d a t a D i r e c t i c, r, a 1 Survey Page 2 MEAS VERT SUB-SEA D EP'TH DE PT H DE PTH ft ft ft 2500.0 2331..5'. 9 2244. I 2600.0 2399.2 :-"3 i0.4 2700.0 2461.0 2372.2 2800.0 25;-20. ~:."" 2431 .4 290~?.i 0 ~,~ :::. 6 c::~.4~0.8 3000.0 263'9.9 2551. 1 3i00.0 2700.4 26i 1.6 3200.0 276~0.9 2672. t 3300.0 282 i. 8 2733.0 3400.0 2882.9 2794. 1 3500.0 2944.2 2855.4 3600.0 30eJ4.8 2916.0 3706.0 3064.3 2975.5 3800.0 .3! 23.3 3034.5 3900.0 318i. 8 3093.0 4000.0 3239.5 3150. 4.100.0 3296.4 3207. 4200.0 3352.4 S263. 4300.0 3407.7 S318. 4400.0 34~.12.6 33'73. 4500.0 3517.6 3428.8 4600.0 3573.7 3484.9 470(?;~. 0 3630.7 3541.9 4800.0 3688.2 7,599.4 49¢,0.0 3746.5 3657.7 INCl._ BORE HOL. E BEARING deg rain deg mir: 52 39 S 26 2 W ,-~ 5L-: S 26 10 W o~ .40 S :'5 34- W c. 24. S 25 30 W 52 12 S 26 i W 52 12 S~.°='o 4.6 W 53 11 S 26 2~5 W 53 46 S 25 1 i W 53 55 S 26 25 W 54 28 S 25 15 W 54 59 S 25.~+.-'"' W 55 41 S o:= il~ W L- ..J,. 56 II S c"'=o2:8 W 56 40 S 24 23 W 56 50 S 24 27 W VERT DOG-LEG H 0 R I Z 0 N T A L SEC]'ION SEVERITY C 0 0 R D ft de g/100' feet 653.7 3.40 727.8 3. 10 805.6 3.62 885.2 .80 964.5 .81 1122. 1 12.00...82: 1 ;:_'79. ': ..... 1357.5 1435.6 i514.3 1593.8 1673.6 1753.8 1834.5 1915.8 1997.6 2079.7 2162. i 56 24 S'--I'= ~-~ 1.4 W 2244.5 55 25 S 27 40 W 23;-26.5 ~ 0 S 27 4'7 W c'408.0 54 50 S 29c:I-' ~ {4 2489.5 53 48 S S0 2 W 2~70.4 1. 04 .24 .52 .26 .47 .20 1.11 1.16 1.01 1.10 .65 .82 .55 1.02 .16 .78 2.24 .43 1.16 601.9 S 277.9 W 669.1 S 310.9 W 739.7 S 345.4 W 812:.7 S 379.7 W 885.7 S 413.4 W 957.7 S 44.7.7 W I029.2 S 482. '7 W 1100.9 S 5i7.4 W 1172.5 S 551.7 W 1243.8 S 586.0 W 1314.8 S 620.6 W 1386. S S 655. o = W 1458.6 S 690.5 W 1531.3 S 725.7 W 1604.3 S 761.1Z~ W 1678.0 S 796.1W 1752.3 S 831.5 W 1827.~'c S 866.9 W 1902.7 S 902.0 W 1978.9 S 936.6 W 2054.6 S 971.6 W 2128.8 S 1008.5 W 220t.5 S i046.7 W 2273.~ S i085.9 W 2343.9 S 1!26. 1 W CLOSURE DISTANCE BEARING ft d e g m i n 663.0 S 24 .,W 737.8 S 816.4 S 25 c~ W 897.0 S 25 2 W 9'77.5 S 25 i W 1057.2 S 25 3 W .113~S.8 S 25 8 W 1216.4 S 25 11 W ,-~.:.8 S i~5 1~ W 1374.9 S 2.5 14 W i453.9 S 25 I6 W I53.S. 5 S 25 i9 W 1613.8 S 25 20 W 1694.6 S 2.5 21 W 1775.7 S 25 23 W 1857.3 S 25 23 W ].939.5 S 25 23 W 20:--12.4 S 25 2:3 W 2105.7 S 25 22 W 2189. S S 25 ~TANDARD ALASKA PRODUCTION COMPANY 'RUDHOF BAY FTELD tE:LL NUMBER Y-"24 I',:,m Number: AKO78GG043 A Gyr oda t a D i r e c t i c, r, a 1 Survey Page 3 MEAS VER"F SUB-SEA DEPTH DEF-'TH DEPTI4 ft ft ft 500~Z. 0 m8b~.~. 5 37i6.7 5!00.0 38E.,4.5 37'75.7 520~.;. 0 3923.7 383.4.9 5300,, 0 3982. 9 3894. i 5400.0 4042.7 ,~ ~,~. 9 Cv.~,. 0 4i04.0 4015. ="' 560~;~. 0 4167. ! 4078.3 5700.0 4230.8 4142.0 5800 0 4~93.9 ..~0,~. I 5q00... 0 ~m~o. ...... i 4267.3 6080.0 44i 7. ! 4328.3 6100.8 447'6. '7 4387.9 620 Z 0 4=;.= ...... ¢ .... ,. 4 4446.6 6300.0 4593.5 4~4.7 6400.0 4650.3 4561.5 6500.0 4705. '7 4616.9 6~0E:~. 0 4760.5 467 i. 7 570e. 0 4815.2 4726.4 6800.0 4869.4 4'780.6 ~dEO. 0 49,=.~. 0 4834. ~ 7060.0 4976.5 4887.7 7100. 0 5030. E, 4.941.8 7200.0 5085.4 4996.6 7300.0 5140.2 5051.4 7400.0 5 .1.95.3 5 i06.5 INCL BORE HOLE BEAR T NG deg mir, deg mir, VERT DOG-LEG H 0 R I Z 0 N T A L C L 0 S U R E SFCTION SEVERITY C 0 0 R D DIoTANCE BEARING i-'t deg/100' feet f't deg m i r, 2650.9 .66 2'731.3 .91 P81 i. 7 .30 2892. ! 1.29 2972.2 1.51 ,$K ,:) 1 0 ~. 41 3128.5 .98 3205.5 1.~' 3283.1 .75 3361.4 .74 3440.6 1.40 3521.0 1. I6 360 i. 9 .29 3683.2 . 75 3T65. ~ ~ 1.08 3848.7 1.22 3932.2 .16 4015.8 . 13 4099.8 .71 4184. 1 .64 4268.4 · 51 4.~.J,-..~ . ,' 5 4435.8 1.. I4 45i9.0 1.09 4602.. 1 .88 2414. 1 S I166.0 W 2484. ! S 1206. i W 2553.8 S 1246.6 W 26;:'3.1 S !2.8-/. 8 W 2692.0 S !328.7 W 2759.8 S !36'9.3 W 2825.5 S 1410.5 W 2890.1 S 14.52.6 W 2954.4 S 1495.9 W 3~19.2 S 1539.9 W 3084.0 S t585.4 W 3149. I S 1632.5 W 3214.6 S 1680.2 W 3280.4 S 1728.. 0 W 3346.9 S i'776.6 W 3413.5 S 1826.4 W 3480.2 S 18'77.0 W 3547.0 S 1927.4 W 3614.2 S 1977.8 W 3681.5 S 2028.9 W 3748. 1 S 2080.8 W 381.4.3 S 21~,-.' 6 W 3879.7 S 2184.8 W 3943.8 S 2238.5 W 4007.7 S 2292.3 W 2680.9 S 25 W 2761.4 S 2:5 W ;=_'841.8 S 26 I W 2922.1 S 26 9 W 3002.1 S 26 16 W 3080.8 S 26 23 W 3t58.0 S 26 32 W 3234.. 6 ~ 26 41 W 33!1.6 S 26 51 W 3389.2 S 27 ! W 3467.7 S 27 i2 W 3547.! S 27 24 W 3627.2 S 27 36 W 370'7.7 S 27 47 W 3789.2 S 27 58 W 387t.5 S 28 9 W 3954. i S 28 20 W 4036.8 S 28 3i W 4120.0 S 28 41 W 4203.5 S 28 5- 4286.9 S 29 2 W 4370.0 S 29 13 W 44~,-..6 S 29 '-'" W 4534.8 S ?9 35 W 4616.9 S 29 46 W ~TANDARD ALASKA PRODUCTION COMPANY 'RUDHOE BAY FIELD ~EI._L NUMBER Y-24 [,:,b Number: AKO78~G043 A Gyr oda t a D i r e [:: t i c, n a 1 Survey MEAS VERT SUB-SEA DEPTH DEPTH DEPTH ft ft 'Ft 75012.0 5251Zi. 8 5162.0 7600.0 5307.3 52i8.5 7700 0 536/+. 4 =""~= . ..,,:::, ,J. 6 78~0.0 542 i, 8 5333.0 7900.0 5479.7 5390.9 8000.0 55.37.7 5448. 9 8!0(?,i 0 =='~'~= 6 55~6 8 . 8200. 0 5~.54.3 5565. 5 8300. BI "':' ~ i o~ ~ 5 5624.7 84.00. 0 5773. 0 5684. 2 8500.0 5832.3 574.3.5 8600.0 5891.4- Jo,~,"'. 6 I~I ,'- · 8700.0 5 950.6 ,. 8o 1 8 8800.0 6010. ~Z ~:q., ;::'" 1. '2 8900.0 6069.3 5980, 5 9000.0 61~'-'8. S 603q._ 8 9100.0 6188.0 ~099.2 9200.0 6247.3 6158. 5 9300.0 6 3t3,":-.~.. 6 6217.8 9400.0 6366. 1 6277.3 =~ ~.. 0 64,~6.5 6337.7 96~0.0 6487. 8 6399.0 970(;3 0 ' =='"' ,.5 ,. 6o~b. ~ ,346 t. 5 98~0.0 66 i 4. i :,,._,=,_,."='-'=' ,5 .... ':...':q'~ ---, 990~] 0 6679 1 6..'.~,~:.,~ INCL BORE HOLE BEARING d e g rn i n d e g r,'~ i r. 53 46 S 32 50 W 53 45 S 32 I G W 53 35 S ,33 1= W,.,~ 53 38 S ,'72 40 W 53 38 S 32 4-0 W 53 32 S 32 3 W 53 38 S 3I 5'7 W 53 4i S 33 20 W 53 40 S 31 47 W 53 13 S 33 30 W 52 34 S 31. 4.3 W 51 46 S 32 19 W 50 50 S 32 30 W · 49 57 S d5 ,~7 W 48 57 S 33 15 W VERT DOG-LEG H 0 R I Z 0 N T A L C L [) S U R E SECTION SEVERITY C 0 0 R D DioTFiIIE,E BEARING ft deg/!00' feet ft deg rain 4.684.8 .87 4766.9 .98 4848. ''=' o 1.29 4.930.0 ., 98 ~ti i 8;:' 5092. 1. .74 5173.2~,.- . 63 ~:,J~. 8 . 49 r~ '~ '~ "". ~,:,. 9~''' .41 5414. i 5.35 5897. 1 .52 5977.5 . i3 6058.0 1. 12 6138.6 1.25 6218.9 i. 46 6298.6 1.57 63'77.5 .93 6455.5 .94 6532.5 ".-'. 80 6608.5 2.29 4.071.4 S 2345.7 W 4134.6 S 2398.8 W 4.197. ! S 24.5i. 9 W 4259.4. S .