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203-121
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I ii/>*s� THE STATE Alaska Oil and Gas � -�_ of ® Conservation Commission lsvrisKA .- - _ �� 333 West Seventh Avenue ii ._: GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 f.or Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Thompson Ali/ Interventions Engineer F a8 217, ` ' BP Exploration(Alaska), Inc. S P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-08C Permit to Drill Number: 203-121 Sundry Number: 316-589 Dear Mr. Thompson: 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, at647,9;-t-41., Cathy P. Foerster Chair DATED this a- day of November,2016. RBDMS 1AV NOV 2 8 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other New Tech:SPARC m ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 203-121 • Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development [JJ• 3. 6. API Number 50-029-21180-03-00 • 99519-6612 Stratigraphic 0 Service 0 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 15-08C • 9. Property Designation(Lease Number): 10. Field/Pools: N O V Ia� 2 016 ADL 0028306 • PRUDHOE BAY,PRUDHOE OIL . - f 11. PRESENT WELL CONDITION SUMMARY C Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MiD): 11552 • 8782 • 11506 8782 9880 Casing Length Size MD TVD Burst Collapse Structural Conductor 84 20"91.5#H-40 28-112 28-112 1490 470 Surface 2513 13-3/8"72#L-80 27-2539 27-2539 4930 2670 Intermediate 7422 9-5/8"47#L-80 25-7447 25-7189 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 4-1/2"12.6#13Cr80 13Cr80 23-8602 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic ® 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development ® Service 0 14.Estimated Date for Commencing Operations: 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 Thompson,Ryan be deviated from without prior written approval. Email RYAN.THOMPSON@bp.com Printed Name it Thompson,Ryan Title Interventions Engineer Signature '? - Phone +1 907 564 4535 Date It //o // i� COMMISSION USE ONLY 6 (, Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3tu? -6 r Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: t-.k . 1, 1-2,-LL Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No Subsequent Form Required: ,0— 404 a/7 APPROVED BYTHE Approved byCOMMISSIONER COMMISSION Date: /1-22•./4 ORIGINAL RBDMS NOV 2 6 2016 tutM. tt kl,b Submit Form and Attachments in Duplicate Form 10-403 Revised 11/2015 " Approved application is valid for 12 months from the date of approval. /� • • 11/16/16 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Ste. 100 Anchorage, AK 99501 To Whom It May Concern: Well 15-08 is a high GOR production well producing —50 MMSCF of gas per day. The purpose of this well intervention is to shoot 10' of perforations into the gas cap and straddle those perforations with ✓ the SPARC (downhole gas reinjection)tool. While on production the SPARC tool will separate the gas and liquids downhole, injecting a percentage of the gas into formation and producing the rest of the . gas and liquids to surface. Thank you, Ryan Thompson Intervention Engineer BPXA (1') 11 /I6/i • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: 15-08C Well Type: Natural Flow Producer API Number: 50-029-21180-03 Well Activity Conventional 4 Classification: Activity Description: SPARC Tool Cost Code/AFE: Z1-006MP-C:SPEND Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: NEW TECHNOLOGY PROJECT Other regulatory requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Yes Primary Required? Secondary Engineer: Paulina Meixueiro Contact numbers: (907) 564-5971 (907)306-6173 Well Intervention Engineer: Ryan Thompson Contact numbers: (907) 564-4535 (907)301-1240 Lead Engineer: Paulina Meixueiro Contact numbers: (907) 564-5971 (907)306-6173 Date Created: November 8, 2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Date Oil Rate lnj Rate Gas Injection GOR Choke Setting Gas Lift Rate Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) (psi) Cut(%) (Mscf/Day) 8/1/2016 624 2.4 bwpd, WC 51,310 82,288 89 0 1,079 0.38% Current Status: Operable Shut In Inclination>70°at Depth(ft) 9,461' MD Recent H2S (date, Maximum Deviation(Angle and ppm) 8/10/2015 20 ppm Depth) 94.3° 10,730' MD _ Datum depth,ft TVDss Dogleg Severity(Angle and Depth) 17° 9,366' MD Reservoir pressure(date, Minimum ID and Depth psig) 1" 10,051' MD Reservoir Temp,F Shut-in Wellhead Pressure 1,200 psi Known mech. integrity problems(specifics) Starting head leak fixed with welding job in 2015 Last downhole operation(date, 1/29/2015 Slickline gas lift job operation) Most recent TD tag (date,depth, toolstring OD) 7/20/2010 9,570' MD SL drift to deviation with 3.77"WRP drift Surface Kit Fit-for-Service? 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, This well is a high GOR well (-80,000)where we will install the SPARC downhole gas injection tool.This background information, program is to perforate in the Ivishak gas cap and straddle the perforations with the SPARC injection tool. etc: The SPARC injection tool is new technology which seperates the produced gas from the liquids downhole and reinjects the gas into new perforations in the gas cap. Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: HGOR Specific Intervention or Well Objectives: 1 Perforate in the Ivishak gas cap and straddle perforations with the SPARC down hole injection tool 2 3 Key risks,critical issues: Mitigation plan: 1 Rig up sufficient lubricator for long tool lengths 2 3 Summary Step# Service Line Activity 1 E Perforate per perforating form. 2 Operations Bring well online for-7 days to clean up perforations(Eline WSL please confirm this with DrillSite operator after perforating job). 3 E Set bottom packer with seal @ 8870' MD. SL Scheduler-Please utilize Halliburton unit for this job. SL WSL verify enough lubricator is rigged up. 4 S -Set upper SPARC straddle completion with upper pper packer seals at 8840'. -WSL discuss post job pop instructions below with DrillSite Operator. 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) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Pop well,attempt to keep WHP between 900 and 1000 psi if possible. 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 • • 4110 1REE= RAC GEN 3 NEW-EA°• RAC 1 5-0 8 C SAFETY NOTES: WELL MOLE>70'0 9482', • 7 CHROME UM 6 4-1/2"ORME T130" AGRA FOR, AXI-LSON CKB ELEV- 71Ll I 22 ' . HI!?WS X P1',ID-3 813' Liu Anake- ge 4 1065s20 0:3•43OCTOR,---: 111' — I Datum 14)- NA 91 S4 1-1-40. 2640. 1-19%/4-x r low II BACX,D-1 510'i Datum ND- 8800 SS 0-19 124* A 2647- 1-f9-5/6*ier iiiR 1 TP a NOR,137 6 700. ) 1 13-3/8'CSC.ii..t.-.o sic R-3,0 12 34r__{ 253, 112 GAS LIT MAN:IRIS .':I' 1.5) ':IV f)T IIV T tv li--VI-V TiiIiii1:161a DATE macs r MAR 04414 2040' 4!3291 3291 0 1016-2 MIK ' OK 16 131726115 7'SG RPI 1:4868, 6_1.10 1170111. i 7758' : 3 5890 5590 3 K8G.7 IXA4 EN 16 01/78/15 2 7800 7292 42 KBG.2 ()If BK 0 01f29111 , 1 8457 eon 21 KBG-2 OW BK 0 ovens ssfrxreocR TEPX reff.1111P -1 7266' I I-BC I-6K ID-6 " I :_ 8626 ] {4I12'I•ES X RP V=3 8131.1 {9.WV CSC475,t 80 PITC, ID--11681' -F74.46' ' ._ [- 86 i ir x 4 1,7IIK17”.*k Piot,Ii -;875;i Minimum ID=1.00"(§ 10061' WSRBB ANCHOR ASSY(06/24/09) ( 546670 -1-, 4-1/71-ES X NV 0=3 813' FTC,P0i'i 17V L74%11-1- 8800* 8 590' '-1_4-1/7 Hes XNI4PIAL LED TO 3 80-(02f24436) 1 I 4-1/7 TOG.1219,13CR-110 YAM ACI.% ri 8602' :0152 bpi U.3458' ' 8600' -1r x 5-3/4'SKR TIEBACK D=5.2V ] I.-- - LC vom.s rocx(xxocraxx)H._8777 USOZ -(4-1/71ALEG.ID=1 95ir7 _...r 11•41,284,13 CR _i -117/10 i Star I-Fr x 5-MR LIP w/MC HSR V.4 430' ---.....___._ .0363 bor.0-8278' ' $420;- 1-1 -uT X0.10-385r T HES USN, — 87111T \' _ 1.111 OUT WPDOW(16-118C)8777.87817 i FERFORTA TON SULAARY REF LEG ON xxocxrxx, , ???? FISH v.crowsuia ap.?x 1-irr x irr nom MIME AT TOP FEW 86*C 9960' 3 DOE WED CONE SMINGS(11/09112) sizE SW N:Xe,Rotor to Roluelon LI DB for Naforeal pee data ' m --I4- y ju_ ?_.•WFD Ef4PKR, 10503/019 I pi-ER/AOWSqz SHOT SOZ 18709O 1 IR LOUT WICOW(15-08CL11 10316•10027 2-7/8* 6 96E0 9660 0 0802/10 11 1 2-7/8' 6 971:0-9725 0 06/22/10 „_ 1004T,,H3-177 OFR OY StV 13-3 2-7/61' 6 9725-9750 0 06121110 2-fir b littU-9825 0 08118/10 —1 10061 I 11 177'X 2 lir X0,Ds 2 887j 2-7I8' 6 95-MO 0 09/17/10 1 2-1/7 4 9940-9980 0 2-1/7 4 10000-10050 0 06138103 1 -------------------- ---------------L5510. 2-11T 4 10070-10230 0 0603103 io % 27/8'Pat ont LED OR t lac -( 121917 ----- 2-1/7 4 102%•10400 0 08,08/03 L80 STL, 0058 W.13=2.3n• 2-1/7 4 10510-10570 0 OBIXV03 i,- i7,8 - 10061' 1 WS11313 ANCHOR 2-117 4 10723-10840 0 0808433 2-7/8' ASSY w/X0,D r,1.00' TBG xr/PAO 2-UT 4 10900-11430 0 01908/03 (05/23/09) REMO(ASSY (05/23/09),D=2 25' ' I 1 loosr EL.I-,voo'AS RE38 FCT POI. 111-99C L1 ‘ D-2067(01/25435) 2-7/8' - 10004.12156 Mt Oft 03/03/05 lik 1 4-Il?L1-4 12 68,1-80 ST-14 3152 W,93=3 asr 1-1 11661._ ----:--- --- --- DATE REV BY COMBOS 10/21IU 112E9 OISGINAL COMPLETION -11/01/93 ICES !SIDETRACK(15-0IA) 11122/97 NORCIC I CTD SIDETRACK(MOM) 08/11/03 SIDETRACK(15-010) 03113106 NORDIC I CTD ST(15-0$C-L1) 1 11/13/12 CACAO&1411 1ARRSET 1 EH(1 WW2) okiE FEV 13Y (X$$U4TS 3 PJC 'MIL NAIK CCM-L-110N 06(06(14 RCTLISID.PX RAE-&V 0/0(06/31/14) 09/09/14 .943 CCCIEINATES CORRECI1DN 01/26/15 DJS1 PJC PULL PX PLUG 1 GLV(20 02/18/15. RIC COMUCTOF7 LIC4CORFELIXVIS RILCHOE BAY MIT 'Ml I 15-09C/CI 1 FE304T Pb.2031210/2050050 API Pb 50-029-21180-03/60 SEC 72,111I4 fil4E,1645'R.&8 1379 WA. BP Exploration(4144ka) • • • I-ilk PENDING PERFORATING PROCEDURE ADW Well: 15-08C API S:50-029-21180-03 Date: .................................11/8/2016Prod Engr Paulina Meixueiro Office Ph: (907).584-5971 1125 Level: HomePh: ..................................................................... 20 ppm Cell/Pager: (907)308-8173 ............................................................................................ CC or AFE: Z1-006MP-C:SPEND ........................................ WBL Entries ........IOR.........._. Type...__.. Work Description............. ... I ,Sae Procedure I i E (. Well Obisafives and Perforating Notes: See Procedure. Attachment: Tie-in log with proposed perfs annotated Reference Log Tie in Log Add 0 feet ........._... Log: MWD Coil Flag/Jewelrylog to be on ...................... to the tie-in Date: 8/1/03-8/8/13 1/25/2005 depth with the reference log. Company: Sperry-Sun............. PDS ................................ Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone Ad/Rellperf 8,850'......... ..........._8,860'........... ..........._8,850'............. ......._8,860'....... ........._10..._. 6 Random 60° Requested Gun Size: 2 718" Charge: PJ 2906 HMX Is Drawdown Necessary/Desired/Unnecessary During Perforating no Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Last Drift: .9 570 K MD on 7/20/2010 Est Res.Pres.@ 'TVDss MD is 0 psi Perforation Summary Summary Dist Well: 15-08C Town: Date: API 8: 50-029-21180-03 Prod Engr: Anch Prod Engr P.D.Center . PBTD General Comments: .. ._._... .._..._ __ Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adpert/Reperf O/B/U O/B/U ............... .__........... _ 0/B/U .. .......... ........_... ......_.._..... ... O/B/U .. _._... _..... O/13/U .................... ............ .... 0/B/U ....._.. ._..___ .___. O/B/U ......_ ....,.... ..._............. ........ .... O/B/U .. ....._... 0/B/U .............. _.. ..._..... ..........,. ___. 0 • i i i of S 1 f i:in i ii f y fig il.1,?i C0149Wly 8P EXPL -•'DON ALASKA),INC 1 t48°Q z ar3 ,6TT Rmmil ,...,,F .11 as 15osc F14:14 PRUC.10E BAY county NORTH SLOPE ALAss.A. 1 1 ,...., 2. Iii 001710 F. 0 2: m 0 „, Z 1:3 o w 81 , 00 (f) 73 c- z E , . , P 6 7) C ..... m :::;' g :14 )t§SitizA2k sin at ox 6 l— a 0 2,21 1 0 CO „,,,,,, 4---.-4.---"--"-' -.±* il — M ...< 4Ik API L 0 0 Z L^^ C) rri rn aq CD 1 , — -11 0 5; * 0 - z - ;. a 1- 21,50T -212 2 -2 9 0 * 0 2 co p ta V -cm ,4 111 s—Fad Here TT, AA inferpretabons are dolmans bawl on nterences from dectncal or Mee meassements we we cannot and do not guarantee re acatacy or nor-a es of any - .refabom and we Wail not et in he case Ot gross or wirfoi negSgence on our pal be++ Or resmcmatge for any foss .-,s,damages or expenses mowed or a)tained by anyone resang atm any mdworetation made by wy Ow°facers ad- or emets —s TbMX inters) --',ons are %Meet to cur general terms we 004443 Set out In Our aurora Plc.Screeasse Comments ) Log referenced to MWD GR/NEU Dated 01-Aug-03 to 08-Aug-03 CCL MP TO E.0 P DISTANCE= 10 34' CCL M.P. DEPTH AT FLAG DEPTH = 10,041' E 0 P DEPTH AT FLAG DEPTH= 1003066 Flag Log was corrected (-9°) • • } J • {{ p t 8800 __. ,__ . ......_. , . . Perfs h { { ( t . ti • • First run - Eline Set • BRO packer with Setting tool DPU • -16'OAL — 2 0 6BRO ",;`• o 2'setting kit o 8'DPU • MAX OD:3.650" • Weight-200 lbs Second run-Slickline Set • Anchor latch,SPARC,BRO packer with Setting tool DPU • 44.5'OAL —_ o 34.5'(BRO,SPARC,Anchor) o 2'setting kit o 8'DPU • MAX OD 3.693" _ * Weight:-700 LBS o 560#(BRO,SPARC,Anchor) o 40#(setting kit) o 100#(DPU) -.41- 7 iimmere -.it 8 ', JL LENGTH PU PU ITEM DESCRIPTION ID(in) OD(in) LENGTH WEIGHT WEIGHT (in) (ft) (lbs) (lbs) 1 Casing 2 BRO Wireline Retrievable Packer(see note 1,2) 2 340 3 650 70 37 75 3 Crossover Pup 2 235 3 470 8 02 8 4 Pressure/Temperature Memory"Collar"-Not supplied by HES 2 250 3 650 33 00 60 34 45 559 5 SPARC Unit 0 000 3 693 236 55 301 6 Pressure/Temperature Memory"Collar"-Not supplied by HES 2 250 3 650 36 00 60 7 Anchor Latch Assembly 2 373 3 650 29 50 55 8 BRO Wireline Retrievable Packer(see note 2,3) 2 340 3 650 70 370 5 86 75 75 S • C, • o• 0 0 0 0 0 0 - ti O O v. cor� v � �n �n 0 N IO 10 N N- (-) y 0 0 0 0 0 0 0 i 6) CO V ct M CO • NI' O CO N N CO NY Co I- N- Co co csj O) (AN- CA N N CO I- 00 M co O O 00 N N Ns 00 CO CO I— O CO O CO I- LC) M CO O M NNCNCOONN N N- CO 4.0 C G) C1) N t N ` N co M N- 10 co LO N I� LC) CO N N- CO v O V 4•./ U 03 0 co in CO CO O N N N N c N = M_ W aO O O 00 U a) --I CO Et —I CO = N N J M �N �$ N (0 () .- - _ M �$ v- N U 00 N - t C CO LC) CNO I) 0) 1-0 J I` N CO W CC ~ C 0 Q W 7) ° QCD C.) u_ a Q Z Z (r W W W W pp O D H Z_ Z_ Z_ D U J J J I-- • 0 0 t0 M V in co O) CO CO CO CO N- IC) Lf) N- N O CO CO N CO o O) O) Q •- N O M O N L() L(7 IC) O) O a7 co O) O co CON- co a0 00 aO CO co co CO a0 a0 co a0 a) a0 CO 00 CO a0 H 0. 0 I O) N V M a0 N- V CO Lf) M O N t a0 - N- M CO O a0 O) O) N- O IC) fl- O N N QO O O) O N V' Cfl a0 r O) O) O) O) O o X- 0 O7 W 0 N- N- CO CO CO CO CO CO co N- > 0 co co co co co co co co co co co co 0 H W 0 0 w 0 cnZ w uJ 0 W 0 a U) g Y 0 0 0 ro 00 ;?, 0 0 ++ a COO N LU N LU COo § 0 0 N (4 0 J J J a a z a O a3 0 0 0 0 0 a) _0 U_ U_ J W W J CD u,0 0 0 0 O) O Z Z Z O -1 -1 _10 J a) 2 2 I Z 0 0 0 Cl N. 0_ 0 � 2 w w w W Q c Z 0 z 2 2 2 O cn cQn cJn can as CO < '012 o 0 0 0 0 0 CO O N O N V _ O O Ln o Lf) O O M 0 CO I N. co 00 0a a 0 0 0 0 0 }r 661 O a7 O O O N Sao ` 22 20 (/)) c OW J Cl) w a 0 0 ° �.. u. u. LLLaaaaaaa m a a a a a a a a a a a a d < < < < < mmmmmmm a 0 0 m 0 a) N O O O O O N N_ N_ N N _ N_ 00 D . . . . . r r 0 OC) C) O C) C) O C) O C) O C) O W N N N N N N N N N N N N OZ WU W N N N a0 C) O) C) 6) O) O) 0 ❑ D W yr r Z CLJ U W W LL W a CO CO CO QO 00 c-• r < 0 J H J J J 0 0_ 0 (3300w --J -10 a a a cn LL it Lai_ a s E 200 ° 0 ° 0 ° 0 ° 000 oo co co co co co a)a) oocoaoao 000000000000 u_ o N o LL N � Ln Ln � Ln cn Lo Ln Ln cn Lo Ln Ln COO a 0. 0 J 0 0 WO- = = = = = = = a a m a] LL LL Ln U) 0_ 1/ . S Packers and SSV's Attachment 15-08C ADL0028306 SW Name Type MD TVD Depscription 15-08C PACKER 2647.06 2647.02 7" Liner Top Packer 15-08C PACKER 7260.22 7067.92 7" Baker H Packer 15-08C TBG PACKER 8545.66 8153.48 4-1/2" Baker S-3 Perm Packer 15-08C PACKER 8607.05 8206.14 4-1/2" Liner Top Packer 15-08C PACKER 9983 8810.32 4-1/2"WFD ER Packer 15-08C PACKER 10052 8812.39 4-1/2"WFD WS-R-B Packer c • STATE OF ALASKA AL .(A OIL AND GAS CONSERVATION COMM 3N • REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate El Other D Starting Head Weld Performed Alter Casing El Pull Tubing El Stimulate-Frac ❑ Waiver❑ Time Extension El Change Approved Program El Operat.Shutdown El Stimulate-Other El Re-enter Suspended WE 2 Operator 4 Well Class Before Work. 5 Permit to Dnll Number BP Exploration(Alaska),Inc Name Development I] Exploratory 203-121-0 3 Address P.O Box 196612 Stratigraphic ❑ Service El 6.API Number Anchorage,AK 99519-6612 50-029-21180-03-00 7 Property Designation(Lease Number) 8 Well Name and Number. ADL0028306 PBU 15-08C 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 RECEIVED Total Depth measured 11552 feet Plugs measured None feet true vertical 8781 55 feet Junk measured 9880 feet FEB 1 8 2015 Effective Depth measured 11506 feet Packer measured See Attachment feet /\O(300 true vertical 8781 75 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 84 20"91 5#H-40 25 79-109 79 25 79-109 79 1490 470 Surface 2512 81 13-3/8"72#L-80 25 29-2538 1 25 29-2538 06 4930 2670 Intermediate 7423 94 9-5/8"47#L-80 24.12-7448 06 24 12-7189 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 See Attachment feet True Vertical depth See Attachment feet SCANNED i ---j.. t .' 1]'c Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 22 77-8602 23 22 77-8202 09 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) 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 Pnor to well operation 678 42413 4 180 1194 - Subsequent to operation 1106 36034 0 50 1087 14 Attachments 15 Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work. Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ El WAG ❑ GINJ❑ SUSP El SPLUG El 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: N/A Contact Garry Catron Email Garry.Catronc BP.Com Printed Name Garry Catron Title PDC PE Signature )J4"."1- C47 --- Phone 564-4424 Date 2/18/2015 00 vrt z/2 3//J RBDMS FEB 2 3 2015 Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028306 SW Name Type MD TVD Depscription 15-08C PACKER 2647.19 2647.15 7" Liner Top Packer 15-08C PACKER 7260.35 7068.01 7" Baker H Packer 15-08C PACKER 8545.79 8153.6 4-1/2" Baker S-3 Perm Packer 15-08C PACKER 9983 8810.32 4-1/2" WFD ER Packer 15-08C PACKER 10052 8812.39 4-1/2"WFD WS-R-B Packer a) Q. 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FISH WRP BROKEN SLP /0:110/1* 0:1 j\ I 2'X 1-1/2"X 1/2"THICK,3 DIE SIZED CONE ��ji01100 SPRINGS(11/09/12) /4/lff #O,/ '' 9983' H 4-1/2"WFD ER PKR,D=2.375" (05/23/09) It- 1004T H 3-1/2"DEPLOY SLV,ID=3.00" PERFORATION SUNAA RY * / 10051' -13-1/2"X 2-7/8'XO,D=2.687 REF LOG: ON XX/XX/XX7 - _ ANGLE AT TOP PERF: 86° 9660' __ ___ --— -_---_- Note:Defer to Production DB for historical pert data -_---____ -- SIZE SPF INTERVAL Opn/Sqz SHOT SQZ --- 2-7/8' 6 9660-9680 O 08/22/10 �'� 2-7/8"PRE DRILLED LNR,6.16#,L-80 STL, 12188' 2-7/8" 6 9700-9725 O 08/22/10 A tom' 2-7/8" 6 9725-9750 0 08/21/10 2-7/8"TBG w/TWO L-80 STL,.0058 bpd,D=2.377' 2-7/8" 6 9800-9825 0 08/18/10 TIEBACK ASSYill 2-7/8" 6 9825-9850 0 08/17/10 (05/23/09),D=2.25" 10051' -WSRBB ANCHOR ASSY 2-1/2" 4 9940-9980 0 08/08/03 ` w/XO(05/23/09),D=1.00' 2-1/2' 4 10000-10050 0 08/08/03 ` 2-1/2" 4 10070-10230 0 08/08/03 10052'ELM 1VVFD WS-IBB RET R(R, 2-1/2' 4 10290-10400 0 08/08/03 D=2.063'(01/25/05) 2-1/2" 4 10510-10570 0 08/08/03 1:15001 2-1/2" 4 10720-10840 0 08/08/03 'if'' 2-1/2' 4 10900-11430 0 08/08/03 4-1/2'LIR,12.6#,L-80,.0152 bpf,D=3.958" -I 11661' DATE REV BY COMJB'ITS DATE REV BY COMMENTS PRt1DHOE BAY MT p 1984 ORIGINAL COMPLETION 06/22/13 PJC WELL NAME CORRECTION WELL: 15-08C/CL1 10/21/93 SIDETRACK(15-08A) 09/09/14 RCT/JMD FX PLUG-GLV C/O(08/31/14) PERIN No: 2031210/2050050 11/22/97 SIDETRACK(15-08B) 09/09/14 JMD COORDINATES CORRECTION AR No: 50-029-21180-03/60 08/11/03 JOM/KK RIG SIDETRACK(15-08C) 01/28/15 DJS/PJC PUL PX PLUG&GLV GO SEC 22,T11 N,R14E,1645'FNL&1378'FWL 03/03/05 NORDIC 1 CTD ST(15-08C-L1) 11/13/12 DMS/AMD RJLL WRPTSET FISH(11/09/12) BP Exploration(Alaska) Image PI ¿ject Well History File coJer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aQ3- Jd.- L Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1II11II1I1111111111 RESCAN D~'TAL DATA ¢ Diskettes, No. f o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: Project Proofing BY: ~ Date: lðvb)DÇ Date: ~d-'} r J OS !J ~O Date: ()~ o Other:: NOTES: vYr£ I~IIIIIIIIIIIIIII ~ + __ = TOTAL PAGES (PO (Count does not include cover sheet) /s/ /s/ BY: Q Scanning Preparation BY: Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: &/ (Count does include cover sheet) ~ES NO 151 VVl (J NO Stage 1 Page Count Matches Number in sea" nninì prìParation: ~ Date: 1& 1 tJs- If NO in stage 1, page(s) discrepancies were found: YES BY: BY: Maria Date: /s/ I111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked IIII111111111111111 10/6/2005 Well History File Cover Page.doc {. * STATE OF ALASKA AL.A OIL AND GAS CONSERVATION COM ION 4. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate ❑ Other U Bridge Plug Pull Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development El Exploratory ❑ 203 -121 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 21180 -03 -00 7. Property Designation (Lease Number): .. 8. Well Name and Number: ADL0028306 PBU 15 -08C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11552 feet Plugs measured None feet true vertical 8781.55 feet Junk measured 9980 feet Effective Depth measured 11506 feet Packer measured See Attachment feet true vertical 8781.75 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 81 20" 91.5# H -40 29 - 110 29 - 110 1490 470 Surface 2511 13 -3/8" 72# L -80 28 - 2539 28 - 2538.96 4930 2670 Intermediate None None None None None None Production 7421 9 -5/8" 47# L -80 27 - 7448 27 - 7188.96 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet RECEIVE 1 True Vertical depth See Attachment feet DEC 1 1 201e Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 26 - 8602 26 - 8201.9 (� '.. ~• AOG 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 MAR 1 1 2013 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: 472 37698 5 1155 Subsequent to operation: 0 0 0 "' "' 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development Q - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ 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.O. Exempt: N/A Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita Summerha, Title Petrotechnical Data Technician Signatu 7 �, ;� „1�".. ...- .„..- -.- Phone 564 -4035 Date 12/11/2012 RRDMS DEC 1 2612 ,eA r2•0612. Form 10 -404 Revised 11/2011 Submit Original Only jl/OT..