-o.e.~. i W 4321.6 S ,",j~7.7 W 4383.8 S 261gl. 4 W 4.446.2 S 2662.9 W 4~7.9 S 2715..:', W 4569. F' S 2767.7 W +bd, d,. 0 S i_::816 4. W 4700.2 S 2860.8 W 4768.2 S 2904.2..: W 48,35.9 S 294.7.8 W 4907,.5 S 2991.6 W 4971. ;-.' S ,.stZ.. e,,.,. 1 W 5039.2 S 3078.1. W 5107.5 S 3120.8 W 5175.3 S 3164.2 W 5243.2 S 3207.6 W 5310.8 S 3250.9 W 5378.0 S 3293.9 W 5445.0 S 3335.7 W 55i0.8 S 3377.6 W 5574.5 S 3420.9 W 5837. i S 3464.0 W 4698.8 S 29 ~ W 4780, I S 30 W 486gl.8 S 30 18 W .494.1.4 S 30 ;.-]'.8 W ','5021.8 S 30 37 W 5102.2 S 30 4.6 W 5182.6 S 30 ='=' 5262.5 S 3I 4 W ,Jo4. c..O S Jl 1~ W 5421.9 S 3t !8 W 5502.3 S 31 20 W 5583.0 S 31 21 W 5663.5 S ,2,:i. ;F.'2 W 5744, 0 S 31 ,::...'-',:,'" W 5824.5 S ,31 24 W =~ ,.~. 0 S 31 ;--',~ W 598'=,...,.4 S 31 26 W 6066.0 S 3i 27 W 6146.5 S 31 27 W 6226.8 S 31,'::.'",' 6306.5 S 31 29 W E,d~o.o S 31 30 W 6463.5 S 31 30 W 6540.5 S 31 32 W 66i6.3 S 3! 34 W ~TANDARD ALASKA PRODUCTION COMPANY )RUDHOE BAY FIELD ,~EL.L NUMBER Y-24 T,:,b Number: AK07863043 A Gyr:,data D i r e c t i o n a 1 Survey Page 5 MEAS VERT SUB-SEA DEPTH DEPTH DEPTH ft ft ft 10000.0 6744.6 6655.8 10100.0 68~.)9.5 6720.7 10208.0 6873.8 6785.0 1030D. 0 ~.,:.7.5 5848 7 10400.0 7001.0 6912.2 10500.0 7064. i 6975.,.., TM 1060gi. 0 '7 i2G. 5 7037.7 10700.0 7189. :L 7100. ,.3 10800.0 7253.4 '7164.6 10900.0 7'319.7 7230.9 i 1000. ~.7 7388. i 7299.3 11100.0 7458.0 7369.2 1 :L 200.0 7528.6 '743'3.8 i 1300.0 7599.9 751 i. i 11400.0 7670.9 7~,8~. 1 11500.0 774.0.4 7651.6 1 i600.0 7807.9 7719. i 11700.0 7873.6 7784.8 11800.0 7939.0 7850.2 i 1900.0 8004.9 7916. 1 12000.0 8071.6 7982.8 12100.0 8!39.2 8050.4 12200.0 820'7.6 8 i i8.8 1230~.:'~. 0 8276.9 8!88. 1 i2408.0 8347.3 8258. o INCL BORE HOI...E BEARING d e g m i r~ c'l e g ~',~ i r, 51 12 S 35 51 W 51 41 S -' ~,.~ 44 W 50 45 Sc',~'~ 58 W 49 12 S 36 1.7 W 47 44 S 39 21 W 4.5 55 S 37 56 W 45 23 S 37 35 W 44 5t S 37 19 W 44 15 S 38,.:.a'-'~ W 45 i5 S 40 32 W 46 40 S 38 38 W 4~ 29 S 39 49 14 49 22 S 4.0 19 W 48 59 S 39 5i W 48 30 S 40 58 W 47 48 S 39 3 i W 47 13 S 39 49 W 46 28 Si 4:~ 19 W 45 4i S 4i 56 W 44 49 S 41 42 W VERT DOG-LEG SECTION SEVERITY ft deo/100' 6684. 1 .40 6760. J. .54 (5836.7 .46 69t. 3.7 .60 699 i. 0 1.33 7068.5 .72 7i46.7 .50 q5 7224.6 .: '7301.2 :1.. 57 7375.9 ~:";. 73 7448.6 2. 10 7520.0 .59 7590.7 .56 7660. '7 .96 7730.9 1.81 7802.4 2.03 '7876.0 2.04 795 I. 0 .96 8026.3 .52 8101. i .88 8175.2 1.20 8248.6 .64 832 t. 2 .83 8392.7 1.40 8463. i .88 H 0 R I Z 0 N T A L CO 0 RD feet 5700.2 S >='"?1= ooc~. 6 W ,.~7o~. 5 S J,,~4-7.8 W 58;',:]7.0 S 3590.6 W 5890.6 S 3634. i W 5953.6 S 3678.8 W 6016.3 S 3724.5 W 6079.7 S 37'70. ;3 W 6142.9 S 3815.9 W 6204.8 S 3861.0 W 6263.9 S ~d~.6.9 W 6320.9 S 3952.5 W 6377.4 S 3996. ;3 W 6433.6 S 4039.3 bi 6489.0 S 4082,. 4. W o,~+,~.4 S 4127 1 W 6598.8 S 4172.8 W 6656.0 S 4219.5 W 6713.7 S 4268.0 W 677i.6 S 4316.7 W 6,8;--_'8.9 S 4,7;65.4 W 6885.8 S 4413.4- W 6942.6 S 4460.5 W 6998.4 S 4507.4 W 7052.7 S 4554.8 W 7105.6 S 4602.2 W CLOSURE Di,~ -'c '- oT~.~I~CE BEARING ft deg rn ir, 6691.9 S 31 .W 6'767.9 S 31 ,. ~4 684 4.4. S 3I 3'~ W 69;31.4 S 3i 40 W 6998.5 S 3i 43 W 7075.9 S 31 4.6 W 7153.9 S 3J. 48 W 7231.6 S 3I 5i W 7308.0 S 31 54 W 7382.4 S 31 57 W '7454..9 S 32 i W 7526.0 S a-"-',: 4 W '7596.6 S 32 7 W 7666.4 S 32 10 W '7736.2 S 32 14 W 7807.5 S .32 i8 W 7880.8 S 32 22 W 7555.5 S 32 27 W 8030.5 ;~-~ 32 31 W 8~.~.~." ~'~= 0 S 32 ,..7:-- 8178.8 S 32 39 W 8252.0 S 32 43 W 8324.4 S 32 4.7 W 8395.6 S 32 5i W 8465.8 S 32 58 W ;TANDARD ALASKA PRODUCTION COMPANY :'RUDHO£ BAY FIELD IE:LL NUi',IBER Y-24 ~-',b Nur~ber: AK(~786G043 A Gyr oda t a D i r e c t i ,", r~ a 1 Survey Pa r:~e 6 MEAS VERT SUB-SEA INCL BORE HOLE VERT DOG-LES DEPTH DEPTH DEPTH BEAR]:NG SFCTION SEVERITY ft ft ft cleg r~in deg r~ir, ft deg/100~ 12500.0 8418.8 8.330.0 43 57 S 4:i. 50 W 8532.5 .88 1;::'6e l~. .0 8491. S 8402.5 43 3 S 45 20 W 8600.4 ¢.."' 57 12700.0 8564.2 8475.. 4 43 ¢.'-"*/ S 44 9 W 8667.8 . 90 12800.0 8~37. 4 8548.6 42 2~ S 44 54 W 8734. E~ 1.23 i2900.0 871i.5 8t522.7 42 7 S 44 t! W 8800.9 .53 13000.0 8786.2 8697.4 41 14 S 45 ':"':' -' ,.~. W 8866. d, 1.42 13100.0 8860.6 8771.8 -'" ,4.,.~ 5;-'" W 893 t. 7 ..... 1. ,~ i 1,.7200.0 8936.0 884.7.2 39 37 S 49 =',..~,~ W 8995.6 d,." 94 i3400.0 9090.9 5002. 1 39 14 S 5i 5~ W 9117.0 1.05 Final Station Cl,:sure: 9!i7.4 feet South 33 deg 51 r~ir~ 56 :sec West H 0 R I Z 0 1'4 T A L CO 0 RD feet 7157.8 S 4648. '7 W 720'7.6 S 4696.2 W 7256.3 S 4744.4 W 7304..8 S 4'792. I W 7352.7 S 4839.3 W '7399.7 S 4886.3 W 7446.2 S 4.-.934.2 W 7490.2 S 4983.0 W 7;3~.~. '9 S 5031.6 W 7570.6 S 5080.6 W CLOSURE DI STC:INCE BEARING f t d e g r~ i r~ 8534.9 S 33 W 8602.6 S 33 ,,W 8669.7 S 3:.'3 li W 873;(..--,. 4S 33 16 W 88~2.3 S 33 2i w 8867.4 S 3,3 26 W 8932.6 S ,.33 ,:72 W 8996.3 S 33 38 W 9057.1 S 33 45 W 9ii7.4 S 33 5;=_` W GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB--SURFACE DIRECTIONAL SURVEY STANDARD ALASKA PRODUCTION COMPANY COld'IF'ANY Y-F'AD WELL NO. 24 WELL NAME PRUDHOE BAY I..OCATION AL686D23 MWD & SINGLE SHOT 7-17-06 JOB NtJ~BE:F~ TYF:'E SURVEY DATE NA~E T I TI...E S I GNATtJRE 500 FT 13155 FT DEF'TH INTERVAL. FRO~ TO THIS IS A RECORD OF A WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR 'FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL DRILLING,INC 7-17186 Client .............. : STANDARD ALASKA PRODUCTION COMPANY Well ................ : Y-PAD WELL N0.24 Closure Direction...: S 34.37 W Moqnet~c Deeltnotion: 31 deg 30 min E Ooto file nome - Y24.DAT RECORD OF SURVEY IWell ossumed ve~ticol to Computotion: RADIUS OF CURVATURE Survey dote: 7-1?-86 Method - MWD TOOL READINGS & SS RKB Height.