--- • • Perforation Attachment ADL0028306 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base 15 -08C 8/22/10 APF 9660 9680 8790.89 8791.71 15 -08C 8/22/10 APF 9700 9725 8734.13 8734.75 15 -08C 8/21/10 APF 9725 9750 8734.75 8736.06 15 -08C 8/18/10 APF 9800 9825 8740.34 8742.89 15 -08C 8/17/10 APF 9825 9850 8742.89 8745.4 15 -08C 8/17/10 BPS 9870 9871 8747.3 8747.39 15 -08C 11/9/12 BPP 9870 9871 8747.3 8747.39 15 -08C 8/8/03 PER 9940 9980 8751.08 8752.24 15 -08C 8/8/03 PER 10000 10050 8752.85 8754.34 15 -08C 8/8/03 PER 10070 10230 8754.97 8757.17 15 -08C 8/8/03 PER 10290 10400 8756.96 8757.84 15 -08C 8/8/03 PER 10510 10570 8758.74 8757.18 15 -08C 8/8/03 PER 10720 10840 8750.07 8741.96 15 -08C 8/8/03 PER 10900 11430 8739.53 8723.96 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCC 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 • • Daily Report of Well Operations ADL0028306 -.. CTU 8 w/ 1.75" CT Job Scope: Drift w/Venturi, Pull 4 1/2" «InterAct Publishing» RU Function test BOPE MU BHA consiting of Dual Acting Accelerator, WT Bar, Dual Acting Jar, 3 1/8" Venturi w/ WRP Equalizing Tool OAL = 31.60' ...Continue WSR on 11/09/12... 11/8/2012 CTU 8 w/ 1.75" CT Job Scope: Drift w/ Venturi, Pull 4 1/2" WRP «InterAct Publishing» Continue WSR from 11/08/12 pulling OOH with WHP increasing and decreasing with CT speed. At 3800' CTM WHP dropped 800 psi rapidly. CT stopped at 2668' CTM while pulling out of hole was able to move freely downhole and back up a few times. WHP would increase with CT on up swing and decrease on down swing. Something around BHA? Pumped meth down backside and WHP responded quickly. Pumped hot water down CT thinking Hydrates may have formed in tubing. After being detained for 2 hours CT came free and pooh. Cut mule shoe on equalizing sleeve. RIH w/ same, tag plug @ 9884'. Saw tbg pressure drop indicating plug equalized. pooh. MU BHA w/ 4" G spear, 3.74" WRP retrieval tool. Ran in hole latched and pulled plug from 9880' CTM hung up in perfs a few times and all x and xn nipples. Lowered BHA and discovered that all six slips in the 4 1/2" WRP had broken leaving 1/2 of one in the well measuring 2" x 1.5" x 1/2" thick. Also left in well three dime sized cone shaped springs. Discussed options with CT Scheduler and decided that Slickline should rattle GLM's and attempt to fish before coil goes back in well with venturi junk basket. Called town APE Tim Lee and discussed plan for well being POP. He will handle in AM of 11/9/2012 11/10/12. Well left S/I at time of departure. *""Job Complete * ** FLUIDS PUMPED BBLS 145 60/40 METH 164 1% SL KCL w /.06% SafeLube 309 TOTAL • • Packers and SSV's Attachment ADL0028306 SW Name Type MD TVD Depscription 15 -08C PACKER 8546 8095.79 4 -1/2" Baker S -3 Perm Packer 15 -08C PACKER 9983 8752.33 4 -1/2" WFD ER Packer 15 -08C PACKER 10052 8754.4 4 -1/2" WFD WS -R -B Packer Casing / Tubing Attachment ADL0028306 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 20" 91.5# H -40 29 - 110 29 - 110 1490 470 LINER 4625 7" 26# L -80 2640 - 7265 2639.96 - 7071.18 7240 5410 LINER 1501 7" 26# 13CR80 7271 - 8772 7075.25 - 8339.33 7240 5410 LINER 2951 4 -1/2" 12.6# L -80 8600 - 11551 8200.21 - 8781.56 8430 7500 PRODUCTION 7421 9 -5/8" 47# L -80 27 - 7448 27 - 7188.96 6870 4760 SURFACE 2511 13 -3/8" 72# L -80 28 - 2539 28 - 2538.96 4930 2670 TUBING 8576 4 -1/2" 12.6# 13Cr80 26 - 8602 26 - 8201.9 8430 7500 • • TREE FMC GEN 3 _ 'ACTUATOR D = FMC ON 15-08C S •T" CHROME t l &4 - 112" CF�tOMEE TBG � ; ACTUATOR %1XELSON '103 B. E E VV :=:' - _ __ 57 B E .EV = _ KOP= 5800' Max Angle = 94° , ,, 10695' Datum M) = WA I I I 2207' 1 FiES X NW D = 3.813" I Daturn ND= 8800' SS 113 -3/8" CSG, 72#, L -80, D = 12.347' H 2539' I l J GAS LFT MANDRH.S ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3291 3291 0 KBG-2 DMY BK 0 01/29/11 3 5590 5590 3 KBG-2 DM',' BK 0 01/29/11 IT SCAB LNR 26#, L 80 H 7265' 2 7600 7292 42 KBG-2 DMY BK 0 01/29/11 1 8457 8073 21 KBG-2 DMY BK 0 01/29/11 19 -5/8" CSG, 47 #, L -80, D = 8.681" H 7448' I- I I I 8525' H4 -1/2' I-ES X NP, D= 3.813' I Minimum ID = 1.00" @ 10061' S g I ' Hr x 4-1/2' si t S-3 FICR, D= 3.875" I WSRBB ANCHOR ASSY (06/24/09) 1 • I 8570' H4 -1/2" I-ES X NP, D= 3.813" I I I I 8590' H4 -1/2- HES XN NP(MILL® 02/24/05), D = 3.80" I 8600' 1--17 X 4- 112" BKR ZXP LNR TOP PKR I i 8602' H4 -1/2' WL.EG, 0= 3.958" I 1 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, D= 3.958"H 8602' I\ MLLOUT VW'DOW (15 -08C) 8772' - 8780' 7" I•ES EZSV 8790' FLOUT WINDOW (15-08CL1) 10016' - 10022' I 7" LNR, 26#,13 CR — I 9825' .0383 bpf, 0 = 6.276" ? ? ?? I— FISH MP BROKEN SLIP 2" X 1 -112' X 1/2' THCK, 3 DIME SEE) CONE 00� I SPRINGS (11/09/12) 01400. 04.••46 ' 9983' H4 -1/2" WFD t32 HACKER (05/23/09), D = 2.375" I • • / %! ' 1 oo4r H3-1/2" DEPLOY MBYT SLEEVE, D = 3.00" I 10051' I--13 X 2 -718' XO, D = 2.687 1 , C.: 2 -7/8' PRE- DFRLLED LNR, 6.16#, L -80 S11., —$ 12188' PERFORATION SUMMARY L-80 STL .0058 bpd, 0 = 2 REF LOG: — — — _ _ ANGLE AT TOP PE E: 86° @ 9660' III — — _ ............ _ — — Aill‘ Note: Refer b Production OB for historical perf data _ _ _ _ _ _ SEE SPF INTERVAL Opn/Sgz DATE �i 2 -7/8" 6 9660 -9680 0 08/22/10 I� 1 0051' WSRBB ANCHORASSY 2 -7/8" 6 9700 - 9725 0 08/22/10 2-7/8" TBG w /IWO �i 1w /XO {05123/09), D = 1.00' 2 -7/8" 6 9725 - 9750 O 08/21/10 TIEBACK ASSY 10052' ELM I— WFD WS -R-BB RET PKR, 2 -7/8'_ 6 9800 - 9825 0 08/18/10 (05/23/09), D = 2.25" ` Dm 2.063 (01125105) 2 -7/8" 6 9825 - 9850 0 08/17/10 1 11. 2 -1/2" 4 9940 - 9980 0 08/08/03 2 -12" 4 10000 -10050 0 08/08/03 ` 2 -1/2" 4 10070 -10230 0 08/08/03 2-112" 4 10290 - 10400 0 08/08/03 2-1/2" 4 10510 1 0 06/08/03 � °°°°°°°°°°°°°°°°°°°°°°°°° 2 -1/2" 4 10720 -10840 0 08/08/03 2 -1/2" 4 10900 - 11430 0 08/08/03 1 4-1/2' LNR 12.8#, L - 80, .0152 bpf, D = 3.958" H 11551' I DATE REV BY COMVENTS DATE FRET/ BY COMMEl1S FRJDHOE BAY UNIT 1984 ORIGINAL COMPLETION 10/04/10 SV ADI'ERF (08/22/10) WELL: 15-080 / CL1 10/21/93 SIDETRACK (15 -08A) 12/14/10 CSR/PJC PBRF CORRECTIONS FE RMIT No: 2031210 / 2050050 11/22/97 SIDETRACK (15-08B) 02/13/11 ? /AGR GLV C/O (01/29/11) API No: 50- 029 - 21180 -03 / 60 08/11/03 JDM/KK RIG SIDETRACK (15 -08C) 11/13/12 DMS/JMD PULL WRWSET FISH (11/09/12) SEC 22, T11N, R14E, 4050.67' FE_ & 3719.98' FM. 03/03/05 NORDIC 1 CID ST (15- 08C -L1) _ 08/30/10 DBM PJC SETWRP (08/21/10) BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, � l ( Z(Z Oi DATE: February 2, 2011 P. I. Supervisor FROM: Jeff Jones SUBJECT: Choke Inspection Petroleum Inspector PBU 15 -08C BPXA PTD #2031210 January 31, 2011: At approximately 5:45 PM, Mr. Travis Rybecki (BPXA) notified me by telephone at the AOGCC North Slope Office that an uncontrolled hydrocarbon release had occurred at BPXA's PBU Drill Site 15 manifold building. He informed me that the Halon had dumped, Operations had performed an emergency shut down (ESD) of the pad and there was no fire or known spill out of containment at this time and the pad was being depressured for inspection and repair. February 2, 2011: I tra veled to BPXA's Flow Station 3 maintenance shop to inspect the failed ry p p choke from BPXA's PBU well 15 -08C that resulted in the uncontrolled hydrocarbon release on 1/31/10 at DS -15 manifold building. I met with BPXA's Rob Endibrock and we inspected the failed choke. Inspection of the choke's interior flow path revealed two distinct erosion paths on opposite sides, with one having removed enough valve body material to allow hydrocarbons to escape through an approximately 2" long hole eroded completely through the valve body, leaving the contents open to atmosphere. Pictures of the exterior and interior of the PBU 15 -08C choke are attached. Summary: I was notified of an uncontrolled hydrocarbon release at BPXA's PBU Drill Site 15 manifold building and I inspected the failed choke, removed from PBU well 15 -08C. Attachments: PBU 15 -08C choke photos (4) MAR 2 i'xi 1 Choke in flowline within DS 15 manifold building; flowling from PBU 15 -08C • • PBU DS15 Manifold Building Gas Release PBU 15 -08 Choke Fa Photos by AOGCC Inspector Jeff Jones February 2, 2011 � „.,� ,� p , ,, A. itt i j `:R r L. {4, . x _ ' ' " ' '''' ' ` "" ' , .4 4 ' k 40 ' 4? , kts, , 1 /' ° ,* 4: 4 ' A ibil l • P BU 15 -08 choke recovered from flowline ina DS 15 m anifold building; split in tail piece immediately downstream of choke 2 • S PBU DS15 Manifold Building Gas Release PBU 15 -08 Choke Failure Photos by AOGCC Inspector Jeff Jones February 2, 2011 Internal view of tail piece toward choke (from tail piece outlet); evidence of erosion 3 OPERABLE: Producer 15 -08C (PTD #01210) Tubing integrity restored - Pas. MITIA Page 1 e Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] � Sent: Sunday, January 30, 2011 1:57 PM ; � To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead Cc: Lee, Timothy; Walker, Greg (D &C); AK, D &C Well Integrity Coordinator Subject: OPERABLE: Producer 15 -08C (PTD #2031210) Tubing integrity restored - Passing MITIA All, Producer 15 -08C (PTD #2031210) passed an MITIA after dummy gas lift valves were set. The passing test verifies tubing integrity has been restored. The well has been reclassified as Operable and may continue on production. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 tt Harmony Radio x2376 ? ' Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, January 18, 2011 1:56 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, OPS PCC EOC TL; AK, RES GPB Eas -Ils Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; A ■0: C Well Services Operations Team Lead Cc: King, Whitney; AK, D &C Well Integrity Coordinator; Lee, Timothy Subject: UNDER EVALUATION: Producer 15 -08C (PTD #2031210) Sustain Casing Pressure on the IA All, Producer 15 -08C (PTD #2031210) has been found to have •stained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to 2450/24 2/50 psi on 01/16/11. The well has been reclassified as Under Evaluation. The well was place, on production last night and may remain online while diagnostics are performed to evaluate TxIA .mmunication. The plan forward is as follows: 1. DHD: TIFL If TIFL fails: 2. Slickline /pumping: S- DGLVs, MITIA to 3000 psi A TIO plot and wellbore schematic have been included for reference. 2/1/2011 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory ^ ~ 203-1210 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21180-03-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ,~ ADLO-028306 PBU 15-08C 10. Field/Pool(s): ,~ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11552 feet Plugs (measured) None feet true vertical 8781.55 feet Junk (measured) None feet Effective Depth measured 11506 feet Packer (measured) 8546 true vertical 8781.75 feet (true vertical) 8154 Casing Length Size MD TVD Burst Collapse Structural Conductor 90 20" 91.5# H-40 SURFACE - 90 SURFACE - 90 1490 470 Surface 2539 13-3/8" 72# L-80 SURFACE - 2539 SURFACE - 2539 4930 2670 Intermediate 7448 9-5/8" 47# L-80 SURFACE - 7448 SURFACE - 7189 6870 4760 Production 1531 7" 26# 13CR80 7271 - 8772 7075 - 8339 7240 5410 Liner 4625 7" 26# L-80 2640 - 7265 2640 - 7071 7240 5410 Liner 2951 4-1/2" 12.6# L-80 8600 - 11551 8200 - 8782 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR SURFACE - 8602 SURFACE - 8202 Packers and SSSV (type, measured and true vertical depth) 7"X4-1/2" BKR S-3 PKR 8546 8154 "~' 12. Stimulation or cement squeeze summary: "~ - Intervals treated (measured): „~ ~. ~ ~, F~~,. ~~4 Treatment descriptions including volumes used and final pressure: /~ ~"4i~ ~6 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: ~ Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ 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: NA Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature P ne 564-4944 Date 8/25/2010 rvnn iv-•rvt r~pv~acu ncvva •~r•s•v r~VV • w+-.,_. /~ ,a,,•"~ ~ 15-08C 203-121 PERF ATTA(_NMFNT Sw Name Pert Operation Code Operation Date Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15-08C PER 8/8/03 9,940. 9,980. 8,809.07 8,810.23 15-08C PER 8/8/03 10,000. 10,050. 8,810.84 8,812.33 15-08C PER 8/8/03 10,070. 10,230. 8,812.96 8,815.16 15-08C PER 8/8/03 10,290. 10,400. 8,814.95 8,815.83 15-08C PER 8/8/03 10,510. 10,570. 8,816.73 8,815.17 15-08C PER 8/8/03 10,720. 10,840. 8,808.06 8,799.95 15-08C PER 8/8!03 10,900. 11,430. 8,797.52 8,781.95 15-08C APF 8/17/10 9,825. 9,850. 8,800.88 8,803.39 15-08C BPS 8/17/10 9,870. 9,871. 8,805.29 8,805.38 15-08C APF 8/18/10 9,800. 9,825. 8,798.33 8,800.88 15-08C APF 8/21/10 9,725. 9,750. 8,792.74 8,794.05 15-08C APF 8/22/10 9,660. 9,680. 8,790.89 8,791.71 15-08C APF 8/22/10 9,700. 9,725. 8,792.12 8,792.74 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED 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 • • 15-08C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 8/17/2010aCTU #9 w / 1.75" ct Job scope_Log & Set WRP & perforates «< InterAct is j publishing »> RIH w /SLB GR CCL logging tool & WFD 3.771" WRP drift to 1 ;9991' Pooh. (Safety drill PACK OFF failure) RIH w/ Weatherford 3.77" WRP plug. Selrplug 10' higher than program requested C 9870' to avoid setting in 'collar. Apply 1000 psi over WHP test plug integrity. good. Pooh. RIH w / 25' of ~--~~ SLB 2.875" HSD PJ2906-HMX- 6 SPF 60 shot phase guns top shot~825' - / l ~) bottom shot 9850'. **job in progress** v ~..______ ~____. _._ v __~ ~ _ _ ~. _ . ~__~: 8/18/2010 ~ CTU #9 w / 1.75" ct Job scope: Log & Set W RP & perforate. «< Continue WSR ,from 8/17/10 »> «< InterAct is publishing »> Confirmed guns fired RIH with gun run #2. Guns HDS-PJ2906-HMX 6spf 60 phase 25'. Ton shot 9800' bottom shot 9825' MU/RIH w/Gun #3, 25' of 2 7/8" 6spf 60 phase PJ2906. RIH to €9913' to tag WRP. WRP appeared to have fallen down hole. Did not fire gun. Pull un-shot gun out of hole. MU/RIH w/venturi «< Job in progress »> __ __..~_ ~ _ ___ ___ ~... ,_. ~ __ w__._._ _ _ _._. __ _.... __~ .~.. _.__~.~ 8/19/2010 CTU #9 w / 1.75" CT Job scope: Log & Set WRP & perforate. «< Continue WSR {from 8/18/10 »> «< InterAct is publishing »> RIH w/Venturi assembly with ;motor. 32.8' TOL. Tag plug 9919' clean off w/venturi, POOH, tools full of paraffixzn/asphaltine. RIH w/Venturi assembly. T,.~g WRP ~ 189.Z„ Recip w/ vventuri /motor. Dry tag, flag CT. POOH. MU/RIH w/ 3.45" DJ nozzle. Jet top of plu & tb w/25 bbl's of diesel xylene. POOH«<Job in progress»> 8/20/2010fCTU #9 w / 1.75" CT Job scope: Log, Set WRP & perforate. «< Continue WSR from 8/19/10 »> «< InterAct is publishing »> POOH with JSN assembly, M/U ~& RIH w/WRP pulling tool assembly.. Tagged plug @ 9920'. RIH to 9940'. Pull out w/fish to 9275'. Pulled heavy. Can't go up/can go down. Bullhead 25 bbls of 50:50 diesel/xylene down backside. Difficulty trying to spot pill due to well 'swapping out. Bullhead hot KCL down backside @ 4 bpm. Perform Emergency `Drill -PIPE RUNAWAY. RIH, attempting to cock jars. Tag out on liner top @ ";9978'. Able to get jar action. Get 9 licks up, pull out of hole to inspect BHA. Recover WRP. Missing 3 springs. Chain/pack off inspection, cut 100' pipe. RIH WFD 3.771" Drift assembly. ~v..~_~____.___. __ _.____~~,_.__.~~. __ .~..~_ _~ 8/21/2010,CTU #9 w / 1.75" CT Job scope: Log, Set WRP & perforate. «< Continue WSR from 8/20/10 »> «< InterAct is publishing »> RIH & drift to 9983', jet w/Diesel/Xylene across new per intervals &WRP setting interval. POOH, M/U ,WRP & setting tools, RIH. Correct depth at flag. Set mid elgtnnent WRP n 9865'. !MU/RIH w/ 25' of 2 7/8" 6spf gun run #3 Tag WRP and PU to top shot at 9725'. Confirmed guns fired. POOH. MU/RIH w/25' of 2 7/8" 6spf gun run #4. »»Job in Progress««« 8/22/2010 C U #9 w / 1.75" CT Job scope: Log, Set WRP & perforate. «< Continue WSR 'from 8/19/10 »> «< InterAct is publishing »> Continue RIH w/ 25' of 2 7/8" 6spf gun run #4. Tag WRP and PU to shooting depth. shot 9700'-972~ti..'., Good 'indication of guns fired. POOH. MU/RIH w/20' of 2 7/8" 6spf gun run #5. Tag ',WRP and PU to shooting depth. Shot 9660-9680'. POOH. FP wellbore to 2500' w/ water/meth. Job is complete. Well is ready to POP. 7 • • FLUIDS PUMPED BBLS 394 1 % KCI W/0.6% SL 641 XS 1 % KCL 78 50/50 METH 1113 Total TREE = FMC GEt WELLHEAD = ~ FMC ACTUATOR = AXELSO~ KB. ELEV = 57.99 BF. ELEV = KOP = 5800 Max Angle = 94 @ 10695 Datum MD = WA Datum TV D = 8800' S: ~ 13-318" CSG, 72#, L-80, ID = 12.347" SAFETY ES: *** 7" CHROME LNR & 4-112" 15 -~ 8 G -L 1 CHROME TBG*** GAS I IFT MANDRFI_S '7" SCAB LNR, 26#, L-80 9-5/8" CSG, 47#, L-80, ID = 8.681" 7265' 744$' Minimum ID =1.00" @ 10051' WSRBB ANCHOR ASSY (05/24/09) 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958"~ 8602' MILLOUT WINDOW (15-08C) 8772' - 8780' MILLOUT WINDOW (15-08CL1) 10016' - 10022' 7 HES S EZSV I--j 879 7" LNR, 26#, 13 CR~ 9825' 0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 88 @ 9940' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-112" 4 9940 - 9980 O 08/08/03 2-112" 4 10000 - 10050 O 08/08/03 2-112" 4 10070 - 10230 O 08/08/03 2-112" 4 10290 - 10400 O 08/08/03 2-1/2" 4 10510 - 10570 O 08/08/03 2-1/2" 4 10720 - 10840 O 08/08/03 2-1/2" 4 10900 - 11430 O 08/08/03 2-7/8" TBG w /lW0 TIEBACK ASSY (05/23/09), ID = 2.25" 2207' 4-1i2" HES X NIP, ID = 3.813" ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3291 3291 0 KBG-2 DOME BK 16 03/05/05 3 5590 5590 3 KBG-2 SO BK 20 03/05/05 2 7600 7292 42 KBG-2 DMY BK 0 08/10/03 1 8457 8073 21 KBG-2 DMY BK 0 08/10/03 8525' --~4-1/2" HES X NIP, ID = 3.813" I 8546' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8570' - 4-112" HES X NIP, ID = 3.813" $5g0' 4-1/2" HES XN NIP (MILLED 02/24!05), ID = 3.80" 8600' 7" X 4-1/2" BKR ZXP LNR TOP PKR 8602' 4-112" WLEG, ID = 3.958" J-~4-112" WFD ER PACKER {05123109), ID = 2.375" 0047' 3-112" DEPLOYMENT SLEEVE, ID = 3.00" 10051' 3-1/2" X 2-7/8" XO, ID = 2.687 2-7/8" PRE DRILLED LNR, 6.16#, L-80 S~--C L-80 STL, .0058 bpd, ID =2.377" ~_~~~_~- 10051' WSRBB ANCHOR ASSY ~ w /XO (05/23/09), ID = 1.00" 10052' ELM WFD WS-R-BB REf PKR,~ ID= 2.063' (01 /25/05) 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~--~ 11551' DATE REV BY COMMENTS DATE REV BY COMMENTS 1984 ORIGINAL COMPLETION 11!14/09 JFO/PJC TREE C/O (11/15/09} 10/21193 SIDETRACK (15-08A) 11!22/97 SIDETRACK (15-08B) 0$!11/03 JDMIKK RIG SIDETRACK (15-08C) 03(03/05 NORDIC 1 CTD ST (15-08C-L1) 05!24!09 SRB/TLH PKR/TB ASSY/ANCHOR SET PRUDHOE BAY UN(T WELL: 15-08C L1 PERMIT No: 2031210, 2050050 RPI No: 50-029-21180-03 (60) SEC 22, T11 N, R14E, 4050.67' FEL & 3719.98' FNL BP Exploration (Alaska) WELL L~~ TRA/1«/TT~4L @. P~Ae~ o•~Na~~ SesvlGa, ~NC_ • To: ABC 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/ MTTj The technical data listed below ~s being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the foAowing BP Expbretion (Alaskaj, Inc. Petrotecfinical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Bhrd Anchorage, Alaska 99506 and ProActive Diagnost~ Services, Mc. Attn: Robert A. Richey 130 West Irrternational Airport Road Suite C Anchorage, AK 99518 Fa~c (907j 245.9952 ~,~3-gar 1~0~~ - 1) Coil Flag 22-May-09 15-08C EDE 50-02821180.03 /~`~`~~. 2 ~~~~~~r ~~~ . ) ~ ~-~ J~~ Q ~ 2OG9 Signed : Date ~lasi<2 Cil ~ Gas i.Qns. Gom,~nissian Print Name: lar~choraae PROACTRlE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~dsanchora4eCaDmernorYloG com WESSRE : ens rrlemorYBog.corrs C:\Docinnan~ and Settings\pwner\Desktop\Twnsmit_BP.docx • -: -_ 03/01/2008 DO NOT PLACE ~~ _ ~: } ~r: ~~_ ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFichelCvrPgs_Inserts\Microfilm Marker.doc e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comrn. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 ,31fD RE: MWD Formation Evaluation Logs 15-08C, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 15-08C: LAS Data & Digital Log hnages: 50-029-21180-03 :)D?J ~ I ~\ 1 CD Rom ~~ 9/B810lÞ lÒ S~ DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031210 Well Name/No. PRUDHOE BAY UNIT 15-08C Operator BP EXPLORATION (ALASKA) INC ;PÙw--J. J ~ l.óo3 API No. 50-029-21180-03-00 MD 11552 /' 8782 ./ Completion Date 8/10/2003 /' Completion Status 1-01L TVD REQUIRED INFORMATION Mud Log No Samples No Current Status 1-01L Directional su~ . (data taken from Logs Portion of Master Well Data Maint Interval OH/ '-'" Start Stop CH Received Comments 8762 11552 Open 8/29/2003 MWD Survey Final: text file and PDF 8762 11552 Open 8/29/2003 8645 11551 Open 9/16/2003 8654 11509 Open 9/16/2003 MWD-GR, EWR4, CNP, SLD,ROP 8654 11509 Open 9/16/2003 MWD-GR, EWR4, CNP, SLD, ROP 8654 11509 Open 9/16/2003 MWD-GR, EWR4, CNP, SLD,ROP Sample Set Number Comments --' DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, ASI, NEU, DEN Well Log Information: Log/ Data e Electr Digital Dataset Med/Fnnt Number D Name Directional Survey (j)N ~N Log Log Scale Media Run No Final Directional Survey 11981 LIS Verification D 11981 I nd uction/Resistivity D 11981 Neutron D 11981 Density Final 2,3,4 2,3,4 2,3,4 2,3,4 Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION y¡Q Chips Received? ~ ~ Well Cored? Daily History Received? Formation Tops Analysis Received? Comments: Permitto Drill 2031210 MD 11552 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Operator BP EXPLORATION (ALASKA) INC Well Name/No. PRUDHOE BAY UNIT 15-08C 8782 API No. . 50-029-21180-03-00 JI:;;ion Date 8/10/2003 I Completion Status Current Status 1-01L UIC N Date: ¡ 7 N 0 I/.~ r- 1-01L .~. ~' ) } /: (90,3 _u) d , \\Cr8\ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7tl¡ Avenue, Suite 100 Anchorage, Alaska September 9,2003 RE: MWDFoffilation Evaluation Logs 15-08C, AK-MW-2589887 1 LDWG fonnatted Disc with verification listing. API#: 50-029-21180-03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 c::;;~-::..-..... Signe(i~C:\'~ ,~ '\ ~,,-~è,-~_ð-·"~ Date: t~ECEiVED SEP 16 2003 A!aska Og ¿~ Gas C~)ftZ. Commi3eton i\nd'loraf:Þ'e ~ß~\\\ ~ '\ STATE OF ALASKA " ALAS {¡ ,ilL AND GAS CONSERVATION COM. )SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development o Exploratory OGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit Number BP Exploration (Alaska) Inc. 8/10/2003 203-121 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 8/3/2003 50- 029-21180-03-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Number Surface: 8/7/2003 PBU 15-08C 1645' SNL, 1378' EWL, SEC. 22, T11N, R14E, UM 8. Elevation in feet (indicate KB, DF, etc.) 15. Field and Pool Top of Productive Horizon: 272' NSL, 2092' EWL, SEC. 15, T11N, R14E, UM KBE = 57.99' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 1498' NSL, 687' EWL, SEC. 15, T11N, R14E, UM 11506 + 8782 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ TVD) 16. Lease Designation and Serial No. Surface: x- 677321 y- 5959869 Zone- ASP4 11552 + 8782 Ft ADL 028306 TPI: ----- Zone- -- 11. Depth where SSSV set 17. Land Use Permit: x- 677986 y- 5961801 ASP4 ---- -- (Nipple) 2207' MD Total Depth: x- 676550 y- 5962994 Zone- ASP4 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes ONo N/A MSL 1900' (Approx.) 21. Logs Run: MWD, DIR, GR, RES, ABI, NEU, DEN 22. CASING, LINER AND CEMENTING RECORD :):' ..... PASIN~',I,"¡:¡· ~ ~, 'I. ' , ;: ': , : ',' ~ ,: I ,,'!:,,' 'I I , I 1,",1,> ':,1;":'1" ,,~':,"I >'1" '::,1 i I':" I,', ':. ;1 ' " ,.,SEJ.¡rING::OEI:i!;rt;l:.¡'I'",:1 :.; 'j"H"'E' ·."1·" ""··"I:"I::,.;,!:,:I,'I: ''''''''''·,1'... ,'I,::, :{i"I·"I, ·."",,'¡·'!I;,;II':~'·"i.·' :",',::, . !.'I.'I"·I·." ~ :: : I '" ",,; " : : ' I" II I ' ...! ,I' I " I, I ' : ! ,II : I" , ,,: ' :,'1,,: I'·"G~D'~I,,'I'!..I:) "'I',..·~,'~. .1\1:". I'~,I"'.·'·".·,.' ""I')J~'i,~ . ", I", ),:'1111'(':::',:,:1,:",' ." ,:i .1.,1. ",~IZE"",,:., WJ· I¡ ~Fa:" ,n!., I,I ., "::,¡"10ij'I!'.,,.' '1'18ø¡rI0M'" ¡." :I:·::;:¡II:':ª ~,~:,:,:!!'I!:~¡"I::~"I: ."'11",1,1 ,,,,',,.' 'II", ~"""."" ,'I,.',' 20" 91.5# H-40 Surface 90' 30" 370 sx Permafrost II 13-3/8" 72# L-80 Surface 2539' 17-1/2" 1938 sx PF 'E', 400 sx PF 'C' 9-5/8" 47# L-80 Surface 7448' 12-114" 500 sx Class 'G', 300 sx PF 'C' 7" 26# 13Cr80 7271' 8772' 8-1/2" 534 sx Class 'G' 7" 26# L-80 2640' 7265' Scab Lnr 274 sx Class 'G', 223 sx Class 'G' 4-1/2" 12.6# L-80 8600' 11551' 6-1/8" 351 sx Class 'G' 23. Perforations 0Ren to Production (MD + TVD of Top and ...' ,:.I, " ,I' , I I,'" ,.,' . . , , " , , ' , ' ' " " ., ' " ",: ,', ~, " I', 'I ': ." , "I " . .' :..:.. "" 'i,.,',· '.'''' "," 'I:,':" ",I ::,"',II,"',i:"'¡',I:'",:",,, '., ',.\ """," 1.~'t:~:II"':':'II',.'1 i ',:',.' :"1', ""'"," ", ',"I""""" Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 8602' 8546' MD TVD MD TVD 9940' - 9980' 8809' - 8810' 2~~"" ' , '1'1;' ,;!,!ACI'PI'F¡I~C~0a.è 'GEM'E;NTSQ~E~EtETÖ.,:·. " , ,···'·:"';.:'1':::···.,:,·'··"'.·::,.··,· 10000' - 10050' 8811' - 8812' "":1,:,'1""'; 1"'1,1, ;,:",""'" ",',"1'1 1',,1" " '.,,: I;,;: ,:,,1,:,:';,':" .:',).', I: ",:,'",1 '., ',:, ,I:, "'''':'1 I, ,1"1,'-,', ,:1', ';' . :":;:.', ,I " ,':,.' ,1:1,1.' ',," ,I,' I " I, I 10070' - 10230' 8813' - 8815' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10290' - 10400' 8815' - 8816' 10510' -10570' 8817' - 8815' Freeze Protect with 155 Bbls of Diesel 10720' - 10840' 8808' - 8800' 10900' - 11430' 8798' - 8782' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): August22,2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF W A TER-BsL CHOKE SIZE I GAS-OIL RATIO 9/3/2003 4 TEST PERIOD ~ 674 59 6 840 87 Flow Tubing Casing Pressure CALCULATED ~ OIL-BSL GAs-McF W A TER-BsL OIL GRAVITY-API (CORR) Press. 291 24-HoUR RATE 4,044 354 36 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none..,..state ."nQne','. .. , IRBDUS BfFL SEP 1 ~?n03 ~,:",,::: ¡ " None -' % _.lUd___'d21 ' ORIGINAL .:.::~~.::~ \: Form 10-407 Revised 2/2003 (,~ CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKER ') NAME MD TVD 8773' 8340' 8971' 8478' 9081' 8543' 9164' 8593' 9482' 8749' 9678' 8792' Sadlerochit Top CGL Base CGL 23SB Zone 1 B Zone 1A 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 29. ')ORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ ~ Wt J.M& Title Technical Assistant PBU 15-08C Well Number 203-121 Permit No. I Approval No. Date 09IÞDL{"03 Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Phil Smith, 564-4897 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 20: True vertical thickness. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 21: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 O~~iG11~AL Legal Name: Common Name: Test Date 8/2/2003 FIT 15-08 15-08C Test Type Test Depth (TMD) 8,784.0 (ft) Bp·EXPLORATION Leak"OffTesfSummary TesfDepth (TVD) 8,345.0 (ft) AMW 8.50 (ppg) SurfacePréssure LeákOffPressu'r'e(BHP) 650 (psi) 4,335 (psi) EMW 10.00 (ppg) ~ .~. Printed: 8/11/2003 10:59:57 AM ') ) Page 1 of 12 BP EXPLORATION Operations Summary, Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-08 15-08C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES I I I I I I From - To : Hours Task Code. NPT ' Phase Date 7/28/2003 11 :00 - 12:00 1.00 MOB P 12:00 -15:30 3.50 MOB P 15:30 - 20:30 5.00 RIGU P 20:30 - 21 :00 0.50 RIGU P 21 :00 - 21 :30 0.50 WHSUR P 21 :30 - 22:30 1.00 WHSUR P 22:30 - 23:00 0.50 WHSUR P 23:00 - 00:00 1.00 WHSUR P 7/29/2003 00:00 - 04:45 4.75 WHSUR P 04:45 - 05: 15 0.50 WHSUR P 05: 15 - 06:00 0.75 WHSUR P 06:00 - 08:00 2.00 WHSUR P 08:00 - 09:30 1.50 BOPSUR P 09:30 - 14:00 4.50 BOPSURP 14:00 - 14:30 0.50 BOPSUR P 14:30 - 16:00 1.50 BOPSURP 16:00 - 17:30 1.50 PULL P PRE PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 17:30 - 19:00 1.50 PULL P DECOMP 19:00 - 22:00 3.00 PULL P DECOMP 22:00 - 22:30 0.50 PULL P DECOMP 22:30 - 23:30 1.00 PULL P DECOMP 7/30/2003 23:30 - 00:00 00:00 - 02:30 0.50 PULL P 2.50 BOPSUR P 02:30 - 04:00 1.50 FISH P Start: Rig Release: Rig Number: I Spud Date: 9/16/1984 End: 8/10/2003 7/28/2003 8/10/2003 Description of Operations Prepare for rig move from 15-23 to 15-08. Move shop, sub base, pits, and camp to 15-08C. MIRU. Spot sub structure, pit module, and shop. Rig up on 15-08 location. ACCEPT rig at 20:30 hrs, 07-28-2003. Pre spud safety and environmental meeting. Install secondary annulus valve. Pull BPV with DSM lubricator. R/U circulating lines and test to 3,500 psi. PJSM. Open well and monitor pressures. SITP 470 psi SICP 500 psi. Circulate 9.8 ppg brine at 2 bpm and 500 psi down to tubing cut at 9,025'. Increase rate to 3 bpm and circulate 9.8 ppg around to surface. Shut down and monitor well. No flow. Confirm 0 psi on tubing and annulus. Blow down lines. R/U and install FMC TWC. Test from below to 1,000 psi. Blow down surface equipment. RID lines. NID tree and adapter flange. N/U BOPE R/U test equipment. Test BOPE and all related valves to 250 psi low and 3,500 psi high. Witness of test by John Crisp of the AOGCC. LID test joint. DSM R/U to pull TWC with lubricator. Encounter difficulties. Pump on TWC to clear debris. Pull TWC. RID lubricator. PJSM. BOLDS. Unseat hanger with 125K. Pull to 175K up weight. Relax and reseat hanger. Pull up to 195K. Tubing parted; tubing hanging weight 65K. Monitor well. Check derrick and crown sheaves. O.K. Pull hanger to rig floor. LID hanger. R/U 4 1/2" tubing equipment. RlU Cameo control line spooling unit. LID 41/2",12.6#, L-80, BTRS tubing. LID SSSV. RID control line spooler. Recovered 53 SS bands. LID 41/2" tubing to 41/2" X 31/2" crossover. C/O handling equipment. LID 3 1/2", 9.2#, L-80, TDS tubing. String parted at pin end of #5 GLM (uppermost GLM). Lower pup joint(9.86'), with coupling, remains in the hole. Total recovery: 75 joints 41/2", 12.6, L-80 tubing 1 SSSV and 53 SS control line bands 2 joints 3 1/2", 9.2#, L-80 tubing 1 3 1/2" pup joint (9.93') 1 GLM Top of fish at 3,181 '. DECOMP RID tubing equipment. DECOMP Clear rig floor. Test lower rams and Hydril to 250 psi low and 3,500 psi high. Install wear bushing. DECOMP P/U Baker O/S with 41/4" grapple, bumper sub, and 9 - 6 1/2" Printed: 8/11/2003 11:00:05AM ) ) BP EXPLORATION Operations Summary Report Page 2 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-08 15-08C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/28/2003 Rig Release: 8/10/2003 Rig Number: Spud Date: 9/16/1984 End: 8/10/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/30/2003 02:30 - 04:00 1.50 FISH P DECaMP drill collars to 290'. 04:00 - 06:30 2.50 FISH P DECaMP RIH P/U 4" HT40 drill pipe from 290' to 3,153'. P/U weight 90K, SIO weight 90K. 06:30 - 08:30 2.00 FISH P DECaMP Wash down to fish at 4 bpm and 150 psi. Engage fish at 3,187'. Work pipe to 250K up weight (160K overpull)- 50K down weight. Gained 5' tubing movement. Tubing parted while working pipe. Up weight 90K. Monitor well bore. 08:30 - 10:00 1.50 FISH P DECaMP Inspect derrick and top drive. POOH from 3,187' to 290'. 10:00-11:00 1.00 FISH P DECaMP cIa handling equipment. POOH from 290' with BHA. Break down OIS tool. Recover 1 tubing collar. 11 :00 - 12:00 1.00 FISH P DECaMP M/U O/S BHA #2 to 293'. 12:00 - 13:00 1.00 FISH P DECaMP RIH with drill pipe from 293' to 3,187'. Up weight 90K, Down weight 95K. Engage fish at 3,187'. 13:00 - 15:30 2.50 FISH P DECaMP Space out for lubricator. PJSM. R/U lubricator and 'Y-block' side door sub. RlU SWS. 15:30 - 18:30 3.00 FISH P DECaMP SWS RIH with 2 3/8" chemical cutter and CCL. Chem cut tubing at 8,797'. SWS POOH and LID Chemical cutter. NOTE: SWS encountered tight spot at crossover above drill collars. Pulled free. Lower section of chem cutter missing at surface. Approximately 24" in length X 2 3/8" o.d. 18:30 - 19:30 1.00 FISH P DECaMP P/U and flex pipe. Work to 21 OK P/U weight. Pipe parted. Hanging weight 140K. RID SWS. RID side door sub and lubricator. 19:30 - 21 :00 1.50 FISH P DECaMP POOH with drill pipe from 3,187' to 293'. 21 :00 - 22:00 1.00 FISH P DECaMP LID fishing assembly from 293' to 16'. Break out fish and LID. 22:00 - 00:00 2.00 FISH P DECaMP R/U 3 1/2" tubing equipment. LID 31/2" tubing from 5,596' to 4,049'. 7/31/2003 00:00 - 03:30 3.50 FISH P DECaMP LID 31/2",9.2#, L-80, TDS tubing. Recovered 177 joints 31/2" tbg, 2 GLM, 5.33' cutoff section of pup joint (9.90') above GLM #2. TOF calculated at 8,797.69'. 03:30 - 05:00 1.50 FISH P DECaMP RID tubing handling equipment. Clear rig floor. 05:00 - 06:00 1.00 CASE P TIEB1 R/U SWS. PJSM. 06:00 - 10:00 4.00 CASE P TIEB1 SWS RIH with CCL, Junk basket, 6.15" Gauge ring. Clear to tubing stump. POH. RIH with HES 7" EZSV and set at 8,797' (WLM). POH. 10:00 - 10:30 0.50 CASE P TIEB1 RID SWS 10:30 - 12:00 1.50 CASE P TIEB1 M/U HES 9 5/8" RTTS. RIH to 2,749' and set. 12:00 - 13:00 1.00 CASE P TIEB1 Pressure test 9 5/8" casing to surface to 3,500 psi for 30 minutes. Record test. 13:00 - 14:00 1.00 CASE P TIEB1 POH with drill pipe from 2,749' to 43'. 14:00 - 14:30 0.50 CASE P TIEB1 LID RTTS. Clear rig floor. 14:30 - 16:00 1.50 CASE P TIEB1 PJSM. M/U polish mill. RIH with drill pipe to 2,903'. 16:00 - 18:30 2.50 CASE P TIEB1 P/U drill pipe from 2,903'. Tag Tie-back receptacle at 7,260'. 18:30 - 19:00 0.50 CASE P TIEB1 Polish TBR from 7,260' to 7,266' at 4 bpm and 230 psi. Up weight 138K, Down weight 136K, Rot 140K. Monitor well. 19:00 - 21 :30 2.50 CASE P TIEB1 POOH with drill pipe from 7,260' to 9'. Drop rabbit at 3,400'. Brass indicators confirm full insertion of polish mill into TBR. LID mill. 21 :30 - 22:30 1.00 CASE P TIEB1 cIa top rams to 7". 22:30 - 23:00 0.50 CASE P TIEB1 Pull wear bushing. RlU test joint. Test 7" rams to 250 psi low and 3,500 psi high. RID test joint. Set wear bushing. 23:00 - 00:00 1.00 CASE P TIEB1 R/U 7" liner equipment. 8/1/2003 00:00 - 00:30 0.50 CASE P TIEB1 PJSM. RlU to run 7", 26#, L-80, BTC-M liner. Printed: 8/11/2003 11 :00:05 AM ) ') BP EXPLORATION O.perations Summary Report Page 3 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-08 15-08C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/28/2003 Rig Release: 8/10/2003 Rig Number: Spud Date: 9/16/1984 End: 8/10/2003 Date From - To Hours Task Code NPT Phase Description of Operations 8/1/2003 00:30 - 02:30 2.00 CASE P TIEB1 P/U Seal assembly and casing pup joint. Unwrap seals and discover upper set of seals damaged. LID assembly and hot-shot for redress. Cut and slip drilling line. Service top drive. Redressed seal assembly returned at 02:30. 02:30 - 09:00 6.50 CASE P TIEB1 P/U seal assembly and M/U 7", 26#, L-80, BTC-M liner to 4,729'. Ran a total of 112 joints 7",26#, L-80, BTC-M liner. Average M/U torque 8,000 ft-Ibs. Installed a total of 55 RH turbolators, every other joint. Allowed to free float. Made up liner connections with BOL2000 thread compound. 09:00 - 09:30 0.50 CASE P TIEB1 Circulate one liner volume at 4,729' at 6 bpm and 200 psi. 09:30 - 10:30 1.00 CASE P TIEB1 RIH with drill pipe from 4,279' to 7,249'. 10:30 -11:00 0.50 CASE P TIEB1 M/U rotary cement head and manifold. 11 :00 -12:00 1.00 CASE P TIEB1 CBU at 6 bpm and 680 psi. 12:00 - 14:00 2.00 CEMT P TIEB1 PJSM. Dowell pump 5 bbl water and test lines to 4,500 psi. Pump 5 bbl8.4 ppg CW100, 30 bb110.8 ppg MudPUSH. Mix-on-the-fly and pump 88 bbl 13.5 ppg lead 'G' cement, followed by 46 bb115.8 ppg tail 'G' cement. Shut down. Drop dart. Dowell displaced plug with 5 bbl water. Turn over to rig and displace with 198.8 bbl; bump plug. CIP at 13:40 hours 8/01/2003. Set liner hanger with 2,500 psi. Increase to 4,000 psi to set liner top packer. Rotate 15 RH turns to release running tool. Increase pressure to 1,000 psi and unsting. 14:00 - 15:00 1.00 CEMT P TIEB1 Circulate at 13 bpm and 2,530 psi. Trace cement (-1 bbl) back to surface. Pump dry job, LID rotary cement head, BID surface equipment. 15:00 - 16:30 1.50 CEMT P TIEB1 POOH from 2,651'. LID running tool. 16:30 - 18:30 2.00 BOPSURP TIEB1 CIO 7" rams to 3 1/2" X 6" VBR. Pull wear bushing. Install test plug and test 3 1/2" X 6" rams to 250 psi low and 3,500 psi high. RID test equipment. Install wear bushing. 18:30 - 21 :00 2.50 DRILL P TIEB1 PJSM. M/U BHA #1 to 1,064'. 21 :00 - 00:00 3.00 DRILL P TIEB1 P/U drill pipe from 1,064' to 5,268'. 8/2/2003 00:00 - 01 :00 1.00 DRILL P TIEB1 RIH with drill pipe from derrick from 5,268' to 7,100'. 01 :00 - 01 :30 0.50 DRILL P TIEB1 Wash down to 7,229'. 01 :30 - 02:30 1.00 EVAL P TIEB1 R/U and pressure test 7" scab liner to 3,500 psi for 30 minutes. Record test. 02:30 - 06:30 4.00 DRILL P TIEB1 Drill cement and float equipment from 7,229' to 7,233'. 06:30 - 07:30 1.00 DRILL P TIEB1 RIH from 7,233' to 8,790' (DPM). Tag EZSV. Set down 30K to verify. 07:30 - 08:00 0.50 EVAL P TIEB1 Test casing to 3,500 psi for 15 minutes. Good test. 08:00 - 10:00 2.00 DRILL P TIEB1 Displace well to 8.4 ppg QuikDril milling fluid at 6112 bpm and 1 ,420 psi. P/U weight 180K, S/O weight 155K, Rot weight 165K. Clean out from under shakers. Pump dry job. 10:00 - 13:00 3.00 DRILL P TIEB1 POOH from 8,790' to 1,064' 13:00 - 14:30 1.50 DRILL P TIEB1 POOH with BHA from 1,064'. Clean out boot baskets; some cement. Clear rig floor. 14:30 - 16:30 2.00 STWHIP P WEXIT P/U BHA components. M/U 7" Whipstock and BHA to 1,123'. Surface test MWD at 105 spm and 700 psi. 16:30 - 21 :30 5.00 STWHIP P WEXIT RIH from 1,123' to 8,686'. 21 :30 - 22:00 0.50 STWHIP P WEXIT Fill pipe. P/U weight165K, SIO weight 160K. Orient whip stock to 61 degrees LHS at 105 spm and 1,430 psi. Tag EZSV at Printed: 8/11/2003 11 :00:05 AM i) ) BP EXPLORATION Operations Summary Report Page 4 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-08 15-08C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/28/2003 Rig Release: 8/10/2003 Rig Number: Spud Date: 9/16/1984 End: 8/10/2003 Date From ..;To Hours Task Code NPT Phase Description of Operations 8/2/2003 21 :30 - 22:00 0.50 STWHIP P WEXIT 8,790'. Set down 20K and set anchor. P/U to 10K overpull to verify. Set down with 35K to shear bolt. 22:00 - 00:00 2.00 STWHIP P WEXIT Mill 7" window from 8,772' to 8,780'. TOW at 8,772' BOW at 8,784'. 8/3/2003 00:00 - 03:00 3.00 STWHIP P WEXIT Mill window in 7" from 8,780' to 8,784'. Pump Bara Lift sweep. Starter mill drilled to 8,798', giving -7 feet of gauge hole below bottom of window. P/U weight 165K, S/O 160K, Rot weight 160K. To~ueoff3K, To~ueon5-6K 03:00 - 04:30 1.50 STWHIP P WEXIT Pump Bara Lift sweep. Work window and CBU at 113 spm and 1,680 psi. At present, only -25 Ibs. shavings recovered. 04:30 - 05:00 0.50 STWHIP P WEXIT Pull into casing. Conduct FIT at 8,784' MD, 8,345' tvd with 8.5 ppg mud and 650 psi (10.0 ppg EMW). 05:00 - 07:30 2.50 STWHIP P WEXIT Pump dry job. Pull out of hole from 8,798' to 1,123'. 07:30 - 09:00 1.50 STWHIP P WEXIT LID BHA. Mills full gauge. Clear rig floor. 09:00 - 10:00 1.00 STWHIP P WEXIT Pull wear bushing. Flush BOPE. Install wear bushing. 10:00 - 11 :00 1.00 DRILL P PROD1 P/U 61/8" drilling BHA to 229'. Surface check MWD. 11 :00 - 13:30 2.50 DRILL P PROD1 RIH with drill pipe from 229' to 8,630'. Fill pipe at 5,835'. 13:30 - 15:00 1.50 DRILL P PROD1 Cut and slip 77' drilling line. Service top drive. 15:00 - 16:00 1.00 DRILL P PROD1 MAD pass from 8,650' to 8,720'. Orient at 60 deg. LHS to slide through window. No problems at window. MAD pass to 8,772'. Tag undergauge hole at 8,789'. 16:00 - 00:00 8.00 DRILL P PROD1 Ream undergauge hole from 8,789' to 8,798'. Directional drill 6 1/8" hole from 8,798' to 8,881'. ART = 0.17 hrs, AST = 3.21 hrs, ADT = 3.38 hrs P/U weight 165K, S/O weight 155K, Rot weight 160K. Slide 83' (8,798' - 8,881') Slide at TF 30 to 60 LHS to initiate LH turn and build Flow rate 275 gpm, on btm 2,000 psi, off btm 1,850 psi. WOB 5 - 25 K Difficult to maintain differential. Drilling off a couple feet at a time, then stacking. Once window was cleared, attempted rotation. Erratic torque. Decided to assess biUBHA condition. POOH. 8/4/2003 00:00 - 03:00 3.00 DRILL P PROD1 Monitor well. Drop dart, pump dry job. POOH with drill pipe from 8,881' to 229'. 03:00 - 04:00 1.00 DRILL P PROD1 Stand back collars. LID MWD and motor. Break bit. Bit in gauge and good condition. Scarring evident on shirttails. Also, on motor housing stabilizer blades. Motor being sent in for assessment. 04:00 - 06:30 2.50 BOPSUR P PROD1 Pull wear bushing, and install test plug. Test BOPE and all related valves to 250 psi low and 3,500 psi high. Witness of test waived by Chuck Scheve of the AOGCC. Pull test plug and install wear bushing. 06:30 - 07:30 1.00 DRILL P PROD1 P/U BHA to 229'. Surface check MWD. Printed: 8/11/2003 11 :00:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP EXPLORATION Operations Summary Report Page 5 of 12 15-08 15-08C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/28/2003 Rig Release: 8/10/2003 Rig Number: Spud Date: 9/16/1984 End: 8/10/2003 Description of Operations Date From.;. To Hours Task Code NPT Phase 8/4/2003 07:30 - 10:00 2.50 DRILL P PROD1 10:00 - 12:00 2.00 DRILL P PROD1 12:00 - 00:00 8/5/2003 00:00 - 19:30 RIH with drill pipe from 229' to 8,881'. Fill pipe at 3,218',6,410'. Orient at 8,723'. No problems sliding through window. Directional drill from 8,881' to 8,941'. ART = 0.0 hrs, AST = 1.14 hrs, ADT = 1.14 hrs PIU weight 165K, S/O weight 155K, Rot weight 160K. Slide 60' (8,881' - 8,941') 12.00 DRILL P Slide at TF 60 LHS to initiate LH turn and build Flow rate 275 gpm, on btm 2,000 psi, off btm 1,800 psi. WOB 15 - 20 K, ROP 40-60 fph PROD1 Directional drill from 8,941' to 9,293'. ART = 5.34 hrs, AST = 3.72 hrs, ADT = 9.06 hrs PIU weight 165K, S/O weight 150K, Rot weight 160K. Slide I Rotate 352' (8,941' - 9,293') Slide at TF 30 to 60 LHS to maintain LH turn and build Flow rate 275 gpm, on btm 2,150 psi, off btm 1,950 psi. WOB 25 - 30 K, ROP 20-30 fph 19.50 DRILL P Rotate at 80 RPM Flow rate 275 gpm, on btm 2,100 psi, off btm 1,950 psi. Torque on btm 4,000; Torque off btm 3,000 WOB 20 -25K, ROP 40 - 60 PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 9,293' to 9,938' WOB Rotating 20,000# - 24,000#, WOB Sliding 15,000# To 20,000#, RPM 80, Motor RPM 92, Torque Off Bottom 4,000 ft I Ibs - On Bottom 6,000 ft I Ibs, Pump Rate 279 gpm, SPP Off Bottom 2,025 psi, On Bottom 2,200 psi. String Weight Up 170,000#, String Weight Down 150,000#, String Weight Rotating 160,000# - ART = 2.67 hrs. - AST = 11.94 Lithologies encountered 8/5/03 9260-9395 (24P) Predominantly massive sand, fine to very coarse grained, abundant chert fragments, poorly sorted, clean and disaggregated. Interval drilled well, averaging 50-60'/hr while sliding to build angle. 9395-9482 (22P) Sand with minor interbedded siltstone, sand is increasingly fine to medium grained, with decreasing amounts of chert fragments. Clean, disaggregated with minor light tan siltstone. As above, the interval drilled quite well, averaging 60'/hr while sliding. 9482-9678 (Zone 1 B) Predominantly fine grained sand, disaggregated, clean and well developed. Interbedded shales and siltstones are poorly developed. Below 9500, there is a notable increase in light brown oil staining in sand, and oil Printed: 8/11/2003 11 :00:05 AM ') ) BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: 15-08 Common Well Name: 15-08C Spud Date: 9/16/1984 Event Name: REENTER+COMPLETE Start: 7/28/2003 End: 8/10/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/10/2003 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/5/2003 00:00 - 19:30 19.50 DRILL P PROD1 fluorescence and cut in samples, suggestive of PGOC. Overall interval drilled well, in excess of 50'/hr while sliding. Thin siltstones yielded a slower ROP of 20'/hr. 9678-9784 (Zone 1A) Predominantly sand and interbedded siltstone. Sands are fine to very fine grained, clean, disaggregated and moderately well sorted, with GR of 50-60 API. Siltstones are light gray, firm, with GR of 100-120. ROP averaging 50'/hr while sliding, 1 OO'lhr while rotating in sands, 15'/hr while sliding in siltstones. 9784-9850 (13P) Upper lobe in objective interval consists of very fine to fine grained, clean sand, with common light brown oil staining, fair fluorescence and cuts, 40-50 API on GR. Minor interbedded siltstone as above. Interval drilled well, 50-1 OO'lhr while sliding and rotating. 9850-9938 (13P) Predominantly siltstone and tightly cemented sands. 