- 88.9 ft S00.0! MEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 500 0 0 500.00 411.15 812 S 42 811.49 722.64 1173 11 42 1168.17 1079.32 1354 IS 30 1344.06 1255.21 1SSO 18 4 1531.68 1442.83 0.00 N 0.00 E 15.22 S 23.40 W 68.98 S 25.S0 W 111.16 S 28.00 W 167.39 S 26.90 W 0.00 N 0.00 E 14.23 S 6.16 W 63.91 S 28.75 W 101.91 S 47.90 W 152.18 S 74.01 W 1638 16 42 1615.65 1526.80 1827 23 12 1793.21 1704.36 2016 30 4 1942.03 1873.18 2206 34 24 2120.85 2032.00 2394 42 24 2266.06 2177.21 193.62 S 33.40~.W 257.92 S 28.00 W 342.12 S 28.00 W 445.79 S 30.10 W S44.47 S 27.30 W 174.90 S 87.26 W 230.24 S 120.25 W 305.04 S 140~02 W 396.04 S 210.SB W S00.67 S 267.85 W 2583 48 34 2398.44 2309.61 698.23 S 27.60 W 620.24 S 2701 S2 42 2473.27 2384.42 788.94 S 29.00 W 700.56 S 2959 S3 34 2627.99 2539.14 993.93 S 26.20 W 883.S0 S 3197 S2 42 2770.72 2681.87 1182.61 S 26.90 W 1053.87 S 3576 S2 30 3000.92 2912.07 1481.14 S 26.90 W 1322.37 S 329.96 W 373.21W 468.8S W SS3.98 W 690.20 W 3934 54 24 3214.11 3125.26 1744.18 S 26.60 W 1579.17 S 819.64 W 4239 S4 18 3387.S1 3298.66 2014.45 S 26.20 W 1803.90 S 931.19 W 4614 SS 30 3598.87 3510.02 2324.30 S 28.00 W 2081.79 S 1073.40 W 4904 53 54 3766.44 3677.59 2560.00 S 30.40 W 2288.38 S llB8.BS W S291 S3 S4 3993.28 3904.43 2870.19 S 29.70 W 2557.64 S 1344.63 W SSB2 SI 24 4149.81 4080.96 3101.11 S 32.60 W 2755.58 S 1464.26 W 6041 S2 48 4451.76 4342.91 3443.23 S 36.10 W 3054.SS S 1448.59 W 6335 54 34 4625.81 4536.94 3700.08 S 35.70 W 3244.47 S 1807.52 W 66~,~ 6'~ 30 4807.40 4718.55 3959.85 S 35.50 W 3457.74 S 1958.77 W 7005 56 0 5006.07 4917.22 4251.42 S 37.S0 W 3692.28 S 2132.33 W CLOSURE DISTANCE DG MN S 0.00 N 0 0 0 E 1S.S1 S 23 24 0 W 70.08 S 24 13 4 W 112.41 S 25 10 27 W 169.22 S 25 56 9 W 195.44 S 26 30 57 W 259.75 S 27 34 39 W 344.47 S 27 40 53 W 448.56 S 27 59 57 W S67.82 S 28 B 47 W 702.55 S 28 0 44 W 793.77 S 28 2 45 W 1000.20 S 27 57 14 W 1190.60 S 27 43 45 W 1491.66 S 27 33 43 W 1779.21 S 27 25 SO W 2030.07 S 27 lB 12 W 2342.23 S 27 16 34 W 2578.77 S 27 27 10 W 2889.56 S 27 43 56 W 3120.46 S 27 59 7 W 3480.58 S 28 38 46 W 3715.74 S 29 6 27 W 3974.01 S 29 31 52 W 4263.77 S 30 0 25 W DOG LEG de '~,1 O0 0.00(] 1.82? 1. 662 o 1. 326 1.71: 3.47¢ 3.65: 3.33~. 3.26: 3.28; 3. SS! 0 781 0.0S 0.53 0.63 0.38 0.77 0.11 1.OE 0. S? 0.6] 0.26 0.4~ Y-PAD WELL NO. 24 7- 17-86 RECORD OF SURVEY MEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 7290 56 0 5165.44 5076.59 4487.28 S 38.00 W 3879.10 S 2276.98 W 7642 SS 24 5363.80 5274.95 4777.03 S 40.30 W 4104.59 S 2460.55 W 7932 54 42 5529.93 5441.08 5013.60 S 39.60 W 4286.81 S 2613.18 W 8216 54 0 5695.46 5606.~1 5243.14 S 41.00 W 4462.81 S 2762.44 W 8385 53 30 5795.39 5706.54 5378.91 S 37.50 W 4568.33 S 2848.66 W 8682 53 30 5972.05 5883.20 5617.57 S 32.60 W 4763.72 S 2985.73 W 9155 53 24 6253.73 6164.88 5997.32 S 32.20 W S084.55 S 3189.33 W 9533 52 36 6481.22 6392.37 6298.95 S 31.90 W 5340.42 S 3349.53 W 9816 49 54 6658.34 6569.49 6519.51 S 32.90 W 5526.75 S 3467.77 W 10006 49 18 6781.48 6692.63 6664.16 S 33.30 W 5647.96 S 3546.79 W 10479 50 30 7086.14 6~97.29 7025.95 S 34.70 W 5947.90 S 3749.10 W 10762 50 12 7266.72 7177.87 7243.82 S 35.70 W 6125.95 S 3874.70 W 10985 46 54 7414.32 7325.47 7410.85 S 36.80 W 6260.72 S 3973.52 W 11329 44 0 7655.62 7566.77 7655.72 S 37.10 W 6456.61 S 4120.87 W 11612 48 18 7851.63 7762.78 7859.39 S 38.50 W 6617.83 S 4245.92 W 11986 48 18 8100.43 8011.58 8137.84 S 38.90 W 6835.76 S 4420.52 W 12270 46 36 8292.~7 8203.62 8346.35 S 39.20 W. 6998.23 S 4552.32 W 12554 43 54 8492.39 8403.54 8547.08 S 40.60 W 7152.95 S 4681.68 W 12740 ~3 18 8627.09 8538.24 8674.50 S 41.30 W 7249.83 S 4765.75 W 13093 40 18 8890.21 8801.36 8906.51 S 46.30 W 7419.57 S 4928.53 W CLOSURE DISTANCE DG MN S -- ~498.01 S 30 24 44 W 4785.60 S 30 56 28 W 5020.50 S 31 21 57 W 5248.59 S 31 45 26 W 5383.73 S 31 56 47 W 5622.06 S 32 4 41W 6002.04 S 32 5 54 W 6303.92 S 32 5 46 W 6524.60 S 32 6 23 W 6669.27 S 32 7 40 W 7030.88 S 32 13 27 W 7248.49 S 32 18 49 W 7415.22 S 32 24 8 W 7659.60 S 32 32 52 W 7862.80 S 32 41 2 W 8140.55 S 32 53 23 W 8348.59 S 33 2 38 W 8548.85 S 33 12 19 W 8675.96 S 33 19 10 W 8907.33 S 33 35 40 W DOG LE( deg/lOI O. 12: 0.47, 1.37 1.06, 0.05; 0.21' O. 97. 0.33~ .30 .23 .SO .84 .54 ~' 06 50 0.98 0.36 1.03 13155 39 48 8937.67 8848.82 8945.48 S 47.20 W 7446.91 S 4957.59 W 8946.18 S 33 39 10 W 1.00 Y-PAD WELL NO. 24 7- 17-86 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH MEAS. DEPTH 89 189 289 389 TRU VERT DEPTH 189 289 389 489 SUB SEA MD-TVD VERTICAL DEPTH DIFF. CORRECT 0 0 0 100 0 0 200 0 0 300 0 0 400 0 0 RELATIVE COORDINATES FROM WELL-HEAD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 589 589 500 0 0 0.90 N 0.89 689 689 600 0 0 0.49 S 5.68 789 789 700 0 0 10.95 S 7.61 890 889 800 ~ 1 22.19 S 9.57 992 989 900 3 2 34.93 S 14.89 1089 1789 1000 4 1 1100 S 1 1200 8 3 1300 12 4 1400 16 4 1093 1500 2'1 G 1600 27 6 1700 33 6 1800 45 12 1900 S9 14 2089 2000 79 2189 2100 105 2289 220O 138 2389 2300 180 2489 2400 238 1610 1716 1822 1934 2048 20 26 33 42 58 W W W W W 2168 2294 2427 2569 2727 2894 2589 2500 305 3060 2689 2600 371 3227 2789 2700 438 3391 2889 2800 502 3556 2989 2900 S67 S0.44 S 21.22 W 67.89 S 30.63 W 89.31 S 40.40 W 113.18 S S3_86 W 139.99 S 67.79 W 168.66 S 81.57 W 195.2S S 100.20 W 228.63 S 119.38 W 270.41S 141.61W 319.50 S 167.6G W 377.77 S 197.34 W 443.05 S 237.11 W S20.37 S 278.01W 611.43 S 324.68 W 718.68 S 383.20 W 67 836.S8 S 445.40 66 956.70 S S04.63 67 107S.03 S S64.72 64 1191.74 S 623.93 65 1308.31S 683.07 W W W W W Y-PAD WELL N0.24 7-17-88 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 3724 3892 4085 4241 4420 4598 4772 4944 5114 5283 5449 5813 5776 5939 8104 8273 6445 8820 6797 8974 7153 7332 7509 7888 7880 8033 82O5 8374 8542 8710 3089 3000 835 88 3189 3100 703 88 3289 3200 778 73 3389 3300 852 78 3489 3400 931 79 3589 3500 1009 78 3889 3800 1083 74 3789 3700 1155 72 3889 3800 1225 70 3989 3900 1294 89 4089 4000 1380 88 4189 4100 1424 84 4289 4200 1487 83 4389 4300 1SSO 63 4489 4400 1815 85 4589 4500 1684 89 4889 4800 1758 72 4789 4700 1831 75 4889 4800 1908 77 4989 4900 1985 77 5089 SO00 2064 79 5189 5100 2143 79 5289 5200 2220 77 5389 S300 2297 77 S489 S400 2371 74 5589 SSO0 2444 73 5689 5800 2518 72 5789 5700 2585 89 5889 SBO0 2853 88 5989 5900 2721 88 RELATIVE COORDINATES FROM WELL-HEAD 1427.44 S 1548.39 S '1875.31S 1805.89 S 1939.03 S 743.38 W 804.21 W 887.80 W 932.07 W 996.42 W 2072.71 S 2195.18 S 2314.89 S 2433.44 S 2552.38 S 1058. SO W 1132.06 W 1204.39 W 1273.32 W 1341.81 