13P Siltstone is light gray, carbonaceous and slightly pyritic. GR across interval is 60-90 API. Considerable sand in section is very fine to fine grained, tightly cemented with silica, poorly stained with overall poor porosity. Interval drilled slowly while sliding towards landing target, averaging 15-20'/hr. ROP while rotating was 35-40'/hr. 19:30 - 20:00 0.50 DRILL P PROD1 Take Directional Surveys - Circulate Hole Clean While Rotating And Reciprocating Drill String 20:00 - 20:30 0.50 DRILL P PROD1 Held PJSM - Monitor Well Bore (Static) - POH With BHA NO.6 (Wet) From 9,938' To 8,724' With No Problems 20:30 - 21 :30 1.00 DRILL P PROD1 Drop Dart Open Circulating Sub - Circulate Bottoms Up At 9.5 BPM With 1,100 Psi. - Monitor Well Bore (Static) - Pump Dry Job 21 :30 - 00:00 2.50 DRILL P PROD1 POH With BHA NO.6 From 8,723' To 229' 8/6/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Held PJSM - Handle BHA No.6 - Stand Back BHA - Remove Nukes - Down Load MWDILWD Data - Remove 6 1/8" Bit - Lay Down Sperry Sun Mud Motor - Clear Rig Floor 01 :00 - 03:00 2.00 DRILL P PROD1 Held PJSM - Make Up BHA NO.7 - Pick Up Sperry Sun Motor, Make Up 61/8" Security PDC Bit, Pick Up MWDILWD Tools- Orient And Initialize MWDILWD Tools - Make Up Flex Drill Collars, Dailey Jars, Circ. Sub, And Cross Over Sub - Surface Test Sperry Sun Equipment 03:00 - 03:30 0.50 DRILL P PROD1 RIH With BHA No.7 On 4" Drill Pipe From 198' To 1,008' - Pipe Displacement For Drill String With Solid Float Not Correct - Pump Thru Drill String And RIH With 5 Stands To 1,475' Verify Displacement Calculated 7.6 Barrels Actual Displacement 3.8 Barrels 03:30 - 04:30 1.00 DRILL N DPRB PROD1 POH To Circulating Sub - Pump Thru Circ. Sub Verify Okay - POH To Float Sub - Solid Float Stuck In The Open Position 04:30 - 05:30 1.00 DRILL N DPRB PROD1 Remove Solid Float And Change Out - Orient BHA NO.7 And RIH 05:30 - 06:00 0.50 DRILL N DPRB PROD1 RIH With BHA No.7 On 4" Drill Pipe From 198' To 1,475' - Pipe Displacement For Drill String With Solid Float Correct 06:00 - 09:00 3.00 DRILL P PROD1 RIH With BHA NO.7 On 4" Drill Pipe From 1,475' To 9.938' Printed: 8/11/2003 11 :00:05 AM ) BP EXPLORATION Operations Summary Report Page 7 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-08 15-08C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/28/2003 Rig Release: 8/10/2003 Rig Number: Spud Date: 9/16/1984 End: 8/10/2003 Date From - To Hours Task Code NPT Phase Description of Operations 8/6/2003 06:00 - 09:00 3.00 DRILL P PROD1 With No Problems - Fill Drill String Every 3,000' On Trip In Hole - As Precaution Wash Last Stand To Bottom - Pick Up 18 Joints Of 4" Drill Pipe On Trip - Take Bench Mark Survey At 9,100' (Good) 09:00 - 00:00 15.00 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 9,938' to 10,650' WOB Rotating 5,000# - 10,000#, WOB Sliding 10,000# To 20,000#, RPM 95, Motor RPM 252, Torque Off Bottom 4,000 ft I Ibs - On Bottom 6,000 ft I Ibs, Pump Rate 328 gpm, SPP Off Bottom 2,120 psi, On Bottom 2,680 psi. String Weight Up 175,000#, String Weight Down 145,000#, String Weight Rotating 165,000# - ART = 3.91 hrs. - AST = 2.76 hrs. Lithologies Encountered 8/6/03 9938-9950 Predominantly siltstone and tightly cemented sands. 13PSiltstone is light gray, carbonaceous and slightly pyritic. GR across interval is 60-90 API. Considerable sand in section is very fine to fine grained, tightly cemented with silica, commonly v silty and poorly stained with overall poor porosity. Rotated interval following bit trip, averaging160'/hr. 9950-10400 (13P) Lower Objective Section (?) Interbedded sand and siltstones/shales. Sands are very fine to fine grained, commonly very clean and disaggregated, locally very shaley and silty, carbonaceous in part, well sorted overall with uniform light brown oil staining, and overall good oil shows by cut and flu. Interbedded siltstones are medium brown to light gray, locally sandy, firm to hard, with common black carbonaceous laminations. GR in sand ranges from 60-45 API, averaging 50-55 API, while siltstones range from 70-110 API. Overall, interval appears shalierlsiltier than anticipated, suggestive of a marginally developed 13P interval, or thicker 12P interval. Difficulty encountered while sliding in maintaining toolface, resulting in low RaP's of 20-50'/hr, regardless of lithology encountered. While rotating, Rap averaged 150-200'/hr in sands and siltstones. 10400-10650 (12N) Predominantly siltstone and sand, with common shale. Siltstones are light to medium gray, firm, sandy, with common carbonaceous laminations. GR indicating 70-110 API, interbedded sands are generally consolidated, commonly tightly cemented and silty to shaley, very fine to fine grained and locally carbonaceous. Associated shales are black, platey and carbonaceous, grading to coal. Persistent problems with trying to slide in this interval while trying to invert well and climb in the section to reenter overlying sands, yielding erratic RaP's of 10-30'/hr. High RaP's encountered while rotating. Indications of 1.5 deg apparent dip, sliding to maintain 92+ deg inclination. 8/7/2003 00:00 - 11 :30 11.50 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 10,650' to 11,552' WOB Rotating 5,000# - 10,000#, WOB Printed: 8/11/2003 11:00:05AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP EXPLORATION Operations Summary Report Page 8 of 12 15-08 15-08C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/28/2003 Rig Release: 8/10/2003 Rig Number: Spud Date: 9/16/1984 End: 8/10/2003 Description 'of Operations 8/7/2003 00:00 - 11 :30 From - To Hours Task Code NPT Phase 11.50 DRILL P PROD1 Sliding 10,000# To 20,000#, RPM 105, Motor RPM 249, Torque Off Bottom 4,000 ft I Ibs - On Bottom 6,000 ft I Ibs, Pump Rate 323 gpm, SPP Off Bottom 2,410 psi, On Bottom 2,810 psi. String Weight Up 175,000#, String Weight Down 135,000#, String Weight Rotating 165,000# - ART = 4.38 hrs. - AST = 2.19 hrs. Sticking on slides and some problem getting back to bottom I must use beaded pills and keep pipe moving to achieve slides. Sliding at 35 feet per hour but a lot of time spent off bottom with sticky hole. Date Lithologies Encountered 8/7/03 10650-10715 - 12N Predominantly siltstone and sand, with common shale. Siltstones are light to medium gray, firm, sandy, with common carbonaceous laminations. GR indicating 70-110 API, interbedded sands are generally consolidated, commonly tightly cemented and silty to shaley, very fine to fine grained and locally carbonaceous. Associated shales are black, platey and carbonaceous, grading to coal. Persistent problems with trying to slide in this interval while trying to invert well and climb in the section to reenter overlying sands, yielding erratic RaP's of 10-30'/hr. High RaP's encountered while rotating to work in beaded sweeps. Indications of 1.5 deg apparent dip, sliding to maintain 92+ deg inclination. 10715-10965 - 13P Lower Objective Interbedded Sands and siltstones. Sands are very fine to fine grained, locally very clean, overall slightly to very silty, shaley, commonly consolidated, friable, slightly carbonaceous, well sorted with good light brown oil staining and fair to good oil flu/cuts. GR averaging 50-70 API, indicative of a ratty, overall poor reservoir. Siltstones are light to medium gray, slightly sandy, commonly carbonaceous. Rotated throughout most of the interval, with RaP's of 150-200'/hr. One slide to knock down inclination yielded ROP's of 30-50'/hr. 10965-11430 - 13P Upper zone: Predominantly clean, disaggregated, very-fine grained sand, with minor silty beds. Well sorted, with good porosity and oil staining. GR averages 45-60 API units overall, with several thin silty zones indicated with 60-70 API. RaP's averaged 180-220 ft/hr while rotating (most of interval), with several short slides yielding slower RaP's as above. Overall, a good productive interval. 11400-11470 - Uppermost 13P sands and proximal13N silts/shales. Very-fine grained sand, increasing silt. Sand becoming more indurated, tightly cemented. Poor reservoir quality indicated by GR increase above 100 API. No noticeable effect on Rap, averaging 200'/hr while rotating. 11470-11552 - 13P sand Very fine grained, clean and disaggregated. GR 55-60 API, Rap in excess of 200'/hr while rotating. Printed: 8/11/2003 11 :00:05 AM ) ) BP EXPLORATION Operations Summary Report Page 9 of 1.2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-08 15-08C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/28/2003 Rig Release: 8/10/2003 Rig Number: Spud Date: 9/16/1984 End: 8/10/2003 Date From '- To Hours Task Code NPT Phase Description of Operations 8/7/2003 00:00 - 11 :30 11.50 DRILL P PROD1 11 :30 - 13:00 1.50 DRILL P PROD1 Circulate Hi-Vis Sweep While Rotating And Reciprocating Drill String - 7.5 BPM With 2,370 Psi. 13:00 - 14:30 1.50 DRILL P PROD1 Held PJSM - Monitor Well Bore (Static) For Wiper Trip - POH Wet From 11,552' To 9,902' With No Hole Problems - RIH From 9,902' To 11,493' With No Hole Problems - As Precaution Wash Last Stand From 11,493' To 11,552' - No Fill On Bottom 14:30 - 16:00 1.50 DRILL P PROD1 Circulate Hi-Vis Sweep While Rotating And Reciprocating Drill String - 7.5 BPM With 2,325 Psi. - Spot Liner Running Pill In Open Hole Section 16:00 - 18:30 2.50 DRILL P PROD1 Held PJSM - Monitor Well Bore (Static) - POH Laying Down Excess 4" Drill Pipe (87 Joints) From 11,552' To 8,700' With No Hole Problems 18:30 - 19:30 1.00 DRILL P PROD1 Monitor Well Bore At Window - Drop Dart Shear Open Circulating Sub - Circulate Bottoms Up At 11.5 BPM With 1,450 Psi. - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive 19:30 - 22:30 3.00 DRILL P PROD1 POH With BHA No.7 From 8,700' To 198' 22:30 - 23:30 1.00 DRILL P PROD1 Held PJSM - Lay Down Directional BHA NO.7 - Down Load MWDILWD Data In Pipe Shed - Remove 61/8" Bit - Lay Down Sperry Sun Mud Motor - Wash Off And Clear Rig Floor 23:30 - 00:00 0.50 CASE P COMP Held PJSM - Rig Up Casing Tools And Equipment 8/8/2003 00:00 - 03:15 3.25 CASE P COMP Held PJSM - Run 4 1/2" Liner - Pick Up Shoe Track And Bakerlock - Verifiy Floats Working - Pick Up 70 Joints Of 4 1/2" (IBT-M) L-80 12.6# Liner - Make Up To Diamond Torque To 3,900 ftjlbs 03: 15 - 03:45 0.50 CASE P COMP Held PJSM - Changed out to 4" DP Elevators - M I U Baker HMC Liner Hanger, ZXP Packer, Liner Tie Back Sleeve, And Running Tool- Make Up Liner Wiping Plug - PI U (1) 4" Drill Pipe Pup Joint, RIH wI 1 Stand 4" Drill Pipe From Mast 03:45 - 04:00 0.25 CASE P COMP Circulated 4 1/2" Liner Volume At 5 BPM With 150 Psi. - Recorded Liner Weight When Full Of Mud At 36,000 Ibs. 04:00 - 06:30 2.50 CASE P COMP Held PJSM - RIH w/4 1/2" 12.6# Liner On 4" Drill Pipe From 3,066' To 8,732' 06:30 - 07:00 0.50 CASE P COMP Circulate Liner And Drill Pipe Volume At 5 BPM With 620 Psi. 07:00 - 09:00 2.00 CASE P COMP RIH w/4 1/2" 12.6# Liner On 4" Drill Pipe From 8,732' To 11,530' With No Problems - Pick Up And Make Up Baker Cementing Head - Install Circulating Manifold And Hoses - Establish Circulation - Up Weight At 170,000#, Down Weight At 150,000# - Tag Bottom At 11,552' With No Fill 09:00 - 11 :00 2.00 CASE P COMP Circulate And Condition Mud - Reciprocate 4 1/2" Liner - Stage Up Pump Rate To 6 BPM With 1,040 Psi. - Hold PJSM Regarding Cementing Operation - Batch Mix 15.8 PPG Cement 11 :00 - 13:30 2.50 CEMT P COMP Shut Down And Turn Over To Dowell- Reciprocate 41/2" Liner - Flood Surface Lines With Water - Test Surface Lines And Equipment To 4,500 Psi. (Test Good) - Clear Lines With CW-100 Prior To Going Down Hole - Pump 15 BBLS CW-100 Followed With 25 BBLS Of 9.5 PPG Mud Push And 75 BBS (350 Sacks) 15.8 PPG Class "G" Tail Cement At 4.7 BPM - Wash Up Cement Lines To Floor With Perf Pill- Drop Dart And Displace With 76 BBLS Perf Pill And 50.4 BBLS Of 8.6 PPG QUIKDRILn Mud At 5.0 BPM - Slow Rate And Latch Liner Printed: 8/11/2003 11 :00:05 AM ') ") BP EXPLORATION, Operations Summary Report Page 10 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 5-08 15-08C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/28/2003 Rig Release: 8/10/2003 Rig Number: Spud Date: 9/16/1984 End: 8/10/2003 Date From - To Hours Task Code NPT Phase Description of Operations 8/8/2003 11:00-13:30 2.50 CEMT P CaMP Wiper Plug With 85.9 BBLS Pumped Away - Increase Rate To 5.0 BPM Continue To Displace - Slow Rate To 3.1 BPM With Final Circulating Pressure At 1474 Psi. - Bump Liner Plug With A Total Of 126.4 BBLS Pumped - Cement In Place At 12:50 Hours - Pressure Up To 3,500 Psi. To Set Liner Hanger - Bleed Pressure Off And Check Floats (OK) - Rotate 20 Turns To The Right And Release From Liner - Swap Over To Rig Pumps And Pressure Up To 1,000 Psi. - Pick Up To Release Pack Off From Seals And Expose Running Tool Dogs As Pressure Decreases Ramp Up Pumps To Maximum Rate And Circulate Cement Up Hole 30 BBLS - Reduce Pump Rate Slack Off String With 50,000 Ibs. To Set Baker ZXP Packer Rotate And Repeat Process - Increase Pump Rate And Continue To Circulate Out 20 BBLS Cement To Surface. TaL 8599', Landing collar at 11463', Float Collar at 11506', Float Shoe at 11549' 13:30 - 14:30 1.00 CASE P CaMP Held PJSM - Displace Well To 8.6 PPG Sea Water At 11.5 BPM With 2,550 Psi. 14:30 - 15:00 0.50 CASE P CaMP Held PJSM - Break Down Circulating Lines And Lay Down Baker Cementing Head 15:00 - 16:00 1.00 CASE P CaMP Held PJSM - Slip And Cut 95 Feet Of 1 1/4" Drilling Line - Clean Out Possom Belly And Under Shakers 16:00 - 17:00 1.00 CASE P CaMP Held PJSM - Service Top Drive, Traveling Blocks, And Crown Sheaves 17:00 - 20:00 3.00 CASE P CaMP Held PJSM - POH With Baker 4 1/2" Liner Running Tool From 8,600' To 34' - Service Baker Running Tool And Lay Down - Clear Rig Floor 20:00 - 21 :00 1.00 CASE P CaMP Held PJSM - Verify Compressive Strength Of Cement Above 500 Psi. - Test 4 1/2" Liner X 7" Liner X 95/8" Casing At 3,500 Psi. For 30 Minutes Test Good - Hold Pre-Job Safety Meeting Regarding Peforation Gun Handling Operation During This Phase 20:30 - 23:00 2.50 PERF P CaMP Pick Up 1,490' Of 2 1/2" Millennium Guns - 1,070' Charges Loaded With 4 SPF At 60 Degree Phase - Make Up Firing Head And Cross Overs 23:00 - 23:30 0.50 PERF P CaMP Held PJSM - Rig Up 2 7/8" Handling Tools, Power Tongs And Equipment 23:30 - 00:00 0.50 PERF P CaMP Held PJSM - Pick Up 2 7/8" Pac Drill Pipe 8/9/2003 00:00 - 01 :30 1.50 PERF P CaMP RIH With 2 1/2" Millennium Guns Picking Up 45 Joints Of 2 7/8" Pac Drill Pipe 01 :30 - 02:00 0.50 PERF P CaMP Rig Down 2 7/8" Handling Tools, Power Tongs And Equipment 02:00 - 05:00 3.00 PERF P CaMP Install Cross Overs - RIH With 2 1/2" Millennium Guns On 4" HT-40 Drill Pipe From 2,898' To 11,463' (Top Of Landing Collar) 05:00 - 05:30 0.50 PERF P CaMP Place Perf Guns On Depth wI Bottom Shot At 11430, Top Shot At 9940', Spaced Out Throughout The Interval wI 1070' Of Loaded Guns At 4 SPF, 60 Degree Phasing- Close Upper Pipe Rams - Pressure Up To 2,500 Psi. And Fire Perf Guns - Bleed Pressure To 0 Psi. - Open Upper Rams 05:30 - 06:30 1.00 PERF P CaMP POH With Perf Guns Above Top Shot At 9,940' - From 11,430' To 9,902' 06:30 - 07:00 0.50 PERF P CaMP Monitor Well Bore Static Loss Rate At 4 BPH - Pump Dry Job - Blow Down Top Drive Printed: 8/11/2003 11 :00:05 AM ") ) BP EXPLORATION Operations Summary Report Page 11 of 12 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-08 15-08C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/28/2003 Rig Release: 8/10/2003 Rig Number: Spud Date: 9/16/1984 End: 8/10/2003 Date From - To Hours Task Code NPT Phase Description of Operations 8/9/2003 07:00 - 08:00 1.00 PERF P COMP POH With Haliburton 2 1/2" Perf Guns From 9,902' To 7,753' 08:00 - 11 :00 3.00 PERF P COMP POH Laying Down 4" Drill Pipe From 7,753' To 2,898' 11 :00 - 12:00 1.00 PERF P COMP Rig Up 2 7/8" Handling Tools, Power Tongs And Equipment 12:00 - 13:30 1.50 PERF P COMP Lay Down 2 7/8" Pac Drill Pipe From 2,898' To 1,517' 13:30 - 14:00 0.50 PERF P COMP Rig Up 2 3/8" Handling Tools And Equipment 14:00 - 16:30 2.50 PERF P COMP POH Laying Down Haliburton 2 1/2" Millennium Guns All Charges Fired 16:30 - 17:00 0.50 PERF P COMP Wash Off And Clear Rig Floor 17:00 - 17:30 0.50 BOPSUR P COMP Rig Up And Pull Wear Bushing 17:30 - 19:00 1.50 RUNCOIVP COMP Rig Up 4 1/2" Chrome Tubing Handling Tools, Power Tongs And Equipment 19:00 - 19:30 0.50 RUNCOIVP COMP Hold Pre-Job Safety Meeting Regarding Chrome Tubing Running Operation 19:30 - 00:00 4.50 RUNCOIVP COMP Run 4 1/2" Completion - Pick Up Tail Pipe Assembly Baker Lock Connections Below Baker S -3 Packer - RIH With 41/2" (83 Joints) 13 CR80 12.6 lb. Vam Ace Tubing To 3,604' -Torque To 3,620 ftllbs. 8/10/2003 00:00 - 05:30 5.50 RUNCOIVP COMP Run 41/2" Completion - RIH With 41/2" (204 Joints) 13 CR80 12.6 lb. Vam Ace Tubing From 3,604' To 8,607' Tagged Bottom Of 4 1/2" Liner Tie Back Sleeve -Torque To 3,620 ftllbs. 05:30 - 06:30 1.00 RUNCOIVP COMP Space Out 4 1/2" Completion String - Lay Down 3 Joints Of 4 1/2" Tubing - Pick Up 3 Space Out Pup Joints - Pick Up Joint NO.202 - Make Up FMC Tubing Hanger - Up Weight At 120,000 Ibs. Down Weight At 118,000 Ibs. - Top Of Liner Tie Back Sleeve At 8,599' - Wire Line Entry Guide At 8,602' 06:30 - 07:30 1.00 RUNCOIVP COMP Land FMC Tubing Hanger - Run In Lock Down Studs 07:30 - 10:00 2.50 RUNCOIVP COMP Reverse Circulate Sea Water And Corrossion Inhibitor At 3 BPM With 360 Psi. 10:00 - 11 :30 1.50 RUNCOIVP COMP Drop Ball And Rod - Pressure Up On The Tubing To 3500 Psi To Set The Packer - Hold The Pressure For 30 Minutes On Chart Recorder For Tubing Test - Bleed The Pressure To 1500 Psi. - Pressure Annulus To 3500 Psi For 30 Mininutes For Packer Test On The Chart Recorder - Bleed Off The Tubing Pressure To Shear The DCK Valve Set At 2500 Psi. 11:30 -12:00 0.50 BOPSUR P COMP Install Two Way Check Valve - Test From Below To 1,000 Psi. (Good Test) 12:00 - 12:30 0.50 BOPSUR P COMP Blow Down Surface Lines And Equipment 12:30 - 13:30 1.00 BOPSURP COMP Nipple Down 13 5/8 BOP Stack And Related Equipment 13:30 - 15:00 1.50 WHSUR P COMP Nipple Up Tubing Head Adapter And Production Tree 15:00 - 15:30 0.50 WHSUR P COMP Test Tubing Head Adapter And Tree To 5,000 Psi. (Good Test) 15:30 - 16:00 0.50 WHSUR P COMP Rig Up DSM Lubricator And Pull Two Way Check Valve 16:00 - 17:30 1.50 WHSUR N WAIT COMP Cleaning rig floor and pipeshed while Wait On Little Red Hot Oil Services due to other job commitment. 17:30 - 18:30 1.00 WHSUR P COMP Test Surface Lines At 3,500 Psi. (Test Good) - Reverse Circulate 155 BBLS Diesel Freeze Protection Down Inner Annulus At 3 BPM With 2,250 Psi. 18:30 - 20:00 1.50 WHSUR P COMP U Tube Diesel Into Tubing 20:00 - 20:30 0.50 WHSUR P COMP Held PJSM - Install BPV - Test From Below To 1,000 Psi (Test Good) 20:30 - 21 :30 1.00 WHSUR P COMP Break Down Surface Equipment - Remove Secondary Annulus Valve - Install Tree Cap And Gauges - Secure Well Rig Released From Well Work On DS 15-08C At 21 :30 Hours Printed: 8/11/2003 11 :00:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) BP EXPLORATION Operations Summary Report 15-08 15-08C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/28/2003 Rig Release: 8/10/2003 Rig Number: From - To Hours Task Code NPT Phase CaMP On 08/10/2003 8/10/2003 20:30 - 21 :30 1.00 WHSUR P ') Page 12 of 12 Spud Date: 9/16/1984 End: 8/10/2003 Description of Operations Printed: 811112003 11 :00:05 AM ) ) 24-Aug-03 fj03-/t) \ AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-08C Dear Dear Sir/Madam: Enclosed are two survey hard copies and a disk with the *.PTT and *.PDF files. Tie-on Survey: 8,761.90' MD Window / Kickoff Survey: 8,772.00' MD (if applicable) Projected Survey: 11,552.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachme nt( s) RECEIVED AUG 29 2003 ~~bVY\~ Alaska œ & Gas Com~. Gcmmi~"ion Anchorcue Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 15 15-0BC '-- Job No. AKMW0002589887, Surveyed: 7 August, 2003 Survey Report 22 August, 2003 Your Ref: API 500292118003 Surface Coordinates: 5959869.01 N, 677321.27 E (70017' 45.1435" N, 148033' 50.6593" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -' Surface Coordinates relative to Project H Reference: 959869.01 N, 177321.27 E (Grid) Surface Coordinates relative to Structure Reference: 1007.10 N, 1047.36 E (True) Kelly Bushing: 57. 99ft above Mean Sea Level Elevation relative to Project V Reference: 57.99ft Elevation relative to Structure Reference: 57. 99ft 5ru=='I'I'V-5U1! DAft..:. LI NG--'S-e Pi\/' I c:efs A Halliburton Company Survey Ref: svy4087 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 -15-08C Your Ref: API 500292118003 Job No. AKMW0002589887, Surveyed: 7 August, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8761.90 38.380 28.660 8273.43 8331.42 1204.78 N 781.38 E 5961091.89 N 678074.01 E 175.85 Tie On Point 8772.00 38.480 28.760 8281.34 8339.33 1210.29 N 784.40 E 5961097.47 N 678076.89 E 1.166 177.07 Window Point 8809.26 40.870 25.050 8310.02 8368.01 1231.50 N 795.14 E 5961118.93 N 678087.13 E 9.029 182.48 8837.66 42.680 22.490 8331.20 8389.19 1248.81 N 802.76 E 5961136.41 N 678094.34 E 8.756 187.77 8869.75 44.250 19.840 8354.49 8412.48 1269.40 N 810.72 E 5961157.18N 678101.81 E 7.496 194.91 .~ 8903.49 47.840 17.290 8377.91 8435.90 1292.42 N 818.43 E 5961180.38 N 678108.98 E 11.949 203.80 8934.83 51 .740 15.100 8398.14 8456.13 1315.40 N 825.09 E 5961203.51 N 678115.10 E 13.539 213.47 8961.33 53.390 13.370 8414.25 8472.24 1335.80 N 830.26 E 5961224.02 N 678119.79 E 8.101 222.61 9009.74 53.970 13.170 8442.92 8500.91 1373.76 N 839.22 E 5961262.19 N 678127.84 E 1.243 240.16 9055.49 54.480 12.080 8469.67 8527.66 1409.98 N 847.33 E 5961298.59 N 678135.10 E 2.231 257.23 9147.11 52.340 5.630 8524.32 8582.31 1482.59 N 858.70 E 5961371.44 N 678144.75 E 6.114 295.19 9182.58 52.020 3.940 8546.07 8604.06 1510.51 N 861.04 E 5961399.41 N 678146.43 E 3.870 311.34 9212.55 53.500 2.830 8564.20 8622.19 1534.32 N 862.44 E 5961423.25 N 678147.27 E 5.751 325.57 9241.25 54.470 2.300 8581.08 8639.07 1557.51 N 863.48 E 5961446.46 N 678147.76 E 3.695 339.69 9272.67 55.030 1.020 8599.21 8657.20 1583.16 N 864.22 E 5961472.12 N 678147.90 E 3.774 355.60 9303.91 56.820 357.510 8616.72 8674.71 1609.03 N 863.88 E 5961497.97 N 678146.95 E 10.928 372.49 9334.39 59.860 353.700 8632.72 8690.71 1634.88 N 861.88 E 5961523.77 N 678144.34 E 14.581 390.64 9366.10 63.560 349.030 8647.75 8705.74 1662.47 N 857.67 E 5961551.25 N 678139.48 E 17.441 411.60 9399.54 66.680 344.670 8661 .82 8719.81 1692.00 N 850.76 E 5961580.61 N 678131.87 E 15.063 435.87 9427.48 68.590 340.450 8672.46 8730.45 1716.64 N 843.01 E 5961605.06 N 678123.55 E 15.550 457.65 9461.89 70.160 335.680 8684.59 8742.58 1746.49 N 830.98 E 5961634.62 N 678110.81 E 13.752 486.06 9492.79 70.650 331.690 8694.95 8752.94 1772.58 N 818.08 E 5961660.40 N 678097.30 E 12.267 512.71 9522.55 71.960 327.990 8704.49 8762.48 1796.95 N 803.91 E 5961684.42 N 678082.57 E 12.572 539.22 -" 9556.27 73.960 325.200 8714.38 8772.37 1823.85 N 786.16 E 5961710.90 N 678064.19 E 9.887 570.11 9587.47 76.990 322.140 8722.20 8780.19 1848.18 N 768.27 E 5961734.80 N 678045.72 E 13.580 599.46 9616.36 80.170 320.800 8727.92 8785.91 1870.32 N 750.63 E 5961756.52 N 678027.57 E 11.909 627.20 9648.58 85.090 319.450 8732.05 8790.04 1894.84 N 730.15 E 5961780.55 N 678006.51 E 15.825 658.65 9679.66 88.770 316.160 8733.72 8791.71 1917.82 N 709.31 E 5961803.03 N 677985.14 E 15.871 689.39 9709.18 88.950 314.680 8734.31 8792.30 1938.84 N 688. 60 E 5961823.56 N 677963.93 E 5.050 718.77 9743.40 86.570 312.520 8735.64 8793.63 1962.42 N 663.84 E 5961846.55 N 677938.62 E 9.389 752.89 9774.26 85.000 309.820 8737.91 8795.90 1982.68 N 640.67 E 5961866.25 N 677914.99 E 10.100 783.66 9801.35 84.130 308.410 8740.48 8798.47 1999.69 N 619.75 E 5961882.77 N 677893.67 E 6.096 810.62 9836.70 84.190 307.240 8744.08 8802.07 2021.26 N 591.97 E 5961903.67 N 677865.39 E 3.297 845.76 9867.67 84.650 311 .150 8747.09 8805.08 2040.73 N 568.09 E 5961922.58 N 677841.06 E 12.653 876.58 9896.27 86.880 312.010 8749.20 8807.19 2059.66 N 546.76 E 5961941.00 N 677819.28 E 8.354 905.09 22 August, 2003 - 11:08 Page2of4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 -15-08C Your Ref: API 500292118003 Job No. AKMW0002589887, Surveyed: 7 August, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (It) (It) (It) (It) (It) (It) (It) (O/1001t) 9947.43 88.420 309.080 8751.30 8809.29 2092.89 N 507.92 E 5961973.30 N 677779.67 E 6.466 956.19 9983.12 88.240 304.930 8752.34 8810.33 2114.35 N 479.43 E 5961994.09 N 677750.69 E 11 .634 991.81 1 0042.17 88.330 303.990 8754.11 8812.10 2147.75 N 430.77 E 5962026.33 N 677701.25 E 1.598 1050.56 10091.40 87.900 304.900 8755.73 8813.72 2175.58 N 390.19 E 5962053.19 N 677660.03 E 2.044 1099.53 10135.66 87.690 305.370 8757.43 8815.42 2201.03 N 354.02 E 5962077.78 N 677623.27 E 1.162 1143.60 ~ 10182.47 90.930 306.960 8757.99 8815.98 2228.65 N 316.24 E 5962104.50 N 677584.85 E 7.710 1190.29 10229.16 91.050 306.280 8757.18 8815.17 2256.50 N 278.77 E 5962131.46 N 677546.73 E 1.479 1236.89 10294.76 89.230 307.610 8757.02 8815.01 2295.92 N 226.35 E 5962169.63 N 677493.39 E 3.436 1302.40 10325.45 89.410 307.830 8757.39 8815.38 2314.70 N 202.08 E 5962187.83 N 677468.68 E 0.926 1333.06 10356.74 89.880 306.910 8757.58 8815.57 2333.69 N 177.21 E 5962206.23 N 677443.37 E 3.302 1364.32 10415.71 89.260 305.780 8758.03 8816.02 2368.64 N 129.71 E 5962240.05 N 677395.07 E 2.186 1423.16 10448.77 88.770 304.730 8758.59 8816.58 2387.71 N 102.72 E 5962258.48 N 677367.63 E 3.504 1456.10 10479.70 89.910 305.160 8758.95 8816.94 2405.43 N 77.37 E 5962275.60 N 677341.87 E 3.939 1486.91 1 0507.87 90.800 304.130 8758.78 8816.77 2421.44 N 54.20 E 5962291.06 N 677318.32 E 4.832 1514.96 10541.79 91.730 307.900 8758:03 8816.02 2441.38 N 26.77 E 5962310.34 N 677290.44 E 11 .445 1548.78 10601.35 91.670 310.110 8756.26 8814.25 2478.85 N 19.49 W 5962346.71 N 677243.30 E 3.710 1608.30 10650.57 92.350 311.490 8754.53 8812.52 2510.99 N 56.72 W 5962377.96 N 677205.32 E 3.124 1657.48 10695.22 94.320 311.750 8751.94 8809.93 2540.59 N 90.05 W 5962406.77 N 677171.31 E 4.450 1702.04 10730.86 94.320 311.260 8749.25 8807.24 2564.14 N 116.66 W 5962429.69 N 677144.15 E 1.371 1737.57 10789.97 93.980 313.180 8744.97 8802.96 2603.76 N 160.32 W 5962468.26 N 677099.57 E 3.290 1796.47 10838.45 92.960 313.440 8742.04 8800.03 2636.95 N 195.53 W 5962500.61 N 677063.58 E 2.171 1844.78 10886.78 91 .940 313.510 8739.97 8797.96 2670.17 N 230.57 W 5962533.00 N 677027.77 E 2.115 1892.98 10930.55 91.640 313.090 8738.61 8796.60 2700.18 N 262.41 W 5962562.24 N 676995.23 E 1.179 1936.66 '--- 10977.44 92.220 314.300 8737.03 8795.02 2732.55 N 296.29 W 5962593.81 N 676960.59 E 2.860 1983.42 11025.10 92.960 312.430 8734.87 8792.86 2765.24 N 330.90 W 5962625.67 N 676925.22 E 4.216 2030.95 11070.83 92.930 315.450 8732.52 8790.51 2796.93 N 363.78 W 5962656.58 N 676891.60 E 6.596 2076.50 11116.80 92.620 316.000 8730.30 8788.29 2829.80 N 395.84 W 5962688.69 N 676858.78 E 1.372 2122.19 11164.33 92.470 314.860 8728.19 8786.18 2863.63 N 429.16 W 5962721.72 N 676824.67 E 2.417 2169.46 11226.84 91.200 317.510 8726.18 8784.17 2908.71 N 472.41 W 5962765.76 N 676780.37 E 4.699 2231.57 11259.27 90.680 317.130 8725.65 8783.64 2932.54 N 494.39 W 5962789.07 N 676757.83 E 1.986 2263.73 11352.39 90.680 317.480 8724.55 8782.54 3000.98 N 557.53 W 5962856.00 N 676693.09 E 0.376 2356.09 11448.26 90.060 313.960 8723.93 8781.92 3069.60 N 624.45 W 5962923.03 N 676624.57 E 3.728 2451.46 11501 .88 90.250 315.640 8723.78 8781.77 3107.39 N 662.50 W 5962959.90 N 676585.65 E 3.153 2504.89 11552.00 90.250 315.640 8723.56 8781.55 3143.22 N 697.54 W 5962994.90 N 676549.77 E 0.000 2554.77 Projected Survey 22 August, 2003 - 11:08 Page 3 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-08C Your Ref: API 500292118003 Job No. AKMW0002589887, Surveyed: 7 August, 2003 BPXA North Slope Alaska All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 310.000° (True). Magnetic Declination at Surface is 25.8400(01-Aug-03) ---' Based upon Minimum Curvature type calculations, at a Measured Depth of 11552.00ft., The Bottom Hole Displacement is 3219.69ft., in the Direction of 347.488° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8761.90 8772.00 11552.00 8331.42 8339.33 8781.55 1204.78 N 1210.29 N 3143.22 N 781.38 E 784.40 E 697.54 W Tie On Point Window Point Projected Survey Survey tool program for 15-0BC From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) , ~ - 0.00 7398.00 0.00 7398.00 7158.13 11552.00 7158.13 BP High Accuracy Gyro (15-08) 8781.55 MWD Magnetic (15-08APB 1) 22 August, 2003 - 11:08 Page 4 of 4 DrillQuest 3.03.02.005 ~ (l.)) ) VŒ ([~ fÆ~!Æ~lß!Æ / AI/ASIiA. OIL AND GAS / CONSERVATION COMMISSION ' ) FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit, 15-08C BP Exploration (Alaska) Inc. Permit No: 203-121 Surface Location: 1645' SNL, 1378' EWL, SEC. 22, TI1N, RI4E, UM Bottomhole Location: 1450' NSL, 736' EWL, SEC. 15, TI1N, RI4E, UM Dear Mr. Crane: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you ITom obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). S incerel y, tc.-~ ~~ Randy Ruedrich Commissioner BY ORDER OF THE COM:M:ISSION DATED tbis~ day of July, 2003 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section v.J 41\- 1{ ~/¿,o0"5 1 a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at su rface . x = 677321, Y = 5959869' 7. 1645' SNL, 1378' EWL, SEC. 22, T11 N, R14E, UM . At top of productive interval . x = 677925, Y = 5961838 310' NSL, 2032' EWL, SEC. 15, T11N, R14E, UM . At total depth . x = 676600, Y = 5962947 1450' NSL, 736' EWL, SEC. 15, T11 N, R14E, UM . ) STATE OF ALASKA J ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 58' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028306 ./ Unit or Property Name Prudhoe Bay Unit 8. Well Number /. 15-08C 9. Approximate spud datjr 07/26/03 / Amount $200,000.00 14. Number of acres in property 15. P~osed depth (MD and TVD) 2560 . 11530' M 0 187781 TVD . o 17. Anticipated pressure {s~'20 AAC 25.035 (e) (2)} . 92 Maximum surface 2450 psig, At total depth (TV D) 8500' I 3300 psig Setting Depth Top Bottom Lenath MD TVD MD TVD 4760' 2500' 2500' 7260' 7072' 2580' 8950' 8480' 11530' 8778' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance tOllearest well ADL 028303, 3830' MD 15-39 is 268' away at 11087' MD 16. To be completed for deviated wells Kick Off Depth 91001 MD .,- Maximum Hole Angle 18. CaSing;~~gram Specifications Hole CasinQ Weight Grade Couolina NIA 7" 26# L-80 BTC 6-1/8" 4-1/2" 12.6# L-80 IBT Quantity of Cement (include staae data) 287 sx Class 'G', 216 sx Class 'G' /' 312 sx Class 'G' ~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12628 feet Plugs (measured) true vertical 8772 feet Effective depth: measured 12628 feet Junk (measured) true vertical 8772 feet Casing Length Size Cemented R·" [':: ('~~ E~,·, , 1\",,,,,, 'it"...ðfJ I ,,,""'''' JUL {} 2 2003 Ai~s~{~~ o¡¡ g~ ð'\ ¡1J di Ii] m i~1 ~ MD TVD Structural Conductor Surface Intermediate Production Liner Liner Liner 90' 20" 2539' 13-3/8" 7448' 9-5/8" 2555' 7" 957' 4-1/2" 1982' 2-3/8" 370 sx Permafrost II 1938 sx PF 'E', 400 sx PF 'C' 500 sx Class 'G', 300 sx PF 'C' 90' 2539' 7448' 90' 2539' 7194' 534 sx Class 'G' Uncemented Slotted Liner Uncemented Slotted Liner 7271' - 9825' 9768' - 10725' 10494' - 12476' 7079' - 8796' 8794' - 8761' 8766' - 8769' Perforation depth: measured Perf'd & Slotted: 9854' - 12438' true vertical Perf'd & Slotted: 8796' - 8767' 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foreØ6ing is true and correct to the best of my knowledge Signed Lowell ~rane, ~ ~ ...... '. ,. ,-¿:itle.. s~n¡~r Drilling E~.~ineer..:... ", Date '7- Z - 03 . J . I" , i '.... ¡. ,(, ;I{,', Commi.-QŒ·Uø:'Qnl¥,' 'I". I " 'Y" ':i:.\:;'i::~· '(>:1<::,"<' '>',),: Permit Number,. API Number ApP'r~v,1 Date See cover letter ;LO"3 -I 2 I 50- 029-21180-03 7 ! ¥ _d? for other reauirements Conditions of Approval: Samples Required q ~s Ja'Ño Mud Log Required 0 Yes )$(No Hydrogen Sulfide Measures ..HYes '0 No Directional Survey Required ..2"Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other:T-es t- 80 PE to ~ÇDO fU" Æ . /.. R /_ by order of Approved By '.¡:::::-) /~L-~ Rn~s'o\e' A I the commission Form 10-401 Rev. 12-01-85 U t\ lJ \ L Date {[£¡pi icate ) ) I Well Name: I DS 15-08C Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 2A Bottom Hole Location: x = 677,321.3 Y = 5,959,869.0 16451 FNL, 1378' FWL /' Sec. 22, T11 N, R14E Umiat ¿ X = 677,925 Y = 5,961,838' TVDss 8745' 4970' FNL, 2032' FWL /' Sec. 15, T11 N, R14E Umiat - X = 676,600 Y = 5,962,947 TVDss 8720' 38301 FNL, 736' FWL /Sec. 15, T11N, R14E Umiat I AFE Number: I PBD4P2121 I I RiQ: I Nabors 2ES /" I Estimated Start Date: I 07/26/03 I /.- I OperatinQ days to complete: 117.0 I MD: 111 ,530' 1" I TVD: 18,778' 'I I BF/MS: 129.5' I KB: 128.5' I I KBE: 158.0' I Well DesiQn (conventional, slim hole, etc.): I Horizontal Sidetrack / , I Objective: I Zone 1 A CasinQlTubinQ Pro~-ram Hole Size Csg/ WtlFt Gr~ Co," Length Top Btm Tbg O.D. MDITVD MDITVD 9 518 csg 7" 26.0# L-80 STC 4760' 2500 I 2500' 7260 I 7072' 61/8" 4 Y2" 12.6# L-80 1ST 2580' 8950 I 8480' 11 ,530 I 8778 .,/ Tubing 4 Y2" 12.6# 13Cr-80 Vam Ace 8920' GL 8950 I 8480' Directional KOP: 19100' MD Maximum Hole Angle: Close Approach Well{s): Survey Program: -530 at 7450' MD (above window) -530 at the whipstock setting depth " -91.50 in 6 1/8" horizontal section I All wells pass major risk criteria. The closest well is DS15-39 at ctr-ctr distance of 268' and allowable deviation of 70' at reference MD of 11,087'. MW D Standard LOQging PrOQram 6 1/8" Production: Sample Catchers - over entire interval, samples described and discarded. Drilling: MWD Dir/GRlRes + ABI- Real time GR/Res throughout entire interval. NEU/DEN recorded on first bit run Open Hole: None Cased Hole: None DS15-08C Sidetrack Page 1 ) ) Formation Markers Formation Tops (wp03) TDVss TVDbkb MD Comments SAG RIVER SS -8180 SHUBLIK -8220 TOP SADLEROCHITrrZ4B -8290 TZ2 -8492 KICKOFF -8518 8576 9100 TZ1B -8691 8749 9448 ~. ç f P j TZ1A / -8737 8795 9700 BSAD -8770 8828 NOT PENETRATED TD Criteria: Reach planned TD unless drilling conditions deteriorate. Polygon has been extended -500ft /' 10 allow additional drilling past TD if 800 feet of <65 API sand has not been obtained and drilling conditions allow. Mud Program Section Milling Mud Properties: QUIKDRIL-n Density (ppg) Viscosity PV 8.4 - 8.5 I 45 - 55 4 - 7 I Whip Stock Window 7" 26# YP MBT pH 25 - 30 <3 8.5 - 9.0 API FI N/C Production Mud Properties: QUIKDRIL-n Density (ppg) Viscosity PV 8.4 - 8.5 ./ 45 - 55 4 - 7 I 6 1/8" hole section YP MBT pH 20 - 28 <3 8.5 - 9.0 API FI N/C Cement Pro ram Casing Size Basis: Lead: Based on 3000' of 7" x 9 ~' annulus (top of leaking 9 5/8" casing at ±5500') + 20% excess Lead TOC: 2500' (top of liner) Tail: Based on 1760' of 7" x 9 5/8" annulus with no excess + 85' shoe Tail TOC: 5500' MD I Fluid Sequence & Volumes: Pre Flush Spacer Lead Tail 5bbls CW 100 30 bbls MUdPGS "XC t 9.5 ppg/",,/} 92 bbls, 517 ft ,287 cks Class G@ 13.5 PP~.8,O" Yð/sack 45 bbls, 253 f 3 "sacks Class G @ 15.8 pp ,1.1ft3/sack :1 .. - Casing Size Basis: Lead: None Tail: Based on 2430' of 4 Y2" x 6 1/8" open hole annulus with 40% excess + 85' shoe + 150 liner lap + 200' DP x 7" liner annulus Tail TOC: 9100' MD I 8576' TVD-bkb (Top of Liner) I Fluid Sequence & Volumes: Pre Flush 15bbls CW1 00 Spacer 20 bbls MudPUSH XL at 9.5 ppg Lead None ~) Tail ~, " Is, 365 ft3/3J,2' sacks Class G wi Gas-Block@15.8ppg, c.:}' ft3/sack t::, DS15-08C Sidetrack Page 2 ) ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 13-5/8", 5M, 3 MPL Gates with Annular (Hydril- 13-5/8" GK) 3300 psi ( 7.5 ppg @ 8500' TVD) v" 2450 psi (.10 psi/ft gas gradient to surface) ./ Infinite Rams test to 3,500 psi/250 psi. /' Annular test to 2,500 psi/250 psi 3500 psi surface pressure 8.6 ppg Seawater /7.2 ppg Diesel 9-5/8" Casingn" Liner Test Planned completion fluids Disposal · No annular injection in this well. - · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject - at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Sidetrack and Complete Procedure SUmmary Pre-riQ Operations: In preparation for the sidetrack the following pre-work has been performed: ./ PPOT-IC passed at 5000 psi and LOS cycled on 6/2/03 ./ Passed an outer annulus pressure test to 3000 psi on 6/8/03 Remaining Work: 1. Pull the 3 Y2" Eclipse retrievable tubing patch at 5474' MD (set in January 2002). 2. Drift the tubing and liner to as deep as possible (-65° inclination at 9300' MD, building to horizontal) for CT P&A. 3. RU Schlumberger e-line. Run RST log in gravel pack mode to determine top of fill in the tubing annulus on top of the packer at 9270'. 4. R/U coil tubing unit. Fluid pack the tubing annulus and tubing and lay cement abandonment plug from PBTD at 12,438' to 50' above the production packer MD (32.8 bbls). Dress the top of cement at 9220' 5. Drift the 4 Y2" X 3 Y2" tubing and tag the top of the cement to confirm the tubing is clear to the required cut depth of approximately 9120'. 6. R/U E-line. RIH with chemical cutter and cut the 3 Y2" tubing at -9120' MD. POOH 7. Pressure test the well (combo IA x tubing) to 3500 psi 8. Circulate the well to clean seawater. Note final shut-in pressure for brine weight calculation. Freeze protect to 2,100' with diesel. Set BPV with lubricator. OS 15-08C Sidetrack Page 3 ) ) Ria Operations: 1. MIRU Nabors 2ES 2. Circulate out freeze protection and displace well to kill-w~ht brine. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. 4. Pull the 4%" X 3%" tubing from the chemical cut at ±9120' MD. 5. PU and RIH with 7-7/16'~ polishing mill. Polish 7" TBE at 7259' MD. /" 6. Run and Gement a 7" scab liner from 2500' MD to top of existing 7" liner. 7. RIH with 6 1/8" bit and watermelon mill. Test the casing to 3500 psi and drill the scab liner shoe track. 8. RIH to top of cut tubing fish. Displace hole over to 8.4 ppg milling/drilling fluid. . 9. PT casing to 3500 psi for 30 min. POOH./ 10. P/U and RIH with 7" Baker bottom-trip anchor whipstock assembly. Orient whip stock 80° left of high, side and set on the cut tubing stub. ,/ 11. Mill window in 7" casing at 9100' MD. Pull up into 7" casing and conduct an FIT to 10.0ppg EMW. POOH. / 12. RIH with 6 1/8" Dir/GR/Neu/Den assembly. Kick off and drill the 61/8" build section 13. Trip for bit, drop NEU/DEN and continue drilling to TD of approximately 11,530' MD in Zone 1 A, /' according to the directional plan. Short trip, spot liner running pill, ~OH. 14. Run and cement a 4 V2", 12.6#, L-80 production liner. POOH. 15. R/U and RIH with Halliburton 2 %" dpc perforating guns. Perforate per Hallibu~.recommendation. 16. Run a 4 1/2", 12.6#, 13Cr-80 completion, stinging into the 4 1/2" liner tie back. 17. Set packer and test the tubing and annulus to 3500psi for 30 minutes. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. /' 19. Freeze protect the well to -2100' and secure the well. /' 20. Rig down and move off. Post-Ria Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move onto DS15-08C. The well is located on on 120' center from DS15-07C to the no~ (off-driller's side) and 60' center from DS15-30 to the south. ~ D515 is not an H2S site. Recent H2S data from the pad is as follows: v Closest SHL Wells: 15-07C No data 15-30A No data Closest BHL Wells: 15-39 No data 15-49A 1 ppm ,,-- The maximum level recorded of H2S on the pad in recent history was 33 ppm on 15-44 and in 1996. ~ Post Permit to Drill in camp prior to spud. Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP fI' _}.".,.......... .\ -_. _ ~ "'iI"..;.I....;-·-!'t DS15-08C Sidetrack Page 4 ) ) Job 2: De-complete Well Hazards and Contingencies ~ NORM test all retrieved well head and completion equipment. ~ The well will have pressure from the cretaceous leak at ±5500' MD. The correct brine weight (0.1 ppg overbalance) will be determined during the pre-rig work. ~ Inspect the running threads on the tubing hanger and be prepared to pick up a double-grapple spear if the threads are damaged. Reference RP .:. "De-completions" RP ~.~))þ,;~;¡'¡;~WM',&;.;.,...~;';";';";';';"'::¡¡<!-;~"'.:'w"~...,~w".,.,t"~'*I"{{_(~~>O:;:;:":~,W.~';':';';';,I,;,I,,;,~,~\W,¡,W,;I,:.~""'''''''''''~'"~(:';'I;,;':¡¡.W.;~;,W.,~;,..;.,· ~f., Job 3: Run and Cement 7" Tieback Hazards and Contingencies ~ Verify the polish mill run was fully inserted into the tieback sleeve and be prepared to run a drillable bridge plug just below the 7" liner top and conventional float-shoe / landing collar arrangement if the tieback receptacle ID is in question (see recent C-16A sidetrack). Reference RP .:. "Whipstock Sidetracks" RP ~'''~~~~:¡:,~,:r,:..~\~j':I.I :~~~~'~~'f1::~'I'\'.~,'!':\,~'~I;I:C-'''''';> '''.,I, ~¡"',\\~':'r;:~~1fo!t.,~..It.õl¡'M'~~~,I:<,I,~<ØI:¡...:,I':.'~,<Y,'¡'''''~~;;I;\~~ Job 4: Window Mill Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. ~ The 7" liner was cemented with 111 bbls class G cement and full returns during the 1993 sidetrack. Two bbls cement was reported while reverse circulating off the top of liner. Two turbolators per joint are positioned on the 26 joints (below 8800' MD) resulting in a high likelihood that a turbolator will be cut while milling the window. A second mill run may be required. Reference RP .:. "Whipstock Sidetracks" RP ""'-:...........,......w.v....,,->w-:--_~«~w...=*.·,:::_.......................d,"~nWY....x"'~~.....x..··....._....J....._~!~~.¡.¡::::::::::::~WY................w...··,·,"~{~~ml~~: ::m:_~:":::I.:_:=:I:-:-'I ::;;m;,M~_~~·mrml ::::I::mr:a::I!:flmtmll. ~.+>r.>"'">'«~mmcr:1I Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies ~ One fault crossing is anticipated in this well at 11,725' (±100') with 5 -15' of throw. It is not expected to cause lost circulation problems, however the lost circulation decision tree may be followed in the event of losses. ~ The Kavik below and the GOC above bound the Zone 1 A target. Every effort should be made to avoid drilling too low into the Kavik for wellbore instability concerns or too high into the gas. A main objective of this well is to optimize stand-off to the GOC while maintaining good 1 A reservoir ./ quality. The BHA will include ABI to improve directional control in the horizontal section. ~ The hardline east of well plan during build from KOP is marked to avoid faulting. That west of well plan (towards the toe) is to avoid collision risk with 15-39. ~ KICK TOLERANCE: In the worst-case scenario of 8.8 ppg pore pressure in the Ivishak, a ... fracture gradient 6f'9.6 ppg at the 7" casing window, and 8.6 ppg mud in the hole, the kick tolerance is I'nfinit~: , ,-//' DS15-08C Sidetrack Page 5 ') ) Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP 1_~__m:nl':I~I~:n:I":I!:lmllll!Um:m:mm_ _11.\,. \;;;:::!II:!I:\:mnmm:mlmlmnICI!l;lnll~'lm!':I!:I:rl!lm _ .!II:!"lm. _ '1_!:\..I';I:~~I:m:-:"I!:_ .ll!It\ -: ~:!I~: - :llmlll:ln:IIWII~\':-,:mllrll;III-:mlll:----:"III:\:----~!I~I":!I'::-::I-nln-m"-I:-I':lnl~:III:!I:lln:m:'n!:-II~1111111'111111111'--' Imm:-:lmr: -; :\111.1'1.. ,)I,;;.-.l\r'IIII:I: -1:1~I!Cnl'I::lllm'IIII'I':- ':m:mlm. .1 . Job 9: Install 4 V2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.6ppg mud will be -700psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ A Gas-lock type slurry is requested to ensure the best chance for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" ~"''''''''''''^,NH'~···:':W.·.....:o''',,~<~ *'1¡.,,;,.~œ:~:C::I!mlm,I:;:r~;;H:::;;~ii:::~~'I-'''''''!~··''''''«·~,,¥,·~·,~~i::4m. :.t~~:I:::'::CII_III::I:m::I~::::: Job 10: DPC Perforate Production Liner Hazards and Contingencies ~ Observe Halliburton's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Halliburton perforating practices and recommendations. .:. "DPC Perforating" RP ~~~~ ,¡:Ii-:¡;+;':I>~m,I'¡,:,~,I,I,I',~;;'~'1~"m~~,~,,; !., ~~~~1~m:,;,'~¡"~f:Im~m,I,I.I~ Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressu re is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP .:. "Use of 13-Cr Tubulars" .:. "Running and Handling 13-Cr" : 1_--'I-: 1'::n:'-I:;I:-r~I::I:':'CI__1 Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ There are no identified hazards particular to this phase of the operation. Reference RP .:. "Freeze Protecting an Inner Annulus" RP DS15-08C Sidetrack Page 6 TREE = FMC GEN 3 WB..LHEAD = FMC 'ÃëTUA:TÕFf;''''''~'''AXäsõÑ "....-'''".....,''''''.................,............,........~"~,...."..............""...............,.....,,,...~,,,.......................,''''............,' KB. ELEV = 71' ............·.....,.,......·...........,..,·"·.........,...·,....·,...,.,·,..·,...,,,·........,...,"........'''''·M,.,.,..,.......,... BF. ELEV = KOP = 5800' 'Max"Angië..,;'........èïf@...'f1Ù32ï Öatlirri"r\iïb ,;·...···················_··~j"9à€F ÖatÙiTïiV6';;'; ··'······...··áäob"ï'S·S 113-3/8" CSG, 72#, L-80, ID = 12.347" H Minimum ID = 1.75" @ 5474' Eclipse patch set across GLM #2 14-1/2" lBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" H 1 TOP OF 3-1/2" TBG 1-1 1 TOP OF 7' LNR 1-1 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 ) 2539' 3103' 3103' 7259' 7448' PERF ORA TION SUMI'v\A. RY REF LOG: DLL ON 10/20/93 ANGLEATTOP ÆRF: 95 @ 9951' Note: Refer to A"oductbn DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DATE 4-1/2" SL 9854-10725 SLTD 11/23/97 2-3/8" SL 10496 - 10585 SL TD 11/23/97 2-3/8" 10585 - 12438 DRLD 11/23/97 2-1/2" 4 9951 -10120 0 11/23/97 2-1/2" 4 10150 - 10300 0 11/23/97 2-1/2" 4 10440-10471 0 11/23/97 1 3-1/2" lBG, 9.2#, L-80, 0.0087 bpf, ID = 2.992" 1-1 ~ ~, ~ 9258' 1 4-1/2" lBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1-1 13-1/2" lBG, 9.2#, L-80, 0.0087 bpf, ID = 2.992" 1-1 ) 15-088 / SAFETY NOTES: T X IA COMM @ GLM #2. IA x FORM COMMUNCATION@5893',1.5BPM @2800 PSI. WB.L MAY NOT BECAPABLETO FTS lP THEIA. SWN NIP @ 9444'IS BAD. USE SWS NIP @ 9388' FOR TIP. 70° @ 9413' & 90° @ 9854' - L 2026' 1- 4-1/2"CAIVCOTRDP-4A SSSV NIP, ID= 3.