W 2688.08 S 2778.02 S 2884.73 S 2995.81S 3094.99 S 1405.83 W 1477.28 W 1544.53 W 1609.87 W 1898.04 W 3205.27 S 3319.49 S 3438.02 S 3555.45 S 3877.07 S 1777.87 W 1859.93 W 1943.28 W 2027.42 W 2110.00 W 3789.81 S 3908.27 S 4023.23 S 4132.04 S 4241.72 S 2206.81W 2298.10 W 2386.71W 2483.79 W 2575.77 W 4350. S1 S 4459.20 S 4581.29 S 4870.24 S 4782.83 S 2885.41W 2752.42 W 2843.23 W 2923.28 W 2997.94 W Y-PAD WELL NO. 24 7- 17-86 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 8878 9046 9213 9380 9545 9705 9863 10017 10173 10328 10483 10795 10947 11091 11234 11377 21521 11668 11818 11969 12117 12265 12407 12549 12687 128~ 12957 13091 6089 6000 2789 68 6189 6100 2857 68 6289 6200 2924 67 6389 6300 2991 67 6~89 6400 3056 65 6589 6500 3116 60 6689 6600 3174 58 6789 6700 3228 54 6889 6800 3284 56 698~ 6900 3339 SS 7089 7000 3394 SS 7189 7100 34S1 S7 7289 7200 3S06 SS 7389 7300 3558 S2 7489 7400 3602 44 7S89 7500 3645 43 7689 7600 3688 43 7789 7700 3732 44 7889 7800 3779 47 7989 7900 3829 SO 8089 8000 3880 51 8189 8100 3928 48 8289 8200 3976 48 8389 8300 4018 42 8489 8400 4060 42 8589 8500 4098 38 8689 8600 4134 36 8789 8700 4168 34 8889 8800 4202 34 RELATIVE COORDINATES FROM WELL-HEAD 4896.63 S 3070.45 W 5010.56 S 3142.65 W 5124.17 S 3214.86 W 5236.75 S 3284.85 W 5348.64 S 3354.64 W S4SS.GO S 3420.31W 5556.97 S 3487.29 W 5655.21S 3551.55 W S8S4.32 S 3679.90 W 5950.59 S 3750.96 W 6050.23 S 3819.21W 6146.75 S 3889.61W 6239.38 S 3954.85 W 6322.42 S 4019.60 W 6403.87 S 4080.19 W 6483.41S 4141.0S W 6566.64 S 4202.65 W 6650.54 S 4271.91W 6738.55 S 4341.56 W 6826.75 S 4410.97 W 6911.35 S 4481.36 W 6995.88 S 4549_04 W 7074.8G S 4614.06 W 7153.30 S 467G.72 W 7223.06 S 4741.24 W 7292.62 S 4802.57 W 7362.25 S 4859.29 W 7432.16 S 4912.42 W Y-PAD WELL N0.24 7-17-86 DATA INTERPOLATED FOR EVEN 1000 FEET OF MEASURED DEPTH NEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH RELATIVE COORDINATES FROM WELL-HEAD 6000 4427 4338 3038.00 S 1634.00 W ?000 5003 4914 3694.74 S 2121.75 W 8000 5569 5480 4329.63 S 2648.40 W 9000 6161 6072 4979.30 S 3122.89 W 10000 6778 6689 S64~.67 S 3543.50 W 11000 7425 7336 6269.48 S 3980.08 W 12000 8110 8021 6843.89 S ~427.08 W 13000 8820 8731 7384.62 S 4876.70 W 1000 998 909 36.13 S 15.39 2000 1948 1859 298.02 S 156.29 3000 2652 2563 913.10 S 483.38 4000 3252 3163 1627.30 S 843.69 5000 3822 3733 2353.94 S 1227.19 Markm· Zderlf:Iflcsf:torl I~ TVO DEPRT U KOP 5OO ~00 0 BJ iE ~/4~ HOLE TD t3i55 B.q3B B945 HORIZONTAL VIEW STANDARD ALASKA PRODUCTION COMPA Y-PAD WELL N0.24 CLOSURE: 8946 ft S 33.7 W DECLINATION: 3t.50 deg E SCALE: i inch = 1800 feet DRAWN: 7-~7-86 600 6OO i200 3000 3600 4ZOO 4BO0 5400 6000 6600 7~00 7BO0 6600 6000 5400 3000 ~400 1BO0 i~O0 ! / .. _ ...... ...... 600 0 600 9OO 27OO T 3600 V 4500 §400 6300 7200 BiO0 ~00 9900 tOBO0 ii700 t2600 -9. O0 1 i I ' I 5 .......... t~ , , 0 900 i~O0 4.~00 5400 [~epaptupe VERTICAL SECTION STANDARD ALASKA PRODUCTION COMPA Y-PAD NELL N0.24 SECTION AT S 34.37 N TVD SCALE: ! inch = 1800 feet DEP SCALE: ! inch = 1BO0 feet DRAWN : 7-t7-B6 IGu'ken Identlftcatton NO TVD DEPRT A) KOP ~0 500 0 8) i2 t/4" HOLE TD i3i55 B938 B945 tk300 7200 BiO0 9000 99~0 TSLEEO Teleco Oilfield S 6116 Nielson Way Anchorage, AK 99502 (907) 562-2646 .~s of Alaska Inc. July 11, 1986 JOB # 510 TAK STANDARD ALASKA PRODUCTION CO. WELL: Y-24 PRUDHOE BAY AUD #2 Please find attached a copy of the computer calculated MWD directional surveys for the above mentioned well. We at Teleco appreciate this opportunity to provide,service to Standard Alaska Production Company. Teleco is committed to providing the highest quality of service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Pat Havard Field Service Supervisor PH/el Enclosures A ,~1_~11'1' COMPANY Date 7/10/86 TELECO OILFIELD SERVICES JOB #510 SURVEY CALCULATIONS Page Company: Well: Location: Rig: STANDARD ALASKA PRODUCTION Y-24 PRUDHOE BAY AUD # 2 ~ELECO Job # 510 TAK ~rid Correction: Magnetic Declination: ~otal Correction: Proposed Direction: 0.00 degrees 31.50 degrees 31.50 degrees 214.36 degrees S 34 22 W RADIUS OF CURVATURE CALCULATION MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' TIE IN TO VERTICAL 500.00 0.0 203.4 S 23 24 W 500.00 0.00 0.00N 0.00E 0.00 N 90.000E 0.000 TELECO SURVEYS 1354.00 15.5 208.0 S 28 00 W 1344.06 111.16 101.90S 47.91W 112.60 S 25.182W 2.124 1550.00 18.1 206.9 S 26 54 W 1531.68 167.39 152.17S 74.02W 169.22 S 25.941W 1.336 1638.00 16.7 213.6 S 33 36 W 1615.65 193.62 174.88S 87.27W 195.45 S 26.521W 2.775 1173.00 11.7 205.5 S 25 30 W 1168.16 68.98 63.90S 28.76W 70.08 S 24.231W 1.664 812.00 5.7 203.4 S 23 24 W 811.48 15.22 14.22S 6.17W 15.50 S 23.458W 1.827 TELECO Job # 510 TAK 7/10/86 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 1827.00 23.2 208.0 S 28 00 W 1793.21 257.93 230.22S 120.26W 259.74 S 27.581W 3.581 2016.00 30.1 208.0 S 28 00 W 1962.03 342.13 305.01S 160.07W 344.46 S 27.691W 3.651 2206.00 36.4 210.1 S 30 06 W 2120.84 445.80 396.03S 210.63W 448.56 S 28.006W 3.370 2394.00 42.4 207.3 S 27 18 W 2266.05 564.48 500.64S 267.90W 567.81 S 28.152W 3.328 . . 2583.00 48.6 207.6 S 27 36 W 2398.46 698.25 620.21S 330.01W 702.55 S 28.018W 3.282 2701.00 52.7 209.0 S 29 00 W 2473.26 788.96 700.53S 373.26W 793.77 S 28.050W 3.594 2959.00 53.6 206.2 S 26 12 W 2627.99 993.96 883.47S 468.90W 1000.20 S 27.957W 0.936 3197.00 52.7 206.9 S 26 54 W 2770.72 1182.64 1053.84S 554.03W 1190.60 S 27.732W 0.445 3576.00 52.5 206.9 S 26 54 W 3000.92 1481.19 1322.28S 690.38W 1491.66 S 27.570W 0.054 3934.00 54.4 206.6 S 26 36 W 3214.11 1766.24 1579.08S 819.82W 1779.21 S 27.437W 0.535 4239.00 56.3 206.2 S 26 12 W 3387.51 2014.72 1803.81S 931.38W 2030.08 S 27.309W 0.632 4616.00 55.5 208.0 S 28 00 W 3598.87 2324.38 2081.70S 1073.58W 2342.24 S 27.281W 0.449 4906.00 53.9 210.4 S 30 24 W 3766.45 2560.08 2288.28S 1189.04W 2578.77 S 27.457W 0.872 5291.00 53.9 209.7 S 29 42 W 3993.29 2870.27 2557.55S 1344.81W 2889.56 S 27.736W 0.147 5582.00 51.4 212.6 S 32 36 W 4169.82 3101.20 2755.48S 1464.45W 3120.47 S 27.989W 1.169 6041.~00 52.8 216.1 S 36 06 W 4451.77 3463.32 3054.45S 1668.78W 3480.59 S 28.650W 0.674 6335.00 54.6 215.7 S 35 42 W 4625.81 3700.17 3246.38S 1807.71W 3715.76 S 29.111W 0.622 TELECO Job # 510 TAK 7/10/86 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** SINGLE SHOT SURVEYS 6652.00 55.5 215.5 S 35 30 W 4807.41 3959.94 3457.65S 1958.96W 3974.02 S 29.534W 0.289 7005.00 56.0 217.5 S 37 30 W 4807.41 3959.94 3457.65S 1958.96W 3974.02 S 29.534W 0.289 7290.00 56.0 218.0 S 38 00 W 5165.45 4487.36 3879.01S 2277.17W 4498.02 S 30.415W 0.146 TELECO MWD SURVEYS 7642.00 55.5 220.3 S 40 18 W 5165.45 4487.36 3879.01S 7932.00 54.7 219.6 S 39 36 W 5529.48 5013.99 4286.95S 2277.17W 4498.02 2613.57W 5020.83 S 30. 415W 0. 146 S 31.369W ~0.340 10006.00 49.3 213.3 S 33 18 W 6781.02 6664.52 5648.08S 3547.16W 6669.57 S 32.130W 0.355 10479.00 50.5 214.7 S 34 42 W 7085.68 7026.31 5948.02S 3749.48W 7031.18 S 32.226W 0.340 10762.~00 50.2 215.7 S 35 42 W 7266.26 7244.17 6126.06S 3875.08W 7248.79 S 32.316W 0.292 10985.00 46.9 216.8 S 36 48 W 7413.86 7411.20 6260.84S 3973.90W 7415.52 S 32.404W 1.525 9816.00 49.9 212.9 S 32 54 W 6657.88 6519.87 5526.87S 3468.15W 6524.90 S 32.109W 0.993 9533.00 52.6 211.9 S 31 54 W 6480.76 6299.31 5340.54S 3349.90W 6304.22 S 32.098W 0.221 9155.00 53.4 212.2 S 32 12 W 6253.27 5997.69 5084.68S 3189.71W 6002.35 S 32.101W 0.071 8682.00 53.5 212.6 S 32 36 W 5971.59 5617.95 4763.87S 2986.11W 5622.39 S 32.081W 1.326 8385.00 53.5 217.5 S 37 30 W 5794.93 5379.29 4568.48S 2849.05W 5384.06 S 31.949W 1.696 8216.00 54.0 221.0 S 41 00 W 5695.00 5243.52 4462.95S 2762.83W 5248.92 S 31.760W 0.470 TELECO Job # 510 TAK 7/10/86 Page 4 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' **************************************************************************************************** 11329.00 44.0 217.1 S 37 06 W 7655.16 7656.08 6456.73S 4121.25W 7659.91 S 32.550W 0. 845 11612.00 48.3 218.5 S 38 30 W 7851.17 7859.75 6617.95S 4246.31W 7863.10 S 32.686W 1.561 11986.00 48.3 218.9 S 38 54 W 8099.96 8138.20 6835.88S 4420.91W 8140.87 S 32.892W 0.080 12270.00 46.6 219.2 S 39 12 W 8292.01 8346.70 6998.35S 4552.71W 8348.90 S 33.046W 0.604 12554.00 43.9 220.6 S 40 36 W 8491.93 8547.43 7153.07S 4682.07W 8549.16 S 33.207W 1.013 12740.00 13093.00 43.3 221.3 S 41 18 W 40.3 226.3 S 46 18 W 8674.85 7249.94S 4766.13W 8676.27 S 33.321W 8906.85 7419.69S 4928.92W 8907.64 S 33.596W 8626.62 0.414 8889.75 1.270 -_ TELECO 0 i 1 ~ i ~ 1 d S~rv i VERTICAL PROJECTION m- o_ .J 2000 4000 6000 8000 10000 2000 14000 16000 18000 0 2000 4000 6000 8000 10000 12000 I ~. 5i Jo · o o1~ G ,. N......... . Si'Ar IDNRD AL.A~ ~K~ P~',O[)U~ ;T~ICN = . .. ~ J[ 8~~ $10 ~ '~ce ~s.~ o~ '- 1 irlcl~ = 2~101) ~t --. ~ , . .... J ~,I~ ' 48.3 _ I .... , , . ._ , -.~ .... ~ -. ,_ .... = . ~ ., , , . _ ; , _ , ~ ....... ~ ~ ,. ~ , . ~ ~ ...~ . . , .J _ ,. - ..~ . VERTICAL SECTION (~t) TELECO 0 i 1 f i ~ 1 d S~rv i PLAN VIEW 9600 8000 6400 4800 3200 ! 600 0 WEST (Ft) 1600 3200 48OO 6401~ V 0 8000 9600 1 1200 12800 Standard Alaska Production Compan, 900 Eos. I Benson Bou J P.O Box 196612 Anchoroge. AlosLo 99.519-6612 (907) S64-51 I INDEXED DALLAS ARCO CHEVRON EXXON TO: TEXACO MARATHON MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES REFERENCE: STANDARD ALASKA PRODUCTION Date: 07/28/86 T#: 77219 SAPC OPEN HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: DAL/UNIT/STATE: Y-24 DIL/SFL 07/12/86 #1 13118-13540 Sch 5" & 2" Y-24 BHCS 07/12/86 #1 13118-13506 Sch 5" & 2" Y-24 LDT/EPT-poro 07/12/86 #] 13118-13516 Sch 5" & 2" Y-24 LDT/EPT-raw 07/12/86 #1 13118-13516 Sch 5" & 2" Y-24 EPT 07/12/86 #1 13118-13492 Sch 5" & 2" STATE ONLY' DIRECTIONAL SURVEYS Hagnetic Single ;hot Directional vey Dar Gyroscopic Di Teleco MWD 86 Nece I red Job# ' Job#: 510 TAK .ctoria Aldridge I,R2-i INFORMATION CONTROL Wel I Records LR2-1 Slondard AIo sl~o Produ¢l~on Compor 900 Eos~ Benson BouL Jrd P.O ~ 196612 Anchoroge. Alosko 99519 6612 1907} 564 5 I 1 I ARCO EXXON STANDARD /\1 A.~KA Date: 07/28/86 PHILLIPS ~. 77221 STATE OF AK .PDBY Systems (Transmittal Only) GEOSCIENCES (Transmittal Only) SAPC }~GNETIC LIS TAPES & LISTINGS ?ne following materia/ is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: ~ * Y-24 OH LIS Magnetic tape 07/12/86 ¥/1 Sch#71588 Tape Pos. #04164 * E~XON' An Asterisk (*) next to a listing - have received the Tape(s) and List~g(s service companv~ P] ea.~e.~conJT~iorn~hiI~. R~eiv :'.., i-% ;U!l J, '-'U~ , ve means yot~ V from the rt.:;pectJve Victoria Aldridge LR2-1 Wel 1 Recorc].'~ Standard Alaska - Production Comp~ 900 East Benson B,. lard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ~/,~,' ALASKA PRODUCTIO June 25, 1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Mr. C. V. Chatterton [dell Y-24 (13-4-10-13) PBU Gentlemen' Enclosed in triplicate is Form 10-403, Application For Sundry Approvals, for the above-named well. This gives notice of intention for proposed work on [del 1 Y-24. [de request that the setting depth for surface casing be changed from 2700' TVD as approved on the Permit to Drill to 2547' TVD. Cement volumes have been adjusted accordingly. Review of this change indicates that it meets PBU field rules as outlined in Conservation Order #145 and provides adequate well control capability. Base of permafrost is 2047' TVD on Y-24. RSA/MA~/pm/O799D Enclosure cc: T. O. Stagg, MB12-1 T. N. Tyler, MB9-2 Drilling [dell File #17 [dell Records, LR2-1 Yours very truly, R. S. Allan Division Drilling Engineer A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA AL~-,,.,KA OIL AND GAS CONSERVATION CO,,,MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend E] Operation Shutdown [] Re-enter suspended well [] Alter casing XI Time extension ~ Change approved program ~ Plugging [] Stimulate [] Pull tubing ~ Amend order ~ Perforate C Other 2. Name of Operator 5. Datum elevation(DF or KB) Standard Alaska Production Co. 87' BKB feet 3. Address 6. Unit or Property name P.O. Box 196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 1349' SNL, 5197' WEL, Sec. At top of productive interval 3500' SNL, 5000' WEL, Sec. At effective depth 34, TllN, R13E, UM 4, T10N, R13E, UM Attotaldepth 