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DAlE 1 3178 3178 0 MMG RK *2 5492 5492 0 MMG RK 3 7179 7015 45 Mi\i1G RK 4 8802 8368 16 IVMG TG 5 8987 8507 44 Mi\i1G RKP *STA. 2 PATCHED ~ ;I I I 3103' 5474' 1-1 4-1/2"X 3-1/2" XO, D =3.5" 1 1- TOPOF EQ.IPSE PA TCH RUN ACROSS GLM#2, ID= 1.75" 11 9-5/8" WINDOW @ 7448' 9276' 9227' H 3-1/2" PARKffi SWS NIP, ID = 2.813" 9258' 1-1 3-1/2" X4-1/2"XO 1 9270' 1- 7" X 4-1/2" BAKER SABL-3 R<R W/ 4-1/2" K-22 ANCHOR 1-1 4-1/2" X 3-1/2" XO 1 9388' 1-13-1/2" PARKffi SWS NIP, ID= 2.813" 9444' t- 3-1/2" PARKERSWN NIP ID = 2.75" (MILLED OUT) 1-1 3-1/2" Tl1 WLEG 1-1 B..MD TT NOT LOGGED 9761' 1-1 7" PKR 1 9456' 1 7" LNR, 26#, 13-CR, 0.0383 bpf, ID = 6.276" 1-1 9825' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" 1-1 9854' 1 12-3/8" LNR BLANK, 1',4.6#, R.4S, 0.00387 bpf, ID = 1.995" 1-1 10495' 9768' - 4-1/2" ÆRPD 6.67' RJP JOINT \ \ \ \ \ 1 BOTTOM OF 2-3/8" LNR -SLOTT8J H 10585' 14-1/2" LNR-SLTD, 12.6#, L-80, 0.0152 bpf, ID = 3.953" H 10725' 1 BOTTOM OF 23/8" FREDRILL H 12438' 1 2-3/8" LNR, 4.7# FL-4S, .00387 bpf,lD = 1.995" H 12471' 1 1 TO H 12627' I 1)6. TE 1984 10/21/93 11/22/97 12104/00 01/29/01 04102/02 RBI BY 00 MVI B'..JTS ORk3INAL COrvPLETION COrvPLETION SIDErRACK COMA-EllON CONI! ffiT8J TO CA NI! AS FINAL CORRECTIONS S6-lsl S IS- rvD RN'TP DA lE REV BY COMWENTS 03122/03 JrvP/KK SAFETY NOlE REV610N PRLD -()E BA Y UNIT WELL: 15-08B PERMIT No: 1971820 AA No: 50-029-21180-02 SEe 22, T11N, R14E, 4050.67 FB.. & 3719.98' FNL BP Exploration (Alaska) . TREE = . FMC GEN 3 WELLHEAD = FMC 'ACfÜAfõR;" . AxËLsÕN KËiäE\ï";'" """",. '"'' " "'" 7'1'ï SF. ELsi;;; KOP= Max Angle = DatumMD = . baïüïï1"T\/b"~""'''' ..... ...... "SS'ÖÓï"'SS 113-3/8" CSG, 72#, L-80, ID = 12.347" l-i 17" 26# L-80 BTC Sw cab Liner top l-i ) 5800' 2539' 2500' 1 TOP OF 7" LNR l-i 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 7259' 7448' r 4-1/2" TBG, 12.6#, 13-Cr, 0.0152 bpf, ID = 3.958" l-i 13 1/2" Tubing Cut l-i 9120' Top of 15-07B Abandonment cmt l-i 9220' PERFORA TION SUMMARY REF LOG: DLL ON 10/20/93 ANGLE AT TOP PERF: 95 @ 9951' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1 Old PBTD l-i 12627' 1 DATE 1984 10/21/93 11/22/97 12/04/00 01/29/01 04/02/02 REV BY COMMENTS ORlGINA L COMPLErION COMPLErION SIDErRA CK COMPLErION CONVERTED TO CANVAS FINAL CORRECTIONS 15-08C PROPOSED . I -) SAFETY NOTES: ~ 2100' 1-i4-1/2" X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD ìVD DEV lYPE VLV LATCH PORT DATE 3 2 1 ~I I I ~?:! I J L Ii ~@j: !' ¡~, I ¡(I¡~ ~m :1 ~j:~1 ~i~~:!~ ~:m¡ :1 'H I-Ii p ~ 8954' l. \ ·1 ~\~:!i~ i:::~: . 8880' l-i 41/2" X Nipple 3.813" ID 8900' l-i 7" x 4 1/2" Baker S-3 Packer 8930' l-i 41/2" X Nipple 3.813" ID 8940' l-i 4 1/2" XN Nipple, 3.725" ID 8950' l-i Top of 4 1/2" Liner 9100' l-i 7" Top of Window .. ~ 'r' 0<, ..., l-i 11,530' I l-i 11,450' 1 - 14 1/2" 12.6# L-80 Liner TD 1 PBTD DA TE REV BY COMMENTS 03/22/03 JMP/KK SAFElY NOTE REVISION 06124/03 PGS Proposed Sidetrack SIS-Isl SIS-MD RNlTP PRUDHOE BA Y UNIT WB..L: 15-08C PERMIT No: 1971820 API No: 50-029-21180-03 SEe 22, T11 N, R14E, 4050.67' FB.. & 3719.98' FNL BP Exploration (Alas ka) SURVEY PROGRAM Plan: 15'()8Cwp03 (15'()8AlPlan 15'()8C) Depth Fm Depth To Surv<yIPlan Tool Created By: Ken Allen Dale: 6/4/2003 9100.00 11529.82 Planned: 15-08C wpOJ V6 MWD Checked : Date: Reviewed: Date: WELL DETAILS Name ..;.-W..s +EI-W Northing Easting Latitude Longitude Slot I5-08A 1007.41 W48.27 5959869.01 6TI321.27 7001T45.144N 148"33'50.659W 08 TARGET DETAILS Nam: lVD +NI-S +EI-W Northing Easting Shape 15-08C D \Vp 3 'ð1TI.99 309435 -648.49 5962947.00 676600.00 Point 15-08C T2 \Vp 3 'ð19O.99 2245.97 2'ð1.82 5962121.00 677556.00 Point 15-08C T3 'ð192.99 2972.01 -339.27 5%2832.00 67691200 Point 15-08C D.I 'ð192.99 2870.15 -473.72 5%2727.00 676780.00 Point 15-08C T2 8802.99 2098.60 17430 5961971.00 677446.00 Point 15-08C TI \Vp 3 8802.99 195432 650.06 5961838.00 6TI925.00 Point ] 5-08C T2.1 8802.99 2245.97 2'ð1-82 5962]21.00 677556.00 Point ]5-08C Tl 8807.99 1734.26 818.93 5%]622.00 678099.00 Point SECTION DErAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 9100.00 53.25 26.55 8576.32 1409.56 889.72 0.00 0.00 1197.09 2 9120.00 53.70 23.62 8588.22 1424.11 896.53 12.00 -80.00 1209.94 3 9632.70 84.88 312.50 8789.97 1842.06 774.69 14.00 -82.81 1644.00 4 9756.05 84.88 312.50 8800.98 1925.07 684.11 0.00 0.00 1743.81 ~ 5 9801.01 90.00 308.84 8802.99 1954.32 650.06 14.00 -35.66 1779.43 15-08C Tl Wp 3 6 9826.33 91.52 308.84 8802.65 1970.20 630.34 6.00 0.00 1799.02 7 10266.22 91.52 308.84 8790.99 2245.97 287.82 0.00 0.00 2139.18 15-08C T2 Wp 3 8 10325.41 90.57 312.26 8789.91 2284.43 242.86 6.00 105.52 2186.05 9 11529.82 90.57 312.26 8777.99 3094.35 -648.49 0.00 0.00 3161.57 15-08C T3 Wp 3 CASING DErAILS FORMATIONTOPDErA~S No. TVD MD Name Size No. TVDPath MDPath Fonnation 8777.99 529.82 4 !l2' 4.500 8648.44 9225.16 Z2TS All TVD depths are ssTVD plus 57. 99'for RKBE. REFERENCE INFORMATION WeO Centre: 15-08A_ True North 57.99' 57.99 Slot - 08 (O.OON.O.OOE) 57.99' 57.99 Mini:rnmn CUI\'atuœ ~~ Co-ordinale (NiE) Reference: Verti<31 (IVD) Refereoce: Se.:tion (VS) Reference: Me.sured Depth Reference: Calculation Method: COMPANY DETAILS ß Amoco Minimlml C'\.Jr\"3.tun; ISC\VSA T ray Cylir><ler Nonh Emptical . C<lSing Rules Based Ir! ' I ¡fJ ¡Þ I I ¡; ,I ¡/J ,I o Cakublion Method: Error Syslcm: Scan MClbod: Error Surrac~: Waminsz Method: bp 8086- '/000 -~ 1529.82' MD, 8777.99' TVD - ------ I 3346 I 3625 T oIal Depth 3067 2788 Start Dir 6°/100' : 10266.22' MD, 8790.99'TVD End Dir : 10325.41' MD, 8789.91' TVD , 2509 Vertical Section at 348.16° [ft] 2230 1952 1673 Start Dir 12°/1 00' : 9100' MD, 8576.32'TVD Start Dir 14"/100': 9120' MD. 8588.22'TVD 394 8364- ~ P.. Ö ] ';: > 2 ¡- 8643 8922 c 2 2500 o Ë t t: ~ "5 c </J bp COMPANY DETAILS REFERENCE INFORMATION Depth Fro Depth To SurveylPlan 9100.00 11529.82 PIanœd: I5-08C wp03 V6 Date. ßP Amoco Co-ordina", (NIE) Refereoœ: Well CenlIe: 15-08A. Trœ North Vertical (TVD) Reference: 57.99' 57.99 Section (VS) Reference: Slot - 08 (O.OON.O.OOE) M=ured Depth Refereoœ: 57.99' 57.99 Cakulalioo Method: Minimum CU,,"llure ('alcola!ion Mcthod: Minim,"" ('urvatun: Error System: ISCWSA Seau MeO""': Trnv C)1indcr Nortb Error Sur"'ee: Elliptical + Casing Wamil1 ! Method: Rules ß3,.,d All TVD depths are ssTVD plus 57. 99'for RKBE. See MD 9100.00 9120.00 9632.70 9756.05 9801.01 9826.33 3500-- 1 2 3 4 5 6 : 11529.82' MD, 8777.99' TVD 2000 .·,,·,,·IJ I 'U1!1r.~(n \J~ 7 10266.22 91 .'" "'" . 1j Wp 3 8 10325.41 90 · · A'" 9 11529.82 90 . . 4 ilL' .."" '+ · """ , lt~ ¡ No. , . "- ,',"",,' · , I 8 ,.,' "',' "". ~ · .. . "'- · ,. · '" , . '" ".""., ""..'", '. ~\;;; _.,.. ..'..m. · ". "" "",." · · " . , "- J", niT: 10325.41' MD, 8789.91' TVD . · · ~",I . · u u ".,..' ./ :start .Vir óU( IOU' : 10266.22' MD, 8790.9 · i . ]..~;osw T2 Wp 3 · , · , ! ¡ "",. .." '" .,. -t. ~~,: End Dir : 9826.33' MD I I Start Dir 6°/100' 98( · . . " . . . ~ N.; ~ Kt Start Dir 14°/100 ,. ".. ..,.. ,.,'" .,." ,. \2r Wp3 .,' """.., · · . . .....,. ,.." · .. :.1JI =t-¡_IE "'- ~n : 963 "".", ". ..". , '.' : j !\ .,'.' . .. ' --T \ J'}O ..""., ."'.um "" .'.'.',. """ ""., · · · l..Tr~·IT, · · . . . ßtart .", ~ IrlDi, 'P' .'.'.," ,. · I "" ",', "". ",'," "'" ."" , I ... ,',," ,,"" .,' '" " .., "'" · / · · / · .' · . . . / · ,,' ." '" ".""",., · ¡ : , .. ...m.m.. · / ! ,-- .......m. . · I ., '.', ,,'.',.. . · !y "., ", .,.'"" ""., · · · '/ '" /ì , i I I I I I I I I I I I I I I J I I I J I J J I I I I I I I I I I I I 3000 .. 1500 1000 -1500 -1000 500 W est( - )/East( + ) [500ft/in] 1000 -500 SURVEY PROGRAM Plan: 15-QSCwp03 (15-0SNPlan 15-QSC) Tool Date: 6(412003 Created By: Ken Allen Cheeked: Dale: MWD Reviewed: Ine WELL DETAILS NaIœ +NI-S +fJ-W Nortbing Easting Latitude Longit1Kle Slot 15-08A 1007.41 W4827 5959869.01 67132127 70"IT45.144N 148"33'50.659W 08 TARGET DET All.S Narœ TVD -tNf-S +fJ·W Nonbing EasIing Sbape 15-08CDWp3 'ð/71.99 309435 -648.49 Point 15-08CDWp3 'ð/71.99 309435 -648.49 5962947.00 676600.00 Point 15-08C Tl Wp 3 8802.99 195432 650.06 5961838.00 671925.00 Point SECTION DETAILS Azi TVD +N/-S +EI-W DLeg TFaee VSee Target 26.55 8576.32 1409.56 889.72 0.00 0.00 1197.09 23.62 8588.22 1424.11 896.53 12.00 -80.00 1209.94 312.50 8789.97 1842.06 774.69 14.00 -82.81 1644.00 312.50 8800.98 1925.07 684.11 0.00 0.00 1743.81 308.84 8802.99 1954.32 650.06 14.00 -35.66 1779.43 15-08C T1 Wp 3 308.84 8802.65 1970.20 630.34 6.00 0.00 1799.02 308.84 8790.99 2245.97 287.82 0.00 0.00 2139.18 15-08C T2 Wp 3 312.26 8789.91 2284.43 242.86 6.00 105.52 2186.05 312.26 8777.99 3094.35 -648.49 0.00 0.00 3161.57 15-08C T3 Wp 3 ~' 53.25 53.70 84.88 84.88 90.00 91.52 .52 .57 .57 CASING DETAILS FORMATION TOP DETAILS TVD Size No. TVDPath MDPath Formation MD Name 777.99 11529.82 4112" 8648.44 9225.16 Z2TS 4.500 9'TVD ---- , 8802.65' TVD 2.7' MD, 8789.97' TVD Dir 14°/100': 9120' MD, 8588.22'TVD 12°/100': 9100' MD, 8576.32'TVD / I I I I I I I I I 1500 I I I I I I I I I I 2000 ') BP KW A Planning Report MAP . Company: Fiei (1: ·'Sit~i 'Wëll: .. W~.lþatb: :Date: ,6/4/2Q03" 'Tilne:1,1 ;p~tQO "'" CO"1)~djnllt~(NE)Ref~re~~e: VIJ~I.I: 15-98)\. True North: , Verth:~H'IT\'I»~ëtet~nee:<57J9.9':58,0 ' ,', ..' ,... section (VS)~ef~rèÏi¢e:" 'WøU(9;()öN,ö.QQE,348.16Aii) , , , Suiv~y Çålçülàp()JtMéthod:: ··Mininiqmc:urvature, Db:: Oråclê'· BPl;\mçco .PrtJC hp~l3ay P~pS15' " 15~Ô8A Plåry 15~08C Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: 70 17 Longitude: 148 34 North Reference: Grid Convergence: Well: 15-08A 15-08A Well Position: +N/-S +E/-W Position Uncertainty: Slot Name: 1007.41 ft 1048.27 ft 0.00 ft 5959869.01 ft 677321.27 ft Northing: Easting : Latitude: Longitude: Well path: Plan 15-08C Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 57.99' 5/28/2003 57550 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 57.99 ft Plan: 15-08C wp03 Date Composed: Version: Tied-to: Principal: Yes Casing Points MD ft 11529.82 Formations TVD Diameter . Holë Size Name ft in in 8777.99 4.500 6.125 41/2" TVD Fonnations Lithology ft 0.00 TSag 0.00 TSad 0.00 TCGL 0.00 BCGL 8648.44 Z2TS ') Alaska, Zone 4 Well Centre BGGM2002 35.236 N 21.213 W True 1.34 deg 08 70 17 148 33 45.144 N 50.659 W 15-08A 9100.00 ft Mean Sea Level 25.90 deg 80.84 deg Direction deg 348.16 5/29/2003 6 From: Definitive Path MD ft 9225.16 Targets Map Nortbing Dip ^ng1e deg 0.00 0.00 0.00 0.00 0.00 DipJ)irection. deg 0.00 0.00 0.00 0.00 0.00 Map Easting <......;.. Latitllde-";"> Deg MÌll See <- Longitude --> Deg Min Sec Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/1000 deg/1 OOOdeg/1 000 deg 9100.00 53.25 26.55 8576.32 1409.56 889.72 0.00 0.00 0.00 0.00 9120.00 53.70 23.62 8588.22 1424.11 896.53 12.00 2.26 -14.67 -80.00 9632.70 84.88 312.50 8789.97 1842.06 774.69 14.00 6.08 -13.87 -82.81 9756.05 84.88 312.50 8800.98 1925.07 684.11 0.00 0.00 0.00 0.00 9801.01 90.00 308.84 8802.99 1954.32 650.06 14.00 11.39 -8.15 -35.66 15-08C T1 Wp 3 9826.33 91.52 308.84 8802.65 1970.20 630.34 6.00 6.00 0.00 0.00 ) ) BP KW A Planning Report MAP ¢Q~e~ny: BP Amòço "p~te: . .,.. ?/4/2PQ3", '" " Time:, 11 :$4:QO.. . J!:ield; . PrugÐpel3~Y '~()~~~«Iil1~te(l~r~)',Jl~f~r~llc~: :V)!$11:157q~~ITrueNé)rt~: ' $iiê;" P~:P$1$ , Y~rtiy~~ (TYJ?)a.~{er~n~e: ' ' q7;9~r58.þ . .' . .. . '. . , . Wéïl: ' 15~Ö8A ' .S~eti~?:(.y~,~e~e"~l1çe: " "WEIll :(0;OQN;PiOPEf¡348.16A2:í), ")V~'lpåth: · ,'PI$n15~Ö8Ö .'$*rvëyÇal¢µlatí~p·l\1e(l1od:' ":Mlnlti1urrrCqrvè\ture<·' , Db: Plan Section Information :i\.:ID Joel ·"'·~im tN/-:-S,' tE/FW PI..S ...Bui1Ø .TÍI~11 TJ;'<) ,.: ft g~ d~9f ' ft ft " ,d~9(1.00ft ,~~g/1qOftdeg(1p()ft d~,.·': 10266.22 91.52 308.84 8790.99 2245.97 287.82 0.00 0.00 0.00 0.00 15-080 T2 Wp 3 10325.41 90.57 312.26 8789.91 2284.43 242.86 6.00 -1.61 5.78 105.52 11529.82 90.57 312.26 8777.99 3094.35 -648.49 0.00 0.00 0.00 0.00 15-080 T3 Wp 3 Survey 'MD '¡nd .., Aiim 1'VD . Sys T,vD !VfapN ' .·Måp~ vs PI..S " ", "Tfq 'tOoliÇOll1lnellt ' ft dèg " ··'deg· ft ,'.', ft ft ft'.. ft 'deg/100ftdeg , 9100.00 53.25 26.55 8576.32 8518.33 5961299.07 678177.43 1197.09 0.00 0.00 MWD 9120.00 53.70 23.62 8588.22 8530.23 5961313.78 678183.90 1209.94 12.00 280.00 MWD 9125.00 53.79 22.75 8591.18 8533.19 5961317.53 678185.40 1213.24 14.00 277 .19 MWD 9150.00 54.34 18.48 8605.86 8547.87 5961336.63 678192.07 1230.31 14.00 277.70 MWD 9175.00 55.03 14.28 8620.31 8562.32 5961356.32 678197.35 1248.28 14.00 280.21 MWD 9200.00 55.87 10.15 8634.50 8576.51 5961376.53 678201.23 1267.08 14.00 282.64 MWD 9225.00 56.84 6.11 8648.35 8590.36 5961397.19 678203.68 1286.64 14.00 284.98 MWD 9250.00 57.94 2.17 8661.83 8603.84 5961418.22 678204.70 1306.87 14.00 287.22 MWD 9275.00 59.15 358.32 8674.88 8616.89 5961439.53 678204.28 1327.72 14.00 289.35 MWD 9300.00 60.48 354.57 8687.45 8629.46 5961461.05 678202.43 1349.10 14.00 291.36 MWD 9325.00 61.91 350.93 8699.50 8641.51 5961482.71 678199.15 1370.93 14.00 293.24 MWD 9350.00 63.44 347.38 8710.98 8652.99 5961504.41 678194.46 1393.14 14.00 295.00 MWD 9375.00 65.05 343.93 8721.84 8663.85 5961526.08 678188.36 1415.62 14.00 296.63 MWD 9400.00 66.73 340.57 8732.06 8674.07 5961547.63 678180.89 1438.32 14.00 298.13 MWD 9425.00 68.49 337.30 8741.58 8683.59 5961568.99 678172.08 1461.13 14.00 299.50 MWD 9450.00 70.31 334.10 8750.38 8692.39 5961590.08 678161.95 1483.97 14.00 300.75 MWD 9475.00 72.19 330.98 8758.42 8700.43 5961610.82 678150.54 1506.77 14.00 301.87 MWD 9500.00 74.11 327.93 8765.67 8707.68 5961631.12 678137.89 1529.42 14.00 302.87 MWD 9525.00 76.07 324.93 8772.10 8714.11 5961650.92 678124.06 1551.86 14.00 303.76 MWD 9550.00 78.07 321.98 8777.69 8719.70 5961670.15 678109.10 1573.99 14.00 304.53 MWD 9575.00 80.11 319.08 8782.43 8724.44 5961688.72 678093.05 1595.73 14.00 305.19 MWD 9600.00 82.16 316.21 8786.28 8728.29 5961706.57 678075.99 1617.01 14.00 305.74 MWD 9625.00 84.24 313.37 8789.24 8731.25 5961723.63 678057.97 1637.73 14.00 306.18 MWD 9632.70 84.88 312.50 8789.97 8731.98 5961728.72 678052.23 1644.00 14.00 306.52 MWD 9700.00 84.88 312.50 8795.98 8737.99 5961772.83 678001.76 1698.46 0.00 0.00 MWD 9756.05 84.88 312.50 8800.98 8742.99 5961809.56 677959.73 1743.81 0.00 0.00 MWD 9775.00 87.04 310.95 8802.32 8744.33 5961821.80 677945.33 1759.02 14.00 324.34 MWD 9801.01 90.00 308.84 8802.99 8745.00 5961838.00 677925.00 1779.43 14.00 324.45 MWD 9826.33 91.52 308.84 8802.65 8744.66 5961853.41 677904.91 1799.02 6.00 360.00 MWD 9900.00 91.52 308.84 8800.70 8742.71 5961898.22 677846.48 1855.98 0.00 0.00 MWD 10000.00 91.52 308.84 8798.05 8740.06 5961959.05 677767.16 1933.31 0.00 0.00 MWD 10100.00 91.52 308.84 8795.40 8737.41 5962019.88 677687.85 2010.64 0.00 0.00 MWD 10200.00 91.52 308.84 8792.75 8734.76 5962080.72 677608.53 2087.97 0.00 0.00 MWD 10266.22 91.52 308.84 8790.99 8733.00 5962121.00 677556.00 2139.18 0.00 0.00 MWD 10300.00 90.98 310.79 8790.25 8732.26 5962142.00 677529.56 2165.66 6.00 105.52 MWD 10325.41 90.57 312.26 8789.91 8731.92 5962158.39 677510.15 2186.05 6.00 105.56 MWD 10400.00 90.57 312.26 8789.17 8731.18 5962207.23 677453.79 2246.46 0.00 0.00 MWD 10500.00 90.57 312.26 8788.18 8730.19 5962272.71 677378.22 2327.46 0.00 0.00 MWD 10600.00 90.57 312.26 8787.19 8729.20 5962338.18 677302.65 2408.45 0.00 0.00 MWD 10700.00 90.57 312.26 8786.20 8728.21 5962403.66 677227.08 2489.45 0.00 0.00 MWD 10800.00 90.57 312.26 8785.21 8727.22 5962469.14 677151.51 2570.45 0.00 0.00 MWD 10900.00 90.57 312.26 8784.22 8726.23 5962534.61 677075.95 2651.44 0.00 0.00 MWD 11000.00 90.57 312.26 8783.23 8725.24 5962600.09 677000.38 2732.44 0.00 0.00 MWD 11100.00 90.57 312.26 8782.24 8724.25 5962665.57 676924.81 2813.43 0.00 0.00 MWD 11200.00 90.57 312.26 8781.25 8723.26 5962731.04 676849.24 2894.43 0.00 0.00 MWD 11300.00 90.57 312.26 8780.26 8722.27 5962796.52 676773.67 2975.43 0.00 0.00 MWD pomp~ny~ Fle(d: 'Sit~:,"·. ''\Yell: · W~lIpath:., Survey MD fC 11400.00 11500.00 - 11529.82 BPAmqco' PrtldhÞø B~y , PBb$1S '15-08A· , Plahts"(j8C· 'Incl.,.. , døg · 90.57 90.57 90.57 ) BP KW A Planning Report MAP )\2:lm '., de~J 312.26 312.26 312.26 J'YD ·'ff 8779.28 8778.29 8777.99 "" ..' Sysrvp 'J~ ' 8721.29 8720.30 8720.00 ) Date:!5/4/2003 ' ," ,," , Time:' 1t:54~oO " " , " , ' , éo;'or4Î1i~tt1(NE) Refei"tJnç~: .. VVøI1;1$SÖØA., True, NQrth ''Vertiçal(TVµ)Referencè;'' ?!';9St58;0..,.. :.... .',..'" ...",. .".,. ,.. Section (y~)Ref~rence; , . '.·'W~It~0,OpN;0.OOp;(M8; 16Azi) SurveyÇ:'lculaiionMethôd~' "Minirnlln;1'(}urvature· i)b~ 'M~pN. ft 5962862.00 5962927.47 5962947.00 1\11ipE , ft 676698.11 676622.54 676600.00 'vs ·ft 3056.42 3137.42 3161.57 'þl.is ,'. ".'. TFO æóollCöminênt ' , (jeg/10Oft ,dØg 0.00 0.00 MWD 0.00 0.00 MWD 0.00 0.00 MWD SURVEY PROGRAM Depth Fro Depth To SUl\ey/Plan Tool 9100.00 11529.82 Planned: IS-œC "J'03 V6 MWD WELLPATH DETAILS ToMD Plan I~ 9000 Parent Wellpath: Is.08A 9250 Tie 00 MD: 9100.00 9500 Rig: Ref. Datum: 57.99' 57.99ft 9750 V.section Origin Origin SIarting 10000 Angle +NI-S +Fi-W From 1VD 10250 348.160 0.00 0.00 0.00 10500 10750 11000 11250 LEGEND 11500 - 1".ir"II'_II)o;IM....,lu_l - 1:·-II)oi~\II·....II'\Cr" NlllHRORS 11750 -- ",-II"'i,,¡"fll (1.......'AF"l'I..NOERRORS - 1"'-IJ¡.;illl,,\..(I¡.;fll.r'¡llfRRORS -'".-II,o,EII"El fI"'f.I(E,f"[ClI.JI -- 1··1711'·17,.M.J..·,It'...... ~ I", IlJr\II:"·I·J~\1 M.JI,...Ri5 -1"':'/II"\-:1,M...,.·,I:.I.-" - I·,~!.JII '~IJ M"''''IJ:..¡. - 1..-tI"·.JIF'IM.1I·_.rll~ --- "·-I'(I",-t:IM_'''''(!LL .~ ·-I!.J(I·.~"', tlill...II'!1 ....I,lðl ""j.IJj COMPANY DETAILS BP Amoco ANTI-COLLISION SETTINGS 50.00 11529.82 Plan: 15-08C wp03 Interva To: Reference: Interpolation MethodMD Depth Range From: 9100.00 Maximum Range: 135028 SECTION DETAILS Sa: MD file An 1VD +NI-S +Fi-W DLeg TFace VSa: T a¡get 1 9100.00 5325 2655 857632 1409.56 889.72 0.00 0.00 1191.09 2 9120.00 53.70 23.62 858822 1424.11 89653 12.00 -80.00 1209.94 3 9632.70 84.88 31250 8189.97 1842.06 774.(1) 14.00 -82.81 1644.00 4 9756.05 84.88 31250 8800.98 1925.07 684.11 0.00 0.00 1743.81 < 9801.01 901JO 308.84 8802.99 195432 650.06 14.00 -35.66 1179.43 15-08C TI Wp 3 6 982633 9152 308.84 8802.65 191020 63034 6.00 0.00 1199.02 7 1026622 9152 308..84 8190.99 2245.97 287.82 0.00 0.00 2139.18 15-08C 1'2 Wp 3 8 10325.41 9057 31226 8189.91 2284.43 242.86 6.00 10552 2186.05 9 11529.82 9057 31226 8117.99 309435 -648,49 0.00 0.00 316157 15-08C n Wp Oft/in] ~ Colour ~, - 90 Cakulation Method: Mininu.Btl Curvature Error System: ISCWSA Scan Method: T"", Cvlitxler North Error Surface: Ellipüeã1 + C1!SÙIg Warning Method: Rules Based From o 9000 9250 9500 9750 10000 10250 10500 10750 11000 11250 11500 WELL DETAILS Nam: +N/-S +J-W Northing Easling Latituœ Longitude Slot J5~8A 1007A1 1{). 82 5959869.01 67732127 70'17'45.144N 148"33'50.6S9W os -320 -300 -250 -200 -150 -100 -SO -0 270 -SO -100 -150 -200 -250 -300 -320 c ) BP Anticollision Report -) Co,"-pªny: 'Da.t~: '6/4/2003 'fitild: . Reference Site: RefèrenceWell: ~efèrence Wellpath: . GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There are TRii:NilèJWJdls in this fRtð1cipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 9100.00 to 11529.82 ft Scan Method: Trav Cylinder North Maximum Radius: 1350.28 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/28/2003 Validated: No Planned From To Survey ft ft 86.99 7386.99 7453.06 9100.00 9100.00 11529.82 Version: 0 Toolcode Tool Name 1 : Sperry-Sun BOSS gyro multi 2 : MWD - Standard (0) Planned: 15-08C wp03 V6 BOSS-GYRO MWD MWD Sperry-Sun BOSS gyro multishot MWD - Standard MWD - Standard Casing Points MD ft 11529.82 TVD ft 8777.99 4.500 6.125 41/2" Summary Reference Offset Ctr-CtrNo-Go Allowable MD MD Distance Area Deviation .. ft ft ft ft ft PB OS 15 15-08 15-08 V1 9325.00 9300.00 712.32 522.78 512.78 Pass: Major Risk PB OS 15 15-08A 15-08A V1 9138.89 9150.00 1.77 0.00 1.76 Pass: NOERRORS PB OS 15 15-08APB 1 15-08APB1 V1 9138.78 9150.00 2.65 0.00 2.65 Pass: NOERRORS PB OS 15 15-08B 15-08B V2 9138.89 9150.00 1.77 0.00 1.76 Pass: NOERRORS PB OS 15 15-08BPB1 15-08BPB1 V2 9138.89 9150.00 1.77 0.00 1.76 Pass: NOERRORS PB OS 15 15-17 15-17 V3 Out of range PB OS 15 15-19A 15-19A V1 11517.41 10150.00 1008.48 181.66 827.02 Pass: Major Risk PB OS 15 15-27 15-27 V1 Out of range PB OS 15 15-39 15-39 V1 11086.93 10823.00 267.97 197.56 70.41 Pass: Major Risk PB OS 15 15-41 15-41 B V3 Out of range PB OS 15 15-43 15-43 V1 9152.92 9600.00 297.98 213.35 152.48 Pass: Major Risk PB OS 15 15-49 15-49A V3 9150.00 11736.00 887.10 255.94 650.20 Pass: Major Risk Site: PB DS 15 Well: 15-08 Rule Assigned: Major Risk Wellpath: 15-08 V1 Inter-Site Error: 0.00 ft Reference ,Offset Semi-Major Axis Ctr~Ct,r. 'No-Go Allowable Wa~ MD TVD MD TVD Ref Offset TFO+AZI., TFO-HS . Casing Distance Area Deviätion ft ft ft ft ,(t ft døg qeg in ft ft ft 9125.00 8591.18 9000.00 8082.39 42.89 137.25 37.77 15.02 7.000 668.01 575.09 539.70 Pass 9165.77 8615.01 9050.00 8112.27 42.17 137.15 35.92 20.10 7.000 669.84 573.96 533.43 Pass 9203.27 8636.33 9100.00 8141.27 41.17 135.94 34.63 25.01 7.000 673.70 566.40 527.00 Pass 9238.21 8655.53 9150.00 8169.31 39.93 134.10 33.77 29.76 7.000 679.87 559.51 521.05 Pass 9270.41 8672.52 9200.00 8196.33 38.55 131.55 33.32 34.30 7.000 688.58 548.67 516.76 Pass 9300.00 8687.45 9250.00 8222.78 37.09 128.66 33.19 38.62 7.000 699.49 535.66 514.09 Pass 9325.00 8699.50 9300.00 8249.05 35.70 125.92 33.52 42.59 7.000 712.32 522.78 512.78 Pass 9350.00 8710.98 9350.00 8275.04 34.19 122.53 33.90 46.52 7.000 727.27 508.78 514.59 Pass 9375.00 8721.84 9400.00 8300.67 32.57 118.39 34.28 50.35 7.000 744.45 492.61 520.52 Pass 9392.79 8729.18 9450.00 8325.67 31.34 116.23 35.18 53.65 7.000 764.15 482.92 527.77 Pass 9410.75 8736.24 9500.00 8349.80 30.05 113.50 35.99 56.84 7.000 786.57 471.22 539.92 Pass 9425.00 8741.58 9550.00 8373.06 29.01 111.54 37.00 59.70 7.000 811.59 462.40 554.98 Pass 9441.67 8747.53 9600.00 8395.42 27.74 108.31 37.68 62.52 7.000 839.03 449.08 576.03 Pass 9450.00 8750.38 9650.00 8416.89 27.10 107.82 38.91 64.81 7.000 868.79 445.71 596.13 Pass 9467.12 8755.97 9700.00 8437.42 25.75 103.76 39.27 67.31 7.000 900.59 429.58 626.20 Pass 9475.00 8758.42 9750.00 8456.54 25.13 103.77 40.23 69.24 7.000 934.55 427.70 652.18 Pass 9488.84 8762.53 9800.00 8473.72 24.01 101.07 40.46 71.18 7.000 970.57 416.30 686.88 Pass 9500.00 8765.67 9850.00 8489.69 23.11 99.55 40.76 72.83 7.000 1007.99 409.07 721.63 Pass 9508.23 8767.88 9900.00 8505.86 22.44 99.12 41.23 74.30 7.000 1045.82 405.69 755.02 Pass 9525.00 8772.10 9950.00 8521.47 21.07 94.50 40.82 75.90 7.000 1084.56 387.82 799.01 Pass ) ) BP Anticollision Report çQD1pany; ~p Amoco Date: "",6/4/2003 Time: 11:52:10 Fiel~; , priJdhoeBay VVØII: 15~QßA, true Nortl1 ªefeteoceSite: ' AB P$ 1'5 Referenc~ Well: .' 15~08A' 57;99'58:0 .. ª~fereÏ1ce \Vellpath: Plan 15~08C Site: PB OS 15 Well: 15-08 Rule Assigned: Major Risk Well path: 15-08 V1 Inter-Site Error: 0.00 ft Reference Offset '.. $cïlii';N1:ajðr1\xìs , ' ct¡'~Ctr·. Nò"Gò AUòwable 1\1D TVD MD TVD :Rë{'·' Offset tFO+AZl TFO-HSCasiog Distance Area DeviatJòo Warni~g ft ft ft ft ft :ft'· deg' . deg , in· ft ft· ft 9525.00 8772.10 10000.00 8535.74 21.07 98.23 41.80 76.88 7.000 1124.38 398.94 826.31 Pass 9533.60 8774.12 10050.00 8548.80 20.38 97.96 41.88 77.97 7.000 1165.28 396.09 863.75 Pass 9541.12 8775.80 10100.00 8560.72 19.77 98.20 41.96 78.93 7.000 1207.04 395.06 901.36 Pass 9550.00 8777.69 10150.00 8571.59 19.06 97.98 41.81 79.82 7.000 1249.52 392.29 941.07 Pass 9550.00 8777.69 10200.00 8581.55 19.06 103.07 42.40 80.42 7.000 1292.61 407.52 969.30 Pass 9561.55 8779.99 10250.00 8591.74 18.17 100.74 41.90 81.26 7.000 1335.85 397.82 1014.68 Pass Site: PB OS 15 Well: 15-08A Rule Assigned: NOERRORS Wellpath: 15-08A V1 Inter-Site Error: 0.00 ft Reference Offset ' "S~m¡~Major Axis .' Ctt~Ctr No"Go Allowable i\1D TVD MD TVD Ref Offset TFO+AZI, TFQ-HSCasing Distanc.e , Area Deviation ft ft ft ft ft ft deg dég in ft ft ft 9138.89 8599.36 9150.00 8610.03 42.68 42.69 96.65 76.28 7.000 1.77 0.00 1.76 Pass 9187.72 8627.57 9200.00 8637.94 41.62 41.64 97.43 85.26 7.000 9.31 0.00 9.31 Pass 9234.65 8653.61 9250.00 8664.62 40.07 40.09 94.61 90.03 7.000 21.18 0.00 21.18 Pass 9278.87 8676.86 9300.00 8688.89 38.15 38.18 89.55 91.81 7.000 37.67 0.00 37.67 Pass 9319.92 8697.10 9350.00 8710.81 35.98 36.04 84.68 93.02 7.000 58.29 0.00 58.29 Pass 9358.01 8714.53 9400.00 8730.38 33.67 33.75 80.05 93.78 7.000 81.78 0.00 81.78 Pass 9392.71 8729.15 9450.00 8747.37 31.34 31.44 75.70 94.16 7.000 108.72 0.00 108.72 Pass 9425.00 8741.58 9500.00 8761.51 29.01 29.11 71.50 94.20 7.000 139.07 0.00 139.07 Pass 9450.00 8750.38 9550.00 8773.30 27.10 27.23 68.07 93.96 7.000 172.49 0.00 172.49 Pass 9475.00 8758.42 9600.00 8782.53 25.13 25.26 64.64 93.66 7.000 208.41 0.00 208.41 Pass 9500.00 8765.67 9650.00 8789.23 23.11 23.23 61.17 93.25 7.000 246.05 0.00 246.04 Pass 9517.75 8770.32 9700.00 8794.27 21.66 21.80 58.48 92.69 7.000 285.10 0.00 285.10 Pass 9535.68 8774.59 9750.00 8798.20 20.21 20.34 55.94 92.28 7.000 325.36 0.00 325.36 Pass 9550.00 8777.69 9800.00 8800.62 19.06 19.20 53.79 91.80 7.000 366.90 0.00 366.90 Pass 9565.82 8780.79 9850.00 8800.95 17.85 17.92 51.44 91.30 7.000 409.66 0.00 409.66 Pass 9575.00 8782.43 9900.00 8799.18 17.15 17.26 49.68 90.60 7.000 453.46 0.00 453.46 Pass 9589.20 8784.72 9950.00 8795.39 16.18 16.17 47.41 89.96 7.000 498.05 0.00 498.05 Pass 9600.00 8786.28 10000.00 8790.95 15.45 15.38 45.57 89.36 7.000 543.53 0.00 543.53 Pass 9608.09 8787.34 10050.00 8788.15 15.02 14.83 44.29 89.00 7.000 589.35 0.00 589.35 Pass 9616.99 8788.39 10100.00 8786.49 14.54 14.28 43.11 88.83 7.000 635.30 0.00 635.30 Pass 9625.00 8789.24 10150.00 8785.52 14.11 13.86 42.11 88.74 7.000 681.07 0.00 681.07 Pass 9635.02 8790.18 10200.00 8783.42 13.81 13.52 41.10 88.59 7.000 727.40 0.00 727.40 Pass 9652.05 8791.70 10250.00 8779.68 13.97 13.63 40.79 88.29 7.000 774.22 0.00 774.22 Pass 9669.94 8793.30 10300.00 8776.24 14.13 13.74 40.54 88.03 7.000 820.77 0.00 820.77 Pass 9687.11 8794.83 10350.00 8774.09 14.29 13.84 40.40 87.89 7.000 867.69 0.00 867.69 Pass 9704.71 8796.40 10400.00 8771.99 14.45 13.95 40.27 87.77 7.000 914.44 0.00 914.44 Pass 9722.74 8798.01 10450.00 8770.12 14.63 14.07 40.17 87.67 7.000 961.05 0.00 961.05 Pass 9742.60 8799.78 10500.00 8769.37 14.83 14.20 40.14 87.63 7.000 1006.91 0.00 1006.91 Pass 9756.05 8800.98 10550.00 8767.35 14.96 14.36 40.02 87.52 7.000 1052.28 0.00 1052.28 Pass 9767.57 8801.88 10600.00 8765.02 14.75 14.04 39.06 87.50 7.000 1097.86 0.00 1097.86 Pass 9775.00 8802.32 10650.00 8763.94 14.61 13.94 38.47 87.51 7.000 1143.28 0.00 1143.27 Pass 9784.14 8802.71 10700.00 8763.60 14.52 13.86 37.79 87.58 1188.68 No Reference Casings 9789.82 8802.87 10736.07 8763.41 14.46 13.86 37.38 87.63 1221.56 No Reference Casings ) ) BP Anticollision Report , .. 6/4/2003 11::52:10, . (¡;OÔlpany: BP Amoco Thne: "Fiehl: .F'f1J~hpaBay , , . RêferenceSi~e: PElpS15 .,'Jler~rence'Well: 15~08A , Referenëe",eUpatb: Plán15--08C ., Site: PB OS 15 Well: 15-08APB 1 Rule Assigned: NOERRORS Wellpath: 15-08APB1 V1 Inter-Site Error: 0.00 ft Rêference Offset , , Semi.;MåjprAXis , " ," " . , ., ., . Ctr-Ctr No~Go lVÏD · rYD Mil .1'\1» Ref ,,', Offset TFO-tAZITFÒ4iSCasing Distance Ar¢a. , ft 1t ft ft ff ff deg deg in ft ft 9138.78 8599.30 9150.00 8609.80 42.68 42.73 96.71 76.32 7.000 2.65 0.00 Pass 9187.51 8627.45 9200.00 8637.65 41.63 41.69 96.66 84.46 7.000 10.21 0.00 Pass 9233.99 8653.25 9250.00 8663.55 40.09 40.16 92.62 87.94 7.000 23.34 0.00 Pass 9277.14 8675.98 9300.00 8687.11 38.24 38.31 88.19 90.19 7.000 42.08 0.00 Pass 9316.67 8695.55 9350.00 8707.99 36.16 36.26 83.56 91.43 7.000 65.21 0.00 Pass 9352.67 8712.17 9400.00 8727.10 34.02 34.13 79.74 92.74 7.000 91.84 0.00 91.83 Pass 9385.26 8726.12 9450.00 8744.21 31.86 31.99 76.21 93.67 7.000 121.39 0.00 121.39 Pass 9414.50 8737.67 9500.00 8759.36 29.78 29.93 72.97 94.30 7.000 153.70 0.00 153.70 Pass 9441.28 8747.40 9550.00 8772.83 27.77 27.93 69.92 94.71 7.000 187.50 0.00 187.50 Pass 9465.73 8755.53 9600.00 8784.96 25.86 26.03 67.13 95.00 7.000 222.78 0.00 222.78 Pass 9487.70 8762.20 9650.00 8795.60 24.10 24.27 64.59 95.17 7.000 259.88 0.00 259.87 Pass 9507.55 8767.70 9700.00 8804.83 22.49 22.65 62.22 95.21 7.000 298.38 0.00 298.38 Pass 9525.00 8772.10 9750.00 8812.47 21.07 21.22 60.03 95.11 7.000 338.39 0.00 338.39 Pass 9541.75 8775.94 9800.00 8819.28 19.72 19.84 57.96 95.01 7.000 378.99 0.00 378.99 Pass 9550.00 8777.69 9821.07 8821.89 19.06 19.15 56.99 95.01 396.37 No Reference Casings Site: PB OS 15 Well: 15-08B Rule Assigned: NOERRORS Wellpath: 15-08B V2 Inter-Site Error: 0.00 ft Reference Offset Semi~Major Axis Ctr,;,Ctr' No~Go Allowable MD rVD MD rVD Ref Offset TFOfAZl TFO,;,HS Casing Distance Area·'·' , Deviation ft ft ft ft ft ft deg deg in ft ft ' ft 9138.89 8599.36 9150.00 8610.03 42.68 91.11 96.65 76.28 7.000 1.77 0.00 1.76 Pass 9187.72 8627.57 9200.00 8637.94 41.62 92.04 97.43 85.26 7.000 9.31 0.00 9.31 Pass 9234.65 8653.61 9250.00 8664.62 40.07 91.95 94.61 90.03 7.000 21.18 0.00 21.18 Pass 9278.87 8676.86 9300.00 8688.89 38.15 91.21 89.55 91.81 7.000 37.67 0.00 37.67 Pass 9319.92 8697.10 9350.00 8710.81 35.98 90.13 84.68 93.02 7.000 58.29 0.00 58.29 Pass 9358.01 8714.53 9400.00 8730.38 33.67 88.90 80.05 93.78 7.000 81.78 0.00 81.78 Pass 9392.71 8729.15 9450.00 8747.37 31.34 87.97 75.70 94.16 7.000 108.72 0.00 108.72 Pass 9425.00 8741.58 9500.00 8761.51 29.01 87.47 71.50 94.20 7.000 139.07 0.00 139.07 Pass 9450.00 8750.38 9550.00 8773.30 27.10 88.89 68.07 93.96 7.000 172.49 0.00 172.49 Pass 9475.00 8758.42 9600.00 8782.53 25.13 91.10 64.64 93.66 7.000 208.41 0.00 208.41 Pass 9500.00 8765.67 9650.00 8789.23 23.11 95.40 61.17 93.25 7.000 246.05 0.00 246.04 Pass 9517.75 8770.32 9700.00 8794.27 21.66 104.21 58.48 92.69 7.000 285.10 0.00 285.10 Pass 9535.68 8774.59 9750.00 8798.20 20.21 115.26 55.94 92.28 7.000 325.36 0.00 325.36 Pass 9550.00 8777.69 9800.00 8800.62 19.06 120.81 53.79 91.80 7.000 366.90 0.00 366.90 Pass 9565.82 8780.79 9850.00 8800.95 17.85 117.10 51.44 91.30 7.000 409.66 0.00 409.66 Pass 9575.00 8782.43 9900.00 8799.18 17.15 116.41 49.68 90.60 7.000 453.46 0.00 453.46 Pass 9589.20 8784.72 9950.00 8795.39 16.18 103.31 47.41 89.96 7.000 498.05 0.00 498.05 Pass 9600.00 8786.28 10000.00 8790.95 15.45 86.03 45.57 89.36 7.000 543.53 0.00 543.53 Pass 9608.09 8787.34 10050.00 8788.15 15.02 63.85 44.29 89.00 7.000 589.35 0.00 589.35 Pass 9616.99 8788.39 10100.00 8786.49 14.54 28.75 43.11 88.83 7.000 635.30 0.00 635.30 Pass 9625.00 8789.24 10150.00 8785.52 14.11 29.48 42.11 88.74 7.000 681.07 0.00 681.07 Pass 9635.02 8790.18 10200.00 8783.42 13.81 53.38 41.10 88.59 7.000 727.40 0.00 727.40 Pass 9652.05 8791.70 10250.00 8779.68 13.97 65.43 40.79 88.29 7.000 774.22 0.00 774.22 Pass 9669.94 8793.30 10300.00 8776.24 14.13 79.44 40.54 88.03 7.000 820.77 0.00 820.77 Pass 9687.11 8794.83 10350.00 8774.09 14.29 100.40 40.40 87.89 7.000 867.69 0.00 867.69 Pass 9704.72 8796.40 10400.00 8771.99 14.45 122.63 40.27 87.77 7.000 914.44 0.00 914.44 Pass 9722.74 8798.01 10450.00 8770.12 14.63 150.74 40.17 87.67 7.000 961.05 0.00 961.05 Pass 9742.60 8799.78 10500.00 8769.37 14.83 227.37 40.14 87.63 7.000 1006.91 0.00 1006.91 Pass 9756.05 8800.98 10550.00 8767.35 14.96 267.99 40.02 87.52 7.000 1052.28 0.00 1052.28 Pass 9767.57 8801.88 10600.00 8765.02 14.75 280.66 39.06 87.50 7.000 1097.86 0.00 1097.85 Pass ') ) BP Anticollision Report , CQlJ1påny: Time:. , 11:52:1 Ö Eiél~: ªe~êrënceSite: Co-mJ~¡~!1t~(~)J;r[{~fel"ence: ' 'Reference 'Wêu: V¢rt.i~al(TVJ:)R.èferënëe: ' :Reference 'Welipath: '. Site: PB DS 15 Well: 15-08B Rule Assigned: NO ERRORS Well path: 15-08B V2 Inter-Site Error: 0.00 ft Reference , .. ....... . ... Ctr-Ctr ,N()~Go Allbwablê Offset Sel'tli-MaJorAx.is ",.' . ',.' ,., .' ",' ,',' ",. MD TVD MD TVjj Ref Offset 1;FO+AZITF'O.,HS' Casing Distance· Area · Deviåtiort ft ft ft ft ft 'ft >deg' ' '" '·deg·· ' · in .. " ft ft' ft 9775.00 8802.32 10650.00 8763.94 14.61 332.76 38.47 87.51 7.000 1143.28 0.00 1143.27 Pass 9784.14 8802.71 10700.00 8763.60 14.52 485.67 37.79 87.58 7.000 1188.68 0.00 1188.68 Pass 9792.07 8802.91 10750.00 8763.37 14.44 627.33 37.22 87.65 7.000 1234.15 0.00 1234.15 Pass 9801.01 8802.99 10800.00 8763.49 14.35 700.99 36.57 87.74 1278.24 0.00 1278.24 Pass 9829.99 8802.56 10850.00 8763.65 14.79 706.26 36.67 87.83 1319.48 No Reference Casings 10357.34 8789.60 11350.00 8767.74 22.55 807.96 40.84 88.58 1324.52 No Reference Casings 10396.51 8789.21 11400.00 8769.11 23.09 807.96 40.88 88.62 1293.48 No Reference Casings 10434.65 8788.83 11450.00 8772.49 23.64 807.97 41.02 88.76 1261.31 No Reference Casings 10469.96 8788.48 11500.00 8776.43 24.15 807.98 41.18 88.92 1226.10 No Reference Casings 10504.96 8788.13 11550.00 8777.71 24.66 807.98 41.23 88.97 1190.41 No Reference Casings 10540.82 8787.78 11600.00 8777.92 25.19 807.99 41.22 88.97 1155.58 No Reference Casings 10575.55 8787.44 11650.00 8778.67 25.70 808.00 41.25 88.99 1119.62 No Reference Casings 10607.98 8787.12 11700.00 8779.07 26.18 808.00 41.25 88.99 1081.57 No Reference Casings 10638.82 8786.81 11750.00 8780.46 26.64 808.01 41.31 89.05 1042.24 No Reference Casings 10666.79 8786.53 11800.00 8782.00 27.06 808.02 41.37 89.11 1000.82 No Reference Casings 10692.46 8786.28 11850.00 8781.76 27.45 808.02 41.33 89.07 957.93 No Reference Casings 10717.17 8786.03 11900.00 8780.55 27.82 808.03 41.23 88.97 914.50 No Reference Casings 10743.47 8785.77 11950.00 8781.28 28.22 808.04 41.24 88.98 872.01 No Reference Casings 10774.42 8785.47 12000.00 8780.26 28.69 808.05 41.14 88.88 832.79 No Reference Casings 10807.73 8785.14 12050.00 8777.87 29.20 808.05 40.94 88.68 795.62 No Reference Casings 10842.60 8784.79 12100.00 8776.50 29.74 808.06 40.80 88.54 759.84 No Reference Casings 10876.95 8784.45 12150.00 8776.85 30.27 808.08 40.79 88.53 723.51 No Reference Casings 10912.92 8784.10 12200.00 8775.53 30.82 808.09 40.63 88.37 688.86 No Reference Casings 10950.44 8783.73 12250.00 8772.52 31.41 808.10 40.32 88.06 656.02 No Reference Casings 10989.28 8783.34 12300.00 8768.46 32.01 808.11 39.89 87.63 624.91 No Reference Casings 11029.64 8782.94 12350.00 8766.93 32.64 808.13 39.66 87.40 595.51 No Reference Casings 11069.43 8782.55 12400.00 8768.39 33.27 808.14 39.71 87.45 565.26 No Reference Casings 11108.38 8782.16 12450.00 8770.58 33.88 808.16 39.83 87.57 533.94 No Reference Casings 11145.35 8781.80 12500.00 8772.21 34.46 808.17 39.90 87.64 500.29 No Reference Casings 11180.67 8781.45 12550.00 8773.30 35.02 808.19 39.90 87.64 464.90 No Reference Casings 11214.73 8781.11 12600.00 8774.40 35.56 808.20 39.89 87.63 428.31 No Reference Casings 11235.51 8780.90 12628.00 8774.62 35.89 808.21 39.84 87.58 409.55 No Reference Casings Site: PB DS 15 Well: 15-08BPB1 Rule Assigned: NOERRORS Wellpath: 15-08BPB 1 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr·..,.·No..Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS, Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft 9138.89 8599.36 9150.00 8610.03 42.68 91.11 96.65 76.28 7.000 1.77 0.00 1.76 Pass 9187.72 8627.57 9200.00 8637.94 41.62 92.04 97.43 85.26 7.000 9.31 0.00 9.31 Pass 9234.65 8653.61 9250.00 8664.62 40.07 91.95 94.61 90.03 7.000 21.18 0.00 21.18 Pass 9278.87 8676.86 9300.00 8688.89 38.15 91.21 89.55 91.81 7.000 37.67 0.00 37.67 Pass 9319.92 8697.10 9350.00 8710.81 35.98 90.13 84.68 93.02 7.000 58.29 0.00 58.29 Pass 9358.01 8714.53 9400.00 8730.38 33.67 88.90 80.05 93.78 7.000 81.78 0.00 81.78 Pass 9392.71 8729.15 9450.00 8747.37 31.34 87.97 75.70 94.16 7.000 108.72 0.00 108.72 Pass 9425.00 8741.58 9500.00 8761.51 29.01 87.47 71.50 94.20 7.000 139.07 0.00 139.07 Pass 9450.00 8750.38 9550.00 8773.30 27.10 88.89 68.07 93.96 7.000 172.49 0.00 172.49 Pass 9475.00 8758.42 9600.00 8782.53 25.13 91.10 64.64 93.66 7.000 208.41 0.00 208.41 Pass 9500.00 8765.67 9650.00 8789.23 23.11 95.40 61.17 93.25 7.000 246.05 0.00 246.04 Pass 9517.75 8770.32 9700.00 8794.27 21.66 104.21 58.48 92.69 7.000 285.10 0.00 285.10 Pass 9535.68 8774.59 9750.00 8798.20 20.21 115.26 55.94 92.28 7.000 325.36 0.00 325.36 Pass ) ') BP Anticollision Report CODJpany: BpAm.oco Date: ,.,'·6/4/2003 ,Thne;" 11:52:10 ,Field:, . Prudhoe l3åy "qþ~pt()j~a~e(~E:rRef~rencê: Re(êrençe Sit~: PBD$15 Re'e·rençe,\Velk . 15~P8A " , , ··'Yêrtic~IJ'I'VI) Ji{eferel1ce: Rèferel1ëe \VeïIPlith: .' Plan 1S+08C Site: PB DS 15 Well: 15-08BPB1 Rule Assigned: NO ERRORS Wellpath: 15-08BPB1 V2 Inter-Site Error: 0.00 ft Referenê~" , 'Offset ~eP1HViajprÅXis., ","" Ctr-;ctr·.' No';Go f\lIôwable MD' ' TV]) MD TVD Ref ()ffset " TF'0'¡'AZI TFO~HSCasilÏg ,. I>iStånce Are~ Deviation' , .' ft ft ft ft ff. ft .,. ;deg .. :deg '·in' ,ft ft· · ft 9550.00 8777.69 9800.00 8800.62 19.06 120.81 53.79 91.80 7.000 366.90 0.00 366.90 Pass 9565.82 8780.79 9850.00 8800.95 17.85 117.10 51.44 91.30 7.000 409.66 0.00 409.66 Pass 9575.00 8782.43 9900.00 8799.18 17.15 116.41 49.68 90.60 7.000 453.46 0.00 453.46 Pass 9589.20 8784.72 9950.00 8795.39 16.18 103.31 47.41 89.96 7.000 498.05 0.00 498.05 Pass 9600.00 8786.28 10000.00 8790.95 15.45 86.03 45.57 89.36 7.000 543.53 0.00 543.53 Pass 9608.09 8787.34 10050.00 8788.15 15.02 63.85 44.29 89.00 7.000 589.35 0.00 589.35 Pass 9616.99 8788.39 10100.00 8786.49 14.54 28.75 43.11 88.83 7.000 635.30 0.00 635.30 Pass 9625.00 8789.24 10150.00 8785.52 14.11 29.48 42.11 88.74 7.000 681.07 0.00 681.07 Pass 9635.02 8790.18 10200.00 8783.42 13.81 53.38 41.10 88.59 7.000 727.40 0.00 727.40 Pass 9652.05 8791.70 10250.00 8779.68 13.97 65.43 40.79 88.29 7.000 774.22 0.00 774.22 Pass 9669.94 8793.30 10300.00 8776.24 14.13 79.44 40.54 88.03 7.000 820.77 0.00 820.77 Pass 9687.11 8794.83 10350.00 8774.09 14.29 100.40 40.40 87.89 7.000 867.69 0.00 867.69 Pass 9704.72 8796.40 10400.00 8771.99 14.45 122.63 40.27 87.77 7.000 914.44 0.00 914.44 Pass 9722.74 8798.01 10450.00 8770.12 14.63 150.74 40.17 87.67 7.000 961.05 0.00 961.05 Pass 9742.60 8799.78 10500.00 8769.37 14.83 227.37 40.14 87.63 7.000 1006.91 0.00 1006.91 Pass 9756.05 8800.98 10550.00 8767.35 14.96 267.99 40.02 87.52 7.000 1052.28 0.00 1052.28 Pass 9767.57 8801.88 10600.00 8765.02 14.75 280.66 39.06 87.50 7.000 1097.86 0.00 1097.85 Pass 9775.00 8802.32 10650.00 8764.12 14.61 373.03 38.48 87.52 7.000 1143.22 0.00 1143.22 Pass 9784.19 8802.71 10700.00 8763.78 14.52 532.54 37.80 87.59 7.000 1188.62 0.00 1188.62 Pass 9791.99 8802.91 10750.00 8763.59 14.44 659.79 37.23 87.66 1234.25 No Reference Casings 9801.01 8802.99 10800.00 8763.78 14.35 638.87 36.59 87.75 1278.64 No Reference Casings 9829.14 8802.58 10850.00 8763.94 14.78 640.28 36.68 87.84 1319.88 No Reference Casings 10360.95 8789.56 11350.00 8765.47 22.60 732.94 40.75 88.49 1331.44 No Reference Casings 10401.37 8789.16 11400.00 8769.20 23.16 732.95 40.90 88.64 1302.21 No Reference Casings 10439.53 8788.78 11450.00 8772.25 23.71 732.96 41.02 88.76 1270.04 No Reference Casings 10476.29 8788.42 11500.00 8773.26 24.24 732.97 41.05 88.79 1236.16 No Reference Casings 10512.05 8788.06 11550.00 8775.25 24.76 732.97 41.12 88.86 1201.26 No Reference Casings 10546.54 8787.72 11600.00 8779.26 25.27 732.98 41.30 89.04 1165.26 No Reference Casings 10578.67 8787.41 11650.00 8784.32 25.75 732.99 41.54 89.28 1127.27 No Reference Casings 10607.70 8787.12 11700.00 8789.85 26.18 733.00 41.82 89.56 1086.94 No Reference Casings 10633.56 8786.86 11750.00 8794.11 26.57 733.00 42.05 89.79 1044.37 No Reference Casings 10659.29 8786.61 11800.00 8797.76 26.95 733.01 42.27 90.01 1001.67 No Reference Casings 10684.82 8786.35 11850.00 8799.37 27.33 733.02 42.38 90.12 958.73 No Reference Casings 10711.10 8786.09 11900.00 8799.51 27.73 733.02 42.41 90.15 916.20 No Reference Casings 10740.79 8785.80 11950.00 8799.38 28.18 733.03 42.43 90.17 876.01 No Reference Casings 10774.06 8785.47 12000.00 8799.09 28.69 733.04 42.44 90.18 838.69 No Reference Casings 10806.84 8785.15 12050.00 8797.57 29.19 733.05 42.36 90.10 800.98 No Reference Casings 10830.30 8784.91 12088.00 8795.51 29.55 733.06 42.23 89.97 771.14 No Reference Casings Site: PB DS 15 Well: 15-19A Rule Assigned: Major Risk Wellpath: 15-19A V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No..,Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance' Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11449.91 8778.78 9800.00 8843.05 39.32 7.49 219.82 267.56 1347.47 177.39 1170.15 Pass 11453.29 8778.75 9850.00 8840.34 39.37 7.50 219.85 267.59 1297.60 177.62 1120.04 Pass 11458.84 8778.69 9900.00 8838.75 39.46 7.50 219.82 267.56 1247.93 177.97 1070.03 Pass 11464.75 8778.63 9950.00 8840.50 39.56 7.51 219.64 267.38 1198.46 178.34 1020.20 Pass 11470.50 8778.58 10000.00 8844.26 39.65 7.52 219.33 267.07 1149.25 178.71 970.65 Pass 11483.25 8778.45 10050.00 8851.17 39.85 7.54 218.84 266.58 1101.90 179.46 922.61 Pass ) ) BP Anticollision Report ,Ç~D1pafiY: BPAmoco Date: ' .' 6/4/200;3 Titne: .11:52:10 , Field: Pruclhoe, Bay . . ~fiter~nçe Site: PBDS 15 C().,Qtdi~ate(~~)~e~el'~nce: · ßefer¢nc¢WeU: ,. 15-08A , Vertical (TV))) lt~(erence: · .Db:" ()rä¢le. ~ërereÏJcë Wellþåth: Plan 15~OaC Site: PB OS 15 Well: 15-19A Rule Assigned: Major Risk Well path: 15-19A V1 Inter-Site Error: 0.00 ft Refèrence Offset S!,m.i-lV(~or Axis Ctr-ctr . No';'Go Allowable Mil TVD MD TVD Ref prfset TFO+AZIJ:FO-HSCasing .. Distance Areå Deviation ft ft ft ft'· ft ,Lft ' deg .,deg in ft ft ft, 11498.35 8778.30 10100.00 8854.04 40.10 7.59 218.52 266.26 1054.65 180.37 874.48 Pass 11517.41 8778.11 10150.00 8852.35 40.40 7.64 218.44 266.18 1008.48 181.66 827.02 Pass Site: PB OS 15 Well: 15-39 Rule Assigned: Major Risk Wellpath: 15-39 V1 Inter-Site Error: 0.00 ft .' . ' Referëlic~ " . . '.. . Offset SeD1i-MajorAxis " ... Ctr~Ctr ·,No..Go. Allowable MD ' TVO MD TVD ;R.et ' "Offse~ TFO,¡,AZI TFQ.,HSCasi..g ·.Dist¡m~eA.rea , Diwiation (t ft ft ft ft ft deg" ""'deg , "in ft ft ' ft 10152.74 8794.00 9350.00 8889.44 18.66 7.52 215.11 266.27 1344.63 114.56 1233.28 Pass 10181.87 8793.23 9400.00 8884.53 19.04 7.89 215.18 266.34 1304.02 116.84 1190.39 Pass 10210.71 8792.46 9450.00 8879.10 19.43 8.26 215.27 266.43 1263.23 118.76 1147.32 Pass 10239.62 8791.70 9500.00 8873.26 19.83 8.65 215.39 266.55 1222.52 121.16 1104.21 Pass 10266.22 8790.99 9550.00 8867.47 20.19 8.99 215.51 266.68 1181.95 123.11 1061.51 Pass 10281.23 8790.62 9600.00 8863.99 20.67 9.43 216.43 266.72 1141.82 125.84 1018.58 Pass 10300.00 8790.25 9650.00 8863.35 21.26 9.96 217.42 266.63 1102.57 129.19 975.87 Pass 10311.40 8790.08 9700.00 8863.09 21.64 10.52 217.95 266.50 1064.44 131.88 934.86 Pass 10329.88 8789.87 9750.00 8859.99 22.17 11.19 218.79 266.54 1026.90 135.03 893.69 Pass 10363.31 8789.54 9800.00 8855.12 22.63 11.68 218.93 266.67 989.79 137.90 853.73 Pass 10396.93 8789.20 9850.00 8849.27 23.10 12.13 219.13 266.87 952.94 140.69 814.11 Pass 10430.87 8788.87 9900.00 8844.41 23.59 12.51 219.29 267.03 916.31 142.76 774.90 Pass 10465.06 8788.53 9950.00 8839.97 24.08 12.89 219.43 267.17 879.91 145.42 735.85 Pass 10499.61 8788.19 10000.00 8836.84 24.58 13.28 219.50 267.24 843.77 148.10 697.05 Pass 10534.51 8787.84 10050.00 8833.55 25.10 13.74 219.59 267.33 808.00 150.50 658.35 Pass 10569.63 8787.49 10100.00 8831.54 25.61 14.14 219.59 267.33 772.41 153.27 620.00 Pass 10604.76 8787.15 10150.00 8830.25 26.13 14.58 219.53 267.27 736.84 155.64 581.53 Pass 10640.32 8786.79 10200.00 8829.96 26.67 15.03 219.39 267.13 701.74 158.61 543.46 Pass 10676.03 8786.44 10250.00 8830.35 27.20 15.49 219.18 266.92 666.84 161.63 505.55 Pass 10711.54 8786.09 10300.00 8828.34 27.74 16.00 219.16 266.90 631.65 164.25 467.22 Pass 10746.92 8785.74 10350.00 8824.25 28.28 16.51 219.33 267.07 596.37 167.40 428.81 Pass 10782.34 8785.39 10400.01 8819.69 28.81 16.98 219.58 267.32 561.15 170.47 390.56 Pass 10818.48 8785.03 10450.00 8817.07 29.37 17.41 219.65 267.39 526.63 173.72 352.78 Pass 10854.33 8784.68 10500.00 8815.27 29.92 17.83 219.63 267.37 491.77 176.58 315.06 Pass 10890.11 8784.32 10550.00 8815.17 30.47 18.26 219.40 267.14 456.91 179.47 277.31 Pass 10926.14 8783.97 10600.00 8814.87 31.03 18.77 219.16 266.90 422.29 183.19 238.99 Pass 10961.96 8783.61 10650.00 8813.91 31.59 19.25 218.97 266.71 387.43 186.24 201.09 Pass 10998.26 8783.25 10700.00 8813.71 32.15 19.72 218.62 266.36 353.12 189.27 163.77 Pass 11034.65 8782.89 10750.00 8813.06 32.72 20.22 218.28 266.02 318.88 192.98 125.86 Pass 11070.57 8782.54 10800.00 8811.47 33.29 20.73 218.05 265.79 284.13 196.12 87.99 Pass 11086.93 8782.37 10823.00 8810.42 33.54 20.96 217.98 265.72 267.97 197.56 70.41 Pass Site: PB OS 15 Well: 15-43 Rule Assigned: Major Risk Wellpath: 15-43 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9126.66 8592.16 9150.00 8766.60 42.87 18.36 261.00 238.53 390.73 215.51 228.44 Pass 9196.94 8632.78 9200.00 8796.30 41.37 16.23 250.22 239.57 367.12 202.04 219.87 Pass 9226.47 8649.15 9250.00 8821.69 40.39 15.48 241.35 235.47 342.66 195.75 206.21 Pass 9234.10 8653.31 9300.00 8841.76 40.09 15.50 233.10 228.43 320.24 194.03 193.10 Pass 9229.14 8650.61 9350.00 8853.92 40.29 15.96 225.07 219.62 299.49 195.58 181.64 Pass ') ) BP Anticollision Report , CQl1lpany: EW.Arnoco Field:, prµdho~E3ay ~eretenceSite: PBDS.15 ' .R:e(erenceVveJl:15.:ÖâÄ ,.'R,ê(etenceW e~lpatl1;AIEÜi t5~08C Site: PB DS 15 Well: 15-43 Wellpath: 15-43 V1 Reference 1\1D tVD ft ft 9216.53 8643.70 9197.62 8633.16 9178.34 8622.22 9164.08 8614.03 9152.92 8607.56 Date: .., ,6/4/2003 $enlÎ.:Måjor AXis· '..'