3659' SNL, 5109' WEL, Sec. 4, T10N, R13E, UM 7. Well number Y-24 (13-4-10-13) 8. Permit number 86-113 9. APl number 50-- 029-21608 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Structural Conductor Surface 2547' Intermediate Production Liner Perforation depth: measured Size 68# L-80 true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Cemented Measured depth True Vertical depth 4110cu. ft. 2958' 2547' 12.Attachments Description summary of proposal [] Detailed operations program © BOP sketch 13. Estimated date for commencing operation 6/26/86 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed [~. ~---~, ~ Title Division Drilling Engineer Date 6/25/86 Commission Use Only Conditions of approval Notify commission so representative may witness I Ap ,~. Plug integrity' [] BOP Test [] Location clearanceI proval No. Approved by Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Standard Alaska Produ¢lion Compa r, 900 [osl Benson Bo ,d PO Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5 I I I INDEXED DALLAS ARCO CHEVRON EXXON TO: -TEXACO MARATHON MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES REFERENCE: ST/~NDARD ALASKA PRODUC 1' ION Date: 07/21/86 T~: 77196 SAPc OPEN HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by slgnlng a copy of thls letter and returning It to this offlce: DAL./UNIT/STATE: Y-24 TELECO MWD Gamma 06/24-07/08/86 8546-8947 Y-24 TELECO ~D Gamma 06/24-07/08/86 12630-13150 STATE ONLY: ~ ' /] DIRECTIONAL SURVEYS Magnetic Sing2~hot Di~ct~ona~/Survey D_~4~: JobJ/: Gyroscopic ~re~e~ . /~ Da? ~ .Job//: Received ~]~~, 4,~~~/--~toria Aldridge LR2_I A v~~r~J ~ Co,,~l>r,,,~ ' June 10, 1986 Mr. R. S. Allan Division Drilling Engineer Standard Alaska Production Company P.O. Box 196612 Anchorage, Alaska 99519-661°~ Telecopy: (907) 276-7542 Re .- P~adhoe Bay Unit Y- 24 Standard Alaska Production Company Permit No. 86-113 Sur. Loc. 1349'SNL, 5197'~L, Sec.34, TllN, RI3E, Btmho!e Loc. 3659'Sh~J, 5109'WEL, Sec. 4, T]0N, R13E, UM. Dear Mr. Allan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to co~mlencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~.~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve ~r~/~ tru%~u~r_~s, C. V. Cha--L~f::er.~on' Chai ~--waan of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~ISSION dtf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA ,_.- AND GAS CONSERVATION CO,~MISSION PERMIT TO DRILL 2O AAC 25.005 / la. Type of work Drill ~ Redrill E~'lb. Type of well. Exploratory ~ Stratigraphic Test ~J Development Oil×~ Re-Entry F~ Deepen~1 Service ~ Developement Gas [] Single Zone [~ Multiple Zone !~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company 87' TVD BKB feet Prudhoe Bay Field Prudhoe Bay Oil Pool 3. Address P.O. BOX 196612 Anchorage, AK 99519-6612 6'ADLP47~7]fsignati°n Pro ertv De 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 1349' SNL, 5197' WEL, SEC.34, TllN, R13E UM Prudhoe Bay Unit At top of productive interval 8. Well nu ,mber Number 3500 SNL, 5000' WEL, SEC.4, T10N, R13E UM Y-24 (13-4-10-13) K000683449-G-14 At total depth 9. Approximate spud date Amount 3659' SNL, 5109' WEL, SEC.4, T10N, R13E UM June 23, 1986 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in pro-perty 15. Proposed depth (MD and TVD) property line ADL 28289 280 feet Y'-7 35 feet 2560 13368' MD'9179' ~eVePt 16. To be completed for deviated wells 50° 25' 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle 0 Max~rnum surface 3330 ! psig At total depth (TVD) 8800' 4390psi9 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" ccnducto' 80' Surf~a(e 110' 110' 8 cu. yds. concrete 17 ~" 13 3/8'~ 72# L-80 Butt 3137' Surfa(e 3167' 2680' 4400 cu.ft, permafros 12 ¼" 9 5/8'~ 47# L-80 NSCC 6130 Surfa(e 6160' 4587' 575 cu. ft. class G 12 ¼" 9 5/8'~ 47# L-80 Butt 6679' 6160' 4587 12839 8839 8 ½" 7" 29# L-80 Butt 779 12589 8683 13368 9179' 251 cu. ft. class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface RECEIVED Intermediate ProductionJ U N 0 4 1986 Liner Perforation depth: measured Alaska 0il & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee ~× Property plat ~× BOP Sketch:~: Diverter Sketch ~ Drilling program ×_x Drilling fluid program ~x Time vs depth plot [] Refraction analysis f~ Seabed report ~ 20 AAC 25.050 requirements ~ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~~~~ ~ ~/~ Title Division Drilling Engineer Date~//~// Commission Use Only I API number I Appr~)voc~,?Ce/ I See cover letter Permit Number j2~,--/)~ 50-- c ].-~'~' -?-/ O~ 86 for other requirements Conditions of approval Samples required ,,-1 Yes ~No Mud Icg required L-; Yes 51 No Hydrogen sulfide measures ~ Yes L~ NO Directional.survey required ~A, Yes ~ No Required workin~.4~c~~~ 5M; ~ 10M; ~ 15M Other: ' by order of ~~:2'~ Approved byL ~ ¢~~ ~/~~~ Commissioner the commission Date /! Form 10-401 Rev.'~.-'f'J~-1-85 ~ Submi triplicate PROPOSED DRILLING AND COMPLETION PROGRAM WELL Y-24 [ 13- 4-10-13] PBU Install and cement 80' of 20" conductor to surface. The drilling fluid program will consist of an 8.5-9.5 ppg spud mud in the 17-1/2" hole, a 9.0-9.7 ppg water base mud in the 12-1/4" hole and a 8.8 ppg water base mud in the 8-1/2" hole. Drill 17 1/2" hole to 3187' and cement 13 3/8" L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original resevoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12 1/4" hole to the 9-5/8" casing point above the Sadlerochit Sandstone. Run 9 5/8" 479 L-80 mixed string of Buttress and NSCC to within 5' of 12 1/4" TD and cement in two stages: First stage using Class G cement around the 9 5/8" shoe. The second stage to be downsqueezed in the 13 3/8" x 9 5/8" annulus followed bynonfreezing fluid. Directionally drill 8 1/2" hole to TD. Run 7" liner from TD to 250' inside 9 5/8" casing shoe and cement using Class G cement. Clean out to 7" float equipment. Change over to 9.6 ppg. NaC1 completion fluid. Test casing and lap to 3000 psi. Run 9 5/8" production packer on internal plastic coated tubing with gas lift mandrels and a sliding sleeve. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 50' belowbase of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. Suspend well for perforating subsequent to rig release. Tubing Size: 3 1/2 , 9.39, L-80 EUE 8rd MOD IPC W/7 GLMS Tailpipe Size: 2 7/8", 6.59, L-80 EUE 8rd MOD IPC Note: Optional drillpipe conveyed logs in 8 1/2" hole in the event conventional logging is unsuccessful. JWB: 27-MAY-86 RECEIVED Alaska Oil & Gas Cons, commi'3si~'m PROPOSED DOWNHOLE DIAGRAM WELL Y-24 [ 13- 4-10-13 ] PROPOSED DEPTH BKB 20" Conductor 110 Ball Valve 2249 13 3/8" Casing Shoe 17 1/2" Open Hole 3167 3187 PBU 3 1/2 , 9.3#, L-80 EUE 8rd MOD IPC W/7 GLMS 9 5/8" Packer 7" Tieback Assembly 12539 12589 9 5/8" Casing Shoe 12 1/4" Hole 7" PBTD · 7" Liner Shoe 8 1/2" Open Hole JWB: 27-MAY-86 12839 12844 13328 13368 13368 A~s~ O~l & Gas Cons. Ar, choUg~ B.r'-- P. 13 STACK CONFI¢ IRATION 5/8" TRIPLE RAM STACK 5000 PSI WP ¢,- DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS uO~fll ....... h, , CHECK KILL UNE HAND GATE GATE DRILLING SPOOL 4" CHOKE LINE HAND GATE HYDR. ASST. GATE PIPE RAMS I I 04 40 I I0 20 50 40 I' !0 2D 22 32 I · 29~ ' 28 'Y"-4'ual' ' t'~;' ' IO?l'' .27 0 ~ ~Y-I Y-7 (Actual) O~ Y-19 LA~: 70°16'~05.61'' (Proposed) , LONG.:I4~49 ~1 .~6" Y- II Re4rill (Actual) O~ (Actual) 2492' 04 ~ ~(Actual) ~ , ~ 2780' ~ (Actual) ~ Y-21 (Proposed) Y-8 PORTION OF ~=,~,~ TIIN, RI~E, UM SCALE I'=i/2 MILE CERTIFICATE OF SURVEYOR -~I°~ *~ Y-20 (Proffered) 280'-~ Y-24 { Propo~d) 30 · 40 (Actual) T. I0 N. 2226' I hereby certify that lam properly registered to practice land surveying in the State of Alaska and that this plat represents a location survey of the wellpad shown and the wells thereon. This survey was made by me or under my supervision.. and all dimensions and other details are correct. Bottom hole NOTE: All bottom, holes are 8800' sub sea. I locations are furnished by others. Date Surveyor ~ ~... . ....~¢~ .X, ..... . .... ,o _// I PAD DETAIL- II (,E$-27o11-13) · Y-~ jj U I1 II 02 f ~ ~1- ~1 - I Add Proposed 8HL Y-ZZ ~d Praised BHL Y-ID He~i~ BHL Y-7,8,9,10~12,~ Add Proposed BHL Y-I3 ~l~j Add Prepared BHL Y- I0 Rev;se BHLY- 5,4,~ II from Proposed to Actual 4/ 3 /8l PJR Add Proposed BHL Y - 9 5 / ~/81 D~ Add Proposed BHL Y-8 5/2/81 PJR Revised Proposed BHL Y-7 2/2 /81 PJR Add Praised BHLY-7 1/28/81 PJR A~ Pro,Md BHL Y-12 10/9/80 PJR Add Proposed BHL Y- II 9/2~ PJR All Boffom Holes are 8800' sub sea. Revi~ed BHL Y- 1,2,5 ~6 from Pro,ted toActual. 6/2~80LAB NOTE~ Plat dated Aug. 50, 1979 changed to Oct. 2,1979. BHL 1~5 ~ 6 changed. C.J.R. AS - STAKED Loco*od NE I/4 ~ NW I/4 PROTRACTED SEC. 33 ~ ~,T. IIN. RI3E.,U.M.,A~ Surveyed for SOHIO PETROLEUM CO. Surveyed by F.M. LINDSEY 8~ ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-081 Anchorage Alaska i' : ,, ,, ,. ,,, , :. .... ,. ...... SUF~FA3E "l Tlllq R1BE SEC 34, S',,IL=1349' klE!_=S13?· 1 300 8 30 6 30 4 DO 2 30 ] , ": .~j ~ ~,, '70 LE~ ~" ........... ./5/ ~' .... : ~, .-.~ '~'~'~;~ Y-9 LEI: ID · -:... . I~ :~ $25DUA88:[DRAN017]Y24 CLOSAP SHORT.LIS;6 Search Radius= 4801 COURSE LINE For proposed well: ¥-24 [13- 4-10-13] Location = W-E S-N TVD(SBS) Top 644898.00 5948908.00 -87.00 Bottom 639581.11 5940815.42 9494.96 Note: Ail depths in feet Below Kelly Bushing (BKB) 28-MAY-1986 07:28 --- Closest Approach Analysis Date: 28-MAY-86 Time: 07:27:09 Page 1 Closest Approach WELL IDENT /PROPOSED~ /NEARBY~ TVD DEPART TVD DEPART k029-2001000 331113 A029-2002700 HURL 1 A029-2002701 HURL 1 A029-2006700 STATE1 A029-2011300 A-3 A029-2011600 A-5 A029-2039400 Y-1 A029-2039500 Y-2 A029-2041100 Y-3 A029-2042300 Y-4 A029-2043100 Y-6 A029-2043600 Y--5 A029-2051300 Y-11 A029-2051301 Y-11RD A029-2051700 Y--12 A029-2053600 MPTR43 A029-2056000 Y--7 A029-2057200 Y--8 A029-2057900 Y--9 A029-2058700 Y-10 A029-2063400 2979 1 8817 5 8498 9 5572 2 3466 1 4294 3 56 56 5O0 0 61 57 500 0 1626 4 1633 2 1772 7 7218 9 500 0 996 6 1294 4 1469 2 1693 .9 8758.0 8372.6 4831 4 2283 2 3285 2 0 0 0 0 0 0 0 0 0.0 0 0 296 3 300 1 386 5 6823 8 0 0 54 5 142 3 215 0 2937 5 8808 7 8490 2 5557 2 6630 1 7473 9 O0 00 494 0 00 00 494 6 1627 5 1632 3 1771 0 4140 1 499.9 996.8 1294.8 1468.9 7.3 0 0 0 0 0 0 4262 4 4194 3 0 0 0 0 4 4 0 0 0 0 4 5 7 1 11 3 15.8 563.4 7.0 1.1 9.5 7.1 CLOSEST DISTANCE 2356 9 3873 4 3960 5 4719 2 7879 4 8119 4 695 0 585 3 476 4 365 5 145.0 254.0 272.0 286.4 358.4 5866.1 33.9 51.6 122.6 196.4 Vertical Intersection /PROPOSED~ /NEARBY~ TVD DEPART TVD DEPART 7150.3 507.1 VERTICAL DISTANCE 4969.5 1056.0 69.0 2084.5 54.3 1028.3 1568.7 264.7 3638.1 183.1 2069.5 Y-13 1851.5 441.6 1848.2 A029-2091600 Y-18 0.4 0.0 0.0 A029-2092000 Y-17 500.0 0.0 500.1 $25DUA88:[DRAN017]Y24 CLOSAP SHORT.LIS;6 8.9 0.0 3.0 435.2 789 .9 842.9 A029-2093200 ¥-16 500.0 0.0 508.3 2.4 906.1 A029-2094000 Y-15 500.0 0.0 501.9 6.1 980.9 A029-2141000 A-33 3529.8 2360.2 6692.7 4307.9 7619.5 28-MAY-1986 07:28 Page 2 SUMMARY The well which comes closest to the proposed well is: A029-2056000 Y-7 Closest approach distance = KICK OFF for 'this run = 33.9 feet 500.0 feet $25DUA88:[DRAN017]Y24 CLOSAP SHORT7.LIS;6 Search Radius= 4801 7 DEGREE LEAD LINE For proposed well: Y-24 [13- 4-10-13] Location = W-E S-N TVD(SBS) Top 644898.00 5948908.00 -87.00 Bottom 640608.14 5940227.20 9494.96 Note: Ail depths in feet Below Kelly Bushing (BKB) 28-MAY-1986 07:30 Closest Approach Analysis Date: 28-MAY-86 Time: 07:29:14 Page 1 Closest Approach WELL IDENT /PROPOSED% /NEARBY% TVD DEPART TVD DEPART A029-2001000 331113 A029-2002700 HURL 1 A029-2002701 HURL 1 A029-2006700 STATE1 /%029-2011300 A-3 A029-2011600 A-5 A029-2039400 Y-1 A029-2039500 Y-2 A029-2041100 Y-3 A029-2042300 Y-4 A029-2043100 Y-6 A029-2043600 Y-5 /%029-2051300 Y-11 2%029-2051301 Y-11RD /%029-2051700 Y-12 A029-2053600 MPTR43 A029-2056000 ¥-7 A029--2057200 Y-8 A029-2057900 Y-9 A029-2058700 Y-10 A029-2063400 2741 6 8307 8 7989 3 6018 1 3466 1 4612 8 56 56 500 0 61 57 500 0 1562 2 1563 9 1701 1 5759 6 500 0 963 4 1248 2 1409 7 1406.6 8141.3 7755 9 5370 9 2283 2 3670 6 0 0 0 0 0 0 0.0 0.0 0.0 261.1 262.0 340 5 5058 1 0 0 47 8 126 1 188 8 2715.9 8299.1 7980.6 6003 1 6630 1 7788 4 00 00 494 0 00 00 494.6 