. .. .." '. ..'., .", ,.,; ..',' ..... .", ,'... '. '.,.. ;" Ref' '()ffse~ T:FQ4;AZÏ. ¡..-ø"lISCasing ftft, degdeg,in· 40.73 16.68 217.04 209.57 41.35 17.58 208.88 198.34 41.88 18.47 200.48 186.76 42.21 19.18 191.86 175.76 42.45 19.80 183.79 165.80 Rule Assigned: Inter-Site Error: Ct~~Gtr ·,.NØ-Gò ' Distance. Area 'ft ·ft ' 280.78 198.96 270.20 203.61 270.04 207.86 280.33 210.77 297.98 213.35 " Offset · . MD TV!)' ft ft, 9400.00 8857.13 9450.00 8855.06 9500.00 8852.06 9550.00 8852.02 9600.00 8852.29 9143.27 8601.92 9650.00 8851.77 42.61 20.38 176.67 157.04 321.51 215.46 9132.79 8595.78 9700.00 8850.05 42.77 20.96 171.00 149.59 350.64 217.60 9120.00 8588.22 9750.00 8847.97 42.95 21.59 167.08 143.47 384.87 220.04 9107.90 8581.04 9800.00 8848.28 43.04 22.13 164.53 139.15 423.82 221.83 Site: PB DS 15 Well: 15-49 Rule Assigned: Well path: 15-49A V3 Inter-Site Error: Reference Offset SelDi~Major Axis Ctr~CtrNo-Go MD TVD ' MD TVD "Ref Offset TFO+AZITFO~HSCåsing Distance Area ft ft ft ft ft ft deg deg in ft ft 9125.00 8591.18 11250.00 8789.23 42.89 35.35 122.49 99.73 1336.29 264.36 9125.00 8591.18 11300.00 8783.86 42.89 35.18 123.04 100.29 1290.39 264.08 9120.00 8588.22 11350.00 8778.23 42.95 35.36 123.80 100.19 1242.31 265.36 9120.00 8588.22 11400.00 8776.38 42.95 35.24 124.20 100.58 1193.14 265.19 9122.16 8589.50 11450.00 8775.73 42.93 35.02 124.30 101.06 1143.67 264.45 9125.00 8591.18 11500.00 8774.89 42.89 34.78 124.14 101.38 1094.89 263.57 9125.00 8591.18 11550.00 8773.52 42.89 34.75 123.89 101.13 1048.05 263.57 9135.58 8597.42 11600.00 8773.28 42.73 34.08 122.78 101.84 1003.02 260.33 9150.00 8605.86 11650.00 8773.28 42.51 33.21 121.24 102.76 960.33 255.74 9150.00 8605.86 11700.00 8772.59 42.51 33.20 120.66 102.17 917.63 255.86 9150.00 8605.86 11736.00 8771.84 42.51 33.20 120.20 '101.72 887.10 255.94 Major Risk 0.00 ft Áïïowåble Deviation Wärning " ·ft 172.08 Pass 167.66 Pass 162.17 Pass 154.79 Pass 152.48 Pass 158.55 Pass 173.96 Pass 198.01 Pass 230.23 Pass Major Risk 0.00 ft Allowable Deviation Warning ft 1092.77 Pass 1046.64 Pass 996.93 Pass 947.53 Pass 898.49 Pass 850.40 Pass 803.53 Pass 761.62 Pass 723.25 Pass 680.64 Pass 650.20 Pass --/ ~ N;VALlÓ~;2{~~~~~:;~ji~:'~'~~¡·~;~¡t;'~~}:~Cq , "~'I~'A. ....., ..... ,,- ........ .¿!? ~..:~·:::t~l~,~;:~¡;~~~i;~i:::~:¿:\:i, ***:~("*$100 .00******* AMOUNT CONSOLIDATED COMMERCIAL ACCOUNT 5~389 412 No.POS5086 1110 5 SOB b III I: 0'" . 2 0 :ì B g 51: O. 2 7 B Ii b III DATE·'···.· Jurìé9,-éQØ3 A\as¡(a on ,s\ t\nchorage jUL {) 2 7.003 D~f¡o/'-~·r- r'\, r: \",,~f ~:: H NET VENDOR DISCOUNT CHECK NO. 055086 DATE 6/9/2003 ALASKA OIL & GAS CONSERVATION CQMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGI;, AK 99501-3539 .NATIONALCITV BANK Ashland. Ohio \s~ æ C, GROSS B fJ.,.·,·.·· rr.'",.,::).....,.. tl..."./~n'1,·"..,..fd,"I , tf") 1.;'(. ' ." '.. . t.l, " H' ' .... ._ '.. i.1 ....IUP ,~fW·..m'" TO THE ORDER OF: PAY: BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. PERMIT TO DRILL =EE INV# CK060403F DESCRIPTION INVOICE I CREDIT MEMO 6/9/2003 DATE p055086 ) ) TRANSMIT AL LETTER CHECK'LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME r?ð¿¿ IS- -DB é, , '2-03 -' IZ( PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production, should continue to be reported as a function' of the original API number, stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing ,exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ,:y!EIi§~:~§~!It9~§£~~~!~ Company BP EXPLORATION (ALASKA) INC Well Name: ~DHOE BAY UNIT 15-08C Program DEV Well bore seg PTD#:2031210 Field & Pool PRUDHOF BAY, PRUDHOF 011 - 640150 Initial Class/Type DFV I 1-01l GeoArea 890 Unit 11650 On/OffShore ~ Annular Disposal Administration 1 Pe(mit fee attache.d. . . _ _ _ _ _ _ _ . . . . . . _ _ _ . _ . . . . . . _ _ _ . _ . _ . . . _ . _ . . . . . .Yes. . . . . . _ . _ _ . .. _ . . . . _ . _ _ _ . _ _ _ . . . . . . . . . . . . . . . . . . . . . .. . . . _ , . . . _ . . . _ .. . _ . . _ . _ _ _ . _ . .. 2 .Lease_number .apRrORripte. . . . . . . _ _ _ . . _ . . _ . . _ _ _ _ _ _ . . . . . . . _ . . . . . . . . _ .Ye$. . _ _ . _ _ . . . . . . . . _ . . . . . . . _ . _ _ . _ _ . _ _ _ _ _ _ . _ . _ . _ _ _ _ _ _ . _ _ . _ _ . . . . . _ . . . . _ _ . . . _ . . . . . 3 _U.nlque welt n.arn.e _a[1d Ol!.mb.er _ . _ _ _ . . _ . _ . . _ _ _ _ _ . _ _ . . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ . . . . _ . . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ . _ _ _ _ . _ . . . . . _ . . . . . . _ . _ _ . .. . . _ . . . . .. _ _ _ _ 4 .WelUQcated in.a.define.d_ppol. _ . . . . . . . . _ . . . . . . . _ _ _ _ _ _ . . _ . . . _ . _ . . . _ . . .Yes . . . . . . . _ _ _ _ _ . _ . . . . _ . _ . . . . . . . . . . . . . . . . . . . . . . _ . . . _ _ . . . . . _ _ . . _ _ . . _ . _ _ . . . _ . _ _ . _ 5 .We.IUQcated pr.oper .distance. from drUling Ullilb.oulld.a(y_ . . . . . . . . . . _ . _ .. . . _ _ _ . _ _ _ _Yes _ . . . . . . . . . . . . . . _ . _ . .. _ . _ . . _ . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . 6 .We.IIJQcated pr.oper .distance. from otbe.r wells. . . . . _ . . . . . . . . . . . . . . . . . . . . . . .. . .Yes.. _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . _ .. . _ . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . 7 .S_ufficiellt .acreaQ.e.ayailpble in.driLlioQ. unjL _ . . . . . . . . . . . . _ _ _ _ _ . . . . . . . . . . . . . .Yes. _ . _ . _ _ _ _ . . . . . ,. _ . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . _ _ . .. _ . _ .. _ _ _ . _ . _ _ _ .... .. _ _ _ .. . . . . 8 Jf.deviated, js_ weJlbQre platjnc.lu_ded _ . _ . . . . . . . . _ _ . . . . . . . . . . _ _ _ _ _ _ . _ _ _ . _ .Yes. . . _ . . . . . . . . . . . . . . . _ .. _ . . . _ _ . _ . . . _ _ . _ . . _ _ . . . . . . . . . . _ . . . . . . . . . . . . . . . . . ,. . . . . . . 9 .Qper:ator only- affected party. . . . . . . . . .. .. . _ . . . . . _ . _ . . . _ . . . _ . . . . . ,. . . . . . .Yes _ . _ . _ . _ _ _ _ _ _ _ . . . . . . . . . . . . . . . . . . .. . . . . . .. . . _ _ .. _ .' _ _ .. .. . . .. . .. . . . . . _ . .. .. .. . .. _ _ _ . _ _ _ . . 10 .Oper:atof bas_a.pprppriateJ~o[1d inJorce. . . . . .. . . _ _ .. . . . .. . . . . . .. _ _ _ _ _ _ _ _ _ . _ . . .Yes. .. . .. .. . . . . _ . . .. . .. . . .. . _ _ _ _ . _ _ _ . _ . . . . . .. . .. . . . . _ . . . .. .. . . . .. . . . . . . . . . . . . .. . . . . . . . . . _ . 11 Pe(mit c.a[1 be i.sSl!.eçl wjtbQut co.nserva..tioll Qrder _ . . . . _ . _ _ . _ _ _ . . _ _ _ . . . _ . . . . . . _Ye$. . . _ _ _ _ . . _ . _ _ . _ _ _ . . . . . . . . . . . . . . . . _ . _ . . _ . _ _ _ .. _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ . . 12 Pe(mit c.ao be lssu.eçl wjtbQut ad.ministr:ativ:e.a.ppr9va.1 _ _ . _ . _ . . . . . . . _ . . .. _ . _ . _ . _ . .Yes. . . . . . . . . . . . . . _ . . . . . . . .. _ _ _ _ _ _ . . . . . . _ . _ _ . . . . _ . . . . . . . . . _ . . _ . . . . . . . . . . . . . . . .. .. . 7/2/2003 13 Can permit be approved before 15-daywait Yes 14 _We.IIJQcated withill area an.d.stratp.authorized by_lojectipo Order: # (put 10# in_cplJ1meots).(For. _NA . . . . . . . . . . . . _ . .. _ . . .. _ .. _ _ . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . _ _ 15 .All welJs_within.1l4_l1Jite_are.a_of (eyiew jdeotified (Fpr: ~ervjc.ß.w.ell OOly). _ _ _ _ _ _ _ _ _ _ _ _ . _ .NA . . . . . . . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . . . . _ . . . . . . . . .. . . . _ . . _ . . _ . . . .. . _ _ _ _ _ _ _ 16 PJe-produ.Çectinjector~ .durptio.n_ofpre-pro.duGtiplJles~thaI'\.3mol1tbs.(For.ser:viceweIlon.!y).. NA.............. _. _..... _. _.. _ _ _......................................... _. _ __ 17 AÇMP.F:indjng_ofCon.$i.$te[1cy.h.asbee.nj~sued.for.tbispr:oiect. _.......... _ _ _ _ _ _ _ NA...... .Sidetr:ackof_e~istingweIL _ _.. _ _ _. _ _ _... _. _ _ _.. _............................ _. 18 .C_oodu.ctor str:ing.prQvided . . . . . . . . . . . . . . . . . . . . _ . _ _ _ . . . . . . . . . . . . . . . _ NA . _ . . . _ _ . _ _ . _ . . . . ., . . . . . . . . . . . . . . . . . . . . _ . . _ . _ . _ . _ _ _ . _ . .. _ _ _ _ _ _ _ _ . . . _ . . . . . . . . . . 19 .S.ur:face .ca$illg_ protec.t~ alLknowl'\. USDWs . . . . . . _ . . . _ _ _ . . . _ . . _ . . . . . . . _ . . _ _NA . . _ . _ . . . . _ . . . . . . . . . . . . . . . _ . _ _ _ _ _ . _ . _ . _ . . . _ _ . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . _ . 20 .CMT. v..ol adeql!.ateJo circ.ul..ate.o.n .cond.uctor. & sur[c.$g . . . . . . . . . . . . . . . . . _ _ . . . . . _NA . . . _ . . . . . . . . . . _ _ . _ . . _ _ _ _ . . _ . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ _ . . . . . . _ . . . _ _ . . _ 21 .CMT. v.ol adequ.ate.to tie-inJQng .string to.surj c~g. . . . . . . . . . . . . . .. _ . . . . . . . . . _ _ . .NA . . . _ . _ . Scab Jioe.r.. . . . . . . . . . . . . . . . . . _ . . . . . . . _ . . _ . _ . .. . . .. _ . . _ . . . . . . . . . . . . . . . . . . . . . 22 .CMT.will coYer.aJll<lJow.n_Pfo.ductiYe bori~on_s_ . . . . . . . . . . . _ . _ _ . _ . _ . . . . . . . . . . _Yes. _ _ . _ . _ _ _ _ . _ . . . . . . . . . . . . . . . . . . . . . . . . . _ . _ . . _ . .. _ . _ _ .. _ _ _ _ . . . . . . _ . . . _ .. . . . .. . . . . . 23 .C_asiog de.signs ad.eQua..te fpr: C,.T., B .&_ Rerl1Jafr..ost . _ _ . _ . _ _ . . . . _ . . . . . _ . . _ _ . _ . .Yes. . _ _ . _ _ . . . . . . . . . . . . . . . _ . . . . . . . _ . _ _ _ . . _ . _ .. _ _ . . . . . _ . . . . _ . . . . . . . . . _ . . .. . . . . . . . . 24 Adequpte.tan.kage_or re.seI'Ye pit _ . . _ . . . _ . . . . . . . _ _ . _ . _ . . . . . . . . . _ . . _ . . . .Yes _ . . . . . . Nab.ors.2.ES. _ _ . _ _ _ _ _ . . . . . . . . . . . _ . . . . . . . . . . . . . . . . _ . . _ . _ . . . . . .. . . . _ . _ _ _ . _ . . 25 Jf.a.re-pr:iII.. has_a. 1.0:-4.03 fQr pbançlon.me.nt beeo approved. _ . . _ _ . . _ _ . . . . . . . . . _ _ . .Yes. _ . . . . . . . . . . . . _ . . . . . . . _ . _ . . . _ _ _ . _ _ _ . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . _ _ _ . _ 26 .A.dequpte_V(e!lbore. ~eparaijo_nproposep. . . .. . _ _ _ . . . . . . .. . . . .. . .. . .. _ _ _ _ _ . _ . . .. .Yes .. .. . . . . . . _ _ . _ _ _ . . . . . _ .. . . . . . . . . .. .. . . . .. . . . . . . . . . _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jf..djver:ter req.uired, dQes jt meet regu.lations. . . . . . . . . _ _ .. _ _ _ . _ _ . . . . . . . . _ . _ . _ NA . . . . . . . Sidetr:ack.. . _ . _ _ . . _ . _ _ _ . _ _ . _ . . _ _ . . . . . . . . . . . . . . . . . . . . .. . . . _ _ . . .. . . . .. . . . . . . _ Appr Date 28 .DJiUi09 fJujd. Rrog.ram schematic.& eq..uip Jistaçlequpte. .. . .. _ . _ . . _ . _ . _ . . . . . . _ . _ . .. .Yes. . . . . . . Max MW.8,5. RP9~ . .. _ . . . _ _ _ _ _ _ . . . . . . . . . . . . . . . . . . . . . . _ . . . _ _ _ _ . . . . . _ . . . _ . . . . . WGA 7/3/2003 29 .B.oPEs,. dp ..they .meet regu.la..tion _ _ . _ . . . . . . . _ . _ . . . . . _ . . . . . . . . . _ _ . . . . . . .Y.es . . . . . . . . . . _ . _ . _ . _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ . . . . . . . . . . . . . . . . _ . . . . _ . . _ . . _ _ _ _ . _ _ . . . . . _ . 30 .B.oPE.pre.ssratiogapprop(iate;_testto.(pu.tpsigin.comment$)... _.... _... _..... _ _. _ ..Yes...... .Testlo.35QO.RSl._I\lIS~24.50psi._... _ _.................... _.. _..... _ _ _........... 31 .C.hoke_l1Janjfold compJie~ w/API..R~-53 (May 84). . . . . . . . . . . . . . . . . . _ . . . . . . . . _ ..Yes. . . . . . _ . . . . . . . . . . . _ . . _ .. _ . . . . . . _ .. _ _ . . . . . . . . . . . . . . . . . . . . . _ . . . . _ _ .. . . . _ . . . . . . _ . 32 .Work will pCC.ur: withPIJt.operation _shutdown. . . . . . .. . . . _ _ . _ . .. . . . . . . . . . . . . . . . .Yes. . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . _ _ _ _ _ _ _ _ _ . . _ . . . _ _ . _ . _ _ . . . . . . . . 33 J~ Rres.ence_ Qf H2S gas. Rrob_able. . . . . . . . _ _ _ _ . _ . _ . . . . _ . _ . . . . . . . . . . . . . . No. . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . _ . . .. . _ _ . . . _ . . . . . . . . . . . . . . . _ . . . . . _ . . _ . . . . . . . _ 34 Mecba.nicaLcoodJtion ..of we.lIs wi.thil1 AOR yerifiect (For.s.ervic;e wßIJ on.ly) _ _ . _ . . . . _ _ . . . . .NA . . . . . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . _ . _ . _ . _ . _ . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Appr SFD ) Date Engineering ) Geology Appr SFD Date 7/2/2003 Geologic Commissioner: 35 ..Per:mit CB(1 be i.S$l!.eçl wlo. hyçlr:ogen. s.ulfide meë:!s.ur:es. . . . . _ . . . . . . . . . _ . . . _ _ . . _ .. No. . . . . . . . . . . . . . . . . _ _ _ . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . _ _ . . . . . . . . . . . . _ . . _ . . . . . . 36 .D.ata.preseoted 01'\. Rote_ntial PveJRres.sure .zOlle.$. . . . . . . . . . . . . . . . . . . . _ . . .' . _ . . .Yes _ . . _ . . .. Expectect rese.rv:ojr pre.S$ure i.$ },5.ppg EMW; will.be .d(iIleçl with 6.4 to. 8.5 PR9.I1JUd, . . . . . . . . . . . . . . . . . _ 37 .SeislJ1lc.analysjs. of sba.llow gas.zpoes. . . . _ .. . . . . . . . _ . . . . . . . . . . . . . . . . . . . . _NA . . _ _ . . . .. _ . . . . . . . . . . . . . _ . _ _ _ . _ . . _ . . _ . . . . . . . . . _ . . . . . .. . . . _ . . _ . . . . . . _ . . . . . . . . . . 38 .Seabep .condjtipo survey .(if off-~h9r:e) . . _ . _ . . . . . . . . . . . _ . . . _ _ . . . . _ _ _ . . . . . NA . . . . _ _ . . . . . . . . . . . . . . . _ . _ . _ . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . _ . . . . . . . 39 _ CQnta.ct l1am.elphOl1eJor.V(eekly prpgre~s_reRo.rts [exploratpry .only]. . . . _ . . . _ . _ . _ . . . . NA . . . . . . . . . . .. . . . . . . . . . . . . . . . _ . . . . _ _ . . . . . . . . . . _ . . . . . . . . . _ . _ . . . . . . . . . . . . . . . . . . . Date: Engineering Commissioner: Date Public Commissioner Date D D ) ) Welll-listory File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennilting Process but is part of the history file. To improve the readability of the Well History file and to sim.plify finding infomlation. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr~_)ing Services LIS Scan Utility ) ~03~"ld I \ \ 9 ð' \ $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 04 10:00:53 2003 Reel Header Service name.... . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 15-08C 500292118003 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 04-SEP-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW2589887 J. SACK R. BORDES / MWD RUN 3 AK-MW2589887 T. GALVIN R. BORDES MWD RUN 4 AK-MW2589887 T. GALVIN R. BORDES # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 11N 14E 1645 1378 57.99 29.47 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 8772.0 RECEIVED SEP 1 6 2003 # AJaska Œ~ (~Gas ConDo CG¡1'ìmi~9ion .Anchorage ~~~ffi~ REMARKS: ) ') 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND MILL THE WINDOW, THE TOP OF WHICH WAS AT 8772'MD/8340'TVD AND THE BOTTOM WAS AT 8784'MD/8349'TVD. NO DATA ARE PRESENTED. 4. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL WITH GAMMA MODULE (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS; COMPENSATED THERMAL NEUTRON POROSITY (CTN); STABILIZED LITHO-DENSITY (SLD); AND AT-BIT-INCLINATION (ABI). 5. MWD RUN 4 COMPRISED DIRECTIONAL WITH GM. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 9' DEEPER PER E-MAIL FROM D. SCHNORR, BP EXPLORATION (ALASKA), INC., DATED 8/26/03. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 1 - 4 REPRESENT WELL 15-08C WITH API#: 50-029-21180-03. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11552'MD/8782'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. TNPS SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.5 PPG MUD SALINITY: 1000 PPM CHLORIDES FORMATION WATER SALINITY: 10994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/04 Maximum Physical Record. .65535 File Type...... ......... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR NCNT FCNT NPHI PEF DRHO RHOB Rap $ 1 ) ) and clipped curves¡ all bit runs merged. .5000 START DEPTH 8654.0 8781.0 8781.0 8781.0 8798.5 8798.5 8798.5 8807.5 STOP DEPTH 11509.0 9865.0 9866.0 9865.0 9879.0 9879.0 9879.0 11560.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8654.0 11560.5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 8645.0 11551.5 BIT RUN NO 2 3 4 MERGED MAIN PASS. $ MERGE TOP 8645.0 8881.0 9938.0 MERGE BASE 8881.0 9938.0 11551.5 # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 NPHI MWD PU-S 4 1 68 12 4 FCNT MWD CNT/ 4 1 68 16 5 NCNT MWD CNT/ 4 1 68 20 6 RHOB MWD G/CM 4 1 68 24 7 DRHO MWD G/CM 4 1 68 28 8 PEF MWD BARN 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8654 11560.5 10107.3 5814 8654 11560.5 ROP MWD FT/H 0.14 503.17 118.233 5507 8807.5 11560.5 GR MWD API 11.51 287.89 55.8413 5711 8654 11509 NPHI MWD PU-S 4.7;':; ') 35.02 18.4475 2115 ) 8781 9865 FCNT MWD CNT/ 320 3336.6 1074.27 2118 8781 9866 NCNT MWD CNT/ 22440.2 49656.5 33598.5 2116 8781 9865 RHOB MWD G/CM 1.95 2.92 2.2525 2111 8798.5 9879 DRHO MWD G/CM -0.136 0.482 0.0644173 2111 8798.5 9879 PEF MWD BARN 0.57 9.33 1.60878 2111 8798.5 9879 First Reading For Entire File......... .8654 Last Reading For Entire File.......... .11560.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/04 Maximum Physical Record. .65535 File Type....... . . . . . . . . .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/04 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FCNT NCNT NPHI PEF DRHO RHOB ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 8645.0 8772.0 8772.0 8772.0 8789.5 8789.5 8789.5 8798.5 STOP DEPTH 8836.0 8799.5 8799.0 8799.0 8813.0 8813.0 8813.0 8881.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 03-AUG-03 Insite 66.37 Memory 8881.0 8798.0 8881.0 40.9 42.7 # TOOL STRING (TOP TO VENDOR TOOL CODE SLD CTN GM $ ) BOTTG.·. J TOOL TYPE STABILIZED LITHO DEN COMP THERMAL NEUTRON Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. ............... . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) TOOL NUMBER 150253 113413 69706 6.125 8772.0 QUIKDRIL-N 8.50 43.0 9.0 600 6.6 .000 .000 .000 .000 .0 113.0 .0 .0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 NPHI MWD020 PU-S 4 1 68 12 4 FCNT MWD020 CNTS 4 1 68 16 5 NCNT MWD020 CNTS 4 1 68 20 6 RHOB MWD020 G/CM 4 1 68 24 7 DRHO MWD020 G/CM 4 1 68 28 8 PEF MWD020 BARN 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8645 8881 8763 473 8645 8881 ROP MWD020 FT/H 0.14 130.85 30.4507 166 8798.5 8881 GR MWD020 API 18.95 287.89 58.8064 383 8645 8836 NPHI MWD020 PU-S 15.86 35.02 24.78 55 8772 8799 FCNT MWD020 CNTS 320 878.6 560.702 56 8772 8799.5 NCNT MWD020 CNTS 22440.2 30788.3 26578.5 55 8772 8799 RHOB MWD020 G/CM DRHO MWD020 G/CM PEF MWD020 BARN ),' 2.06b -0.056 1.16 2.92 0.152 9.33 2.25687 0.0400833 2.01917 First Reading For Entire File......... .8645 Last Reading For Entire File.......... .8881 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/04 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/04 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI GR PEF DRHO RHOB ROP $ 3 48 48 48 )8789.5 8789.5 8789.5 8813 8813 8813 header data for each bit run in separate files. 3 .5000 START DEPTH 8826.0 8826.5 8826.5 8836.5 8839.0 8839.0 8839.0 8881.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 9856.0 9857.0 9856.0 9894.0 9870.0 9870.0 9870.0 9938.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SLD STABILIZED LITHO DEN 05-AUG-03 Insite 66.37 Memory 9938.0 8881.0 9938.0 44.3 89.0 TOOL NUMBER 150253 )HERMAL 113413 ) CTN COMk NEUTRON GM Dual GR 69706 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.125 DRILLER'S CASING DEPTH (FT) : 8772.0 # BOREHOLE CONDITIONS MUD TYPE: QUIKDRIL-N MUD DENSITY (LB/G) : 8.50 MUD VISCOSITY (S) : 39.0 MUD PH: 9.2 MUD CHLORIDES (PPM) : 1000 FLUID LOSS (C3) : 6.3 RESISTIVITY ( OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 130.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing................. ... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 NPHI MWD030 PU-S 4 1 68 12 4 FCNT MWD030 CNTS 4 1 68 16 5 NCNT MWD030 CNTS 4 1 68 20 6 RHOB MWD030 G/CM 4 1 68 24 7 DRHO MWD030 G/CM 4 1 68 28 8 PEF MWD030 BARN 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8826 9938 9382 2225 8826 9938 ROP MWD030 FT/H 3.8 177.31 51.7498 2114 8881.5 9938 GR MWD030 API 11.51 124.88 39.4858 2116 8836.5 9894 NPHI MWD030 PU-S 4.72 34.19 18.2784 2060 8826.5 9856 FCNT MWD030 CNTS 453.1 3336.6 1088.21 2062 8826.5 9857 NCNT MWD030 CNTS 25496.7 49656.5 33785.8 2061 8826 9856 RHOB MWD030 G/CM 1.95 2.895 2.2524 2063 8839 9870 DRHO MWD030 G/CM -0.136 0.482 0.0649835 2063 8839 9870 PEF MWD030 BARN 0.57 5.15 1.59923 2063 8839 9870 ) ) First Reading For Entire File......... .8826 Last Reading For Entire File.......... .9938 File Trailer Service name............ .STSLIB.003 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/04 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/04 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 9894.5 9938.5 STOP DEPTH 11500.0 11551.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 07-AUG-03 Insite 4.3 Memory 11552.0 9938.0 11552.0 88.2 94.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 77114 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 8772.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): QUIKDRIL-N 8.50 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: ) 38.0 9.1 1800 6.5 ) .000 .000 .000 .000 .0 145.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWD040 GR MWD040 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9894.5 11551.5 10723 3315 9894.5 11551.5 Rap MWD040 FT/H 0.43 503.17 166.302 3227 9938.5 11551.5 GR MWD040 API 33.9 131.55 66.2623 3212 9894.5 11500 First Reading For Entire File......... .9894.5 Last Reading For Entire File.......... .11551.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/04 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.. . . . . . . . . . . . . . . . . . ..03/09/04 Origin. . . . . . . . . . . . . . . . . . . STS \..' ,~... ) Tape Name............... ._!KNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.................... .03/09/04 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name... ...... ...... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