1563 4 1562 7 1699 9 2680 0 499 9 963 5 1248 4 1409 3 6 9 0 0 0 0 0 0 4262 4 4438 8 0 0 0 0 4 4 0 0 0 0 4 5 6 8 10 9 15 4 0 0 7 0 1 1 9 2 6 8 CLOSEST DISTANCE 2547 2 4995 8 5069 8 4094 9 7721 1 7822 5 695 0 585 3 476 4 365 5 145 0 254 0 306 1 320 8 402 8 6874.5 33.9 57.9 139.0 221.1 Vertical Intersection /PROPOSED~ /NEARBY~ TVD DEPART TVD DEPART VERTICAL DISTANCE 1072.3 73.0 2130.3 63.8 1057.8 1647.6 308.1 3783.7 238.7 2136.1 2265.7 830.7 7559.0 642.0 5294.0 Y-13 1774.2 387.5 1772.2 A029-2091600 ~-18 0.4 0.0 0.0 A029-2092000 Y-17 500.0 0.0 500.1 $25DUA88:[DRAN017]Y24 CLOSAP SHORT7.LIS;6 8.2 0.0 3.0 485.9 789.9 842.9 A029-2093200 Y-16 500.0 0.0 508.3 2.4 906.1 A029-2094000 Y-15 500.0 0.0 501.9 6.1 980.9 A029-2141000 A-33 3593.5 2437.3 6764.4 4377.5 7449.5 28-MAY-1986 07:30 Page 2 SUMMARY The well which comes closest to the proposed well is: A029-2056000 Y-7 Closest approach distance = KICK OFF for this run = 33.9 feet 500.0 feet SUC?~ON 4,1 I,~I D, PLJmP 5 ro ~LJ D 1 - Brandt Dual Tandem Shale Shaker 1 - Demoo 6-12" Cone Shale Desander 1- Demco 416H w/16 cones & (1) Demco 48H w/16 oones (Desilter) 1 - Drilco Atmospheric Mud Degasser 50 1- 200 gpm Operating Capacity. Centrifuge 15 - Brandt MA5 Mud Mix Agitators 1 ' 150 bbl. Trip Tank 1 - Recording drilling fluid pit level indicator with both visual and audio warning devices at driller' s console ~0 DESA,N O~ R T~.M ~ E M S~A~ 70 1 - Dr~'lling fluid flow sensor with readout at console I.HELK L£bl ~UK N~W WkLL FERMITS ITEM DATE (1) Fe__~e & f".)': APPROVE '" ('2~thru 8) (3) Admin~ cn 13) (10 and 1~) (4) Casg ~.~.~, g-A-~g (14 thru 22) (5) BOPE (23 thru 28) OTHER (29 thru 31) rev: 04/03/86 6.011 '~.r~.~. C~%;:-7 '2 ? :2 ' ', ? "' . -: ·-'--~. . ....... , .... . ' .... Company ~¢.~/ c.. Lease & Well No. . v YES NO Is the permit fee attached .................. i............ ~ , Is well to be located in a d~n~ ~'..i ..... Is well located proper distance from property'line [ ..... Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ............. Is operator the only affected party ................................ Can permit be approved before ten-day wait .......................... e 3. 4. 5. 6 7 8. e 10', 11. 12. 13. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string prov{ded ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment, procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate_~ Are necessary diagrams and descriptions of ~ --~ --' BOPE attached ~ Does BOPE have sufficient pressure rating - Test to ,~O~ psig ..' z~ Does the choke manifold comply w/AP1RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. .,, For 29. 30. 31. exploratory and Stratigraphic wells: Are'data'presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas' zones ............ If an offshore loc., are survey results of seabed conditions presented. 32. Additional requirements ............................................. ........ INITIAL GEO. UNIT ' ON/OFF POOL CLASS STATUS AREA NO. SHORE , REMARKS Well Histo.ry 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 APPENDIXi No special'effort has been made to chronologically organize this category of information. LVP OIO.HOZ VERIFICATION LISTING P~GE · ~ REEL HEADER *~ SERVICE NAME ,:EDIT DATE :86/07/18 ORIGIN : REEL NAME : CONTINUATIO'N'~ :01 PREVIOUS REEL : COMMENTS :SCHLUMBERGER WELL SERVICES PROPRIETARY FIELD TAPE ~* 'TAPE HEADER ~ SERVICE NAME :EDIT DATE :86107118 ORIGIN :0000 'TAPE NAME :1588 CONTINUATION ~ :01 PREVIOUS TAPE : COMMENTS :SCH:LUMSERGER WELL SERVICES PROPRIETARY FIELD TAPE ~: FILE HEADER ** 'FILE NAME :EDIT .001 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : INFORMATION RECORDS MNEM CONTENTS CN : WN : =N : RANG: TOWN: SECT: COUN: STAT: CTRY: MNEM STANDARD ALASKA PRODUCTION CO. Y-24 PRUDHOE BAY 13E 11N N. SLOPE ~LASKA US~ CONTENTS PRES: E .,..,. COMMENTS U'NIT TYPE CATE SIZE CODE 000 000 030 065 000 000 004 065 000 000 012 065 000 000 004 065 000 000 003 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 003 065 UNIT TYPE CaTE SIZE CODE 000 000 001 055 LVP OiO.H02 VERIFICATION LISTING PAGE 2 SCHLUMBERGER ALASKA COMPUTING CENTER COMPANY : STANDARD ALASKA PRODUCTION CO WELL : Y-24 FIELD = PRUDHOE BAY COUNTY = NORTH SLOPE BOROUGH STATE = ALASKA JOB NUMBER AT ACC: 71588 RUN ~,1~ DATE LOGGED: 12-JUL-S6 LOP: R. SINES CASING TYPE FLUID DENSITY VISCOSITY PH FLUID LOSS 9.625" @ 13138.0' - BIT SIZE = 8.5" DISPERSED 8.8 LB/G RM = 4.74 @ 68 DF 39 S RMF = 5.0T @ 68 DF 12. RMC = 5.00 @ 68 DF 11.6 C3 RM AT BHT = 1.814@ 189 DF MATRIX SANDSTONE LVP OlOoH02 VERIFIC4TION LISTING PAGE .3 =:-' ::= .';~ ;',-' ~:~ THIS DATA HAS NOT BEEN DEPTH SHIFTED- OVERLAYS FIELD PRINTS -,-"'"'"-,--,-o,-'"-,- SP FROM MAIN PJI. SS USED.. WITH DATA FROM REPEAT LOG .(DIL/BHC) .,-"~"'"'"'"~-~..,-~.-,. ~?_~,'-_~;',~?. , , GR, I'LD, EDT FROM M~IN PASS SPLICED TO REPEAT AT. 1307Z'o SCHLUMBERGER LOGS INCLUDED WITH THIS M~GNETIC TAPE': , DtJ~L IND~'CTION SPHERICALLY FOCUSSED LOG (DIL) ~ REPEAT FILE USED AS MAIN PASS ~ DATA A'VAILABLE: 13568' TO 12683.5' ~ BOREHOLE ~COMPENSATED SONIC LOG (BHC) "~ REPE~T FILE USED ~S MAIN] PASS' "~ DATA AVAILABLE: 13568' TO 12683.5' ~ LITHO DENSITY COMPENSATED LOG ('LDT) X~ DATA ~VAILABLE: 13520' TO 13094' ~ ELECTROM:AGNETIC PROPAGATION TOOL (EPT) ~ DATA AVAILABLE: 13520' TO 13094' LVP OIO.HO2 VERIFICATID'N LISTING PAGE ,4 -q:=:'-' DATA FORMAT RECORO ~'~:~ ENTRY BLOCKS TYPE SI ZE 2 4 8 9 4 0 I DATUM MNEM SPECIFICATION BLOCKS SERVICE .SERVICE UNIT ID ORDER # DEPT FT SFLU OIL OHMM ILO OIL OHMM ILM OIL OHMM SP OIL MY GR OIL GADI OT BH.C 'US/F GR BHC GAPI GR LDT GAPI CALI LOT IN RHOB LOT G/C3 DRHO 'LOT G/C3 PEF LD'T EPHI LOT PU' DPHI LD.T PU LL LOT CPS LS LOT CPS LU LOT CPS SSI LOT CPS SS2 LOT CPS LITH LDT CPS TPL EPT NS/M EATT EPT DB/M CALI EPT IN GR EPT G~PI R E P R CDDE 66 66 ? 3 65 66 66 . . 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REEL TRAILER ""' SERVICE NAME :EDIT DATE :86/07118 ORIGIN : REEL NAME : CONTINUATION ~ :01 NEXT REEL NAME : tVP OlO,.H02 VERIFICATION LISTING P/~GE T COMMENTS :SCHLUMBERGER WELL SERVICES PROPRIETARY FIELD TA,PE *~*~****~ EOF
