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202-197
l @? /Ä\ Cï? æ 1]'- rE fM n /Ä\ @ ry¡ /Ä\ æ) IJ fAjj U: JJJ lr lAJ 11 fAj @ ~ fAj AIßA.SIiA OIL AlWD GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark O. Johnson CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe BayUnitH-14B BP Exploration (Alaska), Inc. Permit No: 202-197 Surface Location: 1542' SNL, 1265' WEL, Sec. 21, TI1N, R13E, UM Bottomhole Location: 2678' SNL, 72' WEL, Sec. 16, T11N, R13E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above development well. This permit does not exempt you from 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). Sincerely, be~~:+ Chair BY ORDER OF THE COMMISSION DATED this~ day of September, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of work [J Drill II Redrill [J Re-Entry [J Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519~6612 4. Location of well at surface 1542' SNL, 1265' WEL, SEC. 21, T11 N, R13E, UM At top of productive interval 2248' NSL, 4320' WEL, SEC. 15, T11 N, R13E, UM At total depth 2678' NSL, 72' WEL, SEC. 16, T11N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028281, 2602' M D No Close Approach 16. To be completed for deviated wells Kick Off Depth 10155' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weiaht Grade Couplina 3~3/4" 3-1/2" x 2-7/8" 8.81 #x 6.16# L-80 STL ALASKA."l AND ~:~T~g~S~~:~ON COMMI~ÅION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory [J Stratigraphic Test II Development Oil [J Service [J Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 82.25' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028284 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /' H-14B 9. Approximate spud da~- 09/26/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12050' MD 18944' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 90 0 Maximum surface 2290 ~Sig, At total depth (TVD) 8800' I 3170 psig Setting Depth Top Bottom Quantitv of Cement Lenath MD TVD MD TVD (include sta~e data) 2200' 9850' 8300' 12050' 8944' 157 cu ft Class 'G' lNC¡A- .c¡/¡q/01- r~¡r- C¡(19~ 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 12556 feet 9057 feet 12482 feet 9040 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 8 cu yd Concrete 110' 110' 3720 cu ft Permafrost II 2692' 2962' 1410 cu ft 'G', 130 cu ft PF 'C' 9981' 8491' 305 cu ft Class 'G' 10187' 8664' 124 cu ft Class 'G' 12542' 9055' t.J' . '~ 110' 20" x 30" 2654' 13-3/8" 9981' 9-5/8" 682" 7" 3568' 2-7/8" true vertical Open: 10560' -10564',11090' -11480',11530' -11560', 11Eì10' -11640',11790' -11820',11850'- 12080' - 12129', 12172' - 12370', 12420' - 1247?' - Open: 8926' - 8929', 9012' - 9021', 9024' - 9027', 9033' - 9036', 9034' - 9033', 9031' - 9030', 9027' - 9030' 9034' - 9030', 9032' - 9033' .,' ,,; " Perforation depth: measured 20. Attachments II Filing Fee 0 Property Plat 181 BOP Sketch [J Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot [J Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5666 Prepared By Name/Number: Sondra Stewman, 564-4750 21, ~~:~:y C::~:::;$Z1~ d corred~to.:::i;:;::ineer. .. . Date. 9 )7/0,- Permit Number API N ber ~9!°v~1 ~ate See cover letter Zo, - / 7' / 50- 029~20580-02 GfI---~c1 /iJ ;;2- for other reauirements Conditions of Approval: Samples Required 0 Yes 81 No Mud Log Required 0 Yes S No Hydrogen Sulfide Measures .Ii Yes 0 No Directional Survey Required ø 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:Te,s+ Be> PE *' 5çoo Pk . YHf:jtfiî*\ Itgned By . . :~:o~~~ Rev. 12~01~85CammyCW>sliT~ 0 R ¡ G r~ÃTer by order of the commission Date Qáð0:Þ ~~~nVTriPlicate ') ) BP H-14b Sidetrack Summary of Operations: A CTD through tubing sidetrack is planned for well H-14a. The coil sidetrack, H-14b, will exit the 7" liner and target Zone 2. Existing perfs in the H-14a liner will be isolated with a cast iron bridge plug set in the 2 7/8". The existing 2 7/8" liner will be cut and recovered and a mechanical whipstock will be used to exit the 7". A 4.25" hole will be drilled to TD in Zone 2 at ,...12050'. The production liner will be a cemented 3 %"x 2 7/8" string. Phase 1: Prep work. Planned for September 22, 2002. 1. The tubing has been drifted, GLM's dummied off and an IA MIT successfully performed to 2500 psi. 2. Slickline - Pull 5 ¥2" liner top packer at 9450' md. 3. E-line - Run cement evaluation log in the 2 7/8" liner to locate free pipe expected at ,...11000' md. 4. E-line - Run 27/8" CIBP and set at 10220' to isolate perfs in the 2 7/8" liner. 5. E-line - Chemical cut the 2 7/8" liner at approx. 10180'. 6. Service coil- Pull and lay down the severed 2 7/8" liner with the work platform. 7. Service coil - Underream the 7" casing to ensure clean for the new whipstock. 8. E-line - Set a mechanical whipstock at,...10155'. 9. Service coil-Pump 15.8 ppg class G cement down past the whipstock to P&A the wellbore past the existing uncemented liner lap. Pump a total of 18 Bbl of 15.8 ppg class G cement during the job. Cement will be cleaned out down to the whipstock tray. 10. wac. Pressure test wellbore to 1000 psi. P&A complete. If the cement were to fail the pressure test, a second squeeze is not planned since this portion of the wellbore will be isolated by cement during the primary cement job of the new sidetrack liner. Phase 2: Mill window, Drill and Complete sidetrack: Planned for September 26, 2002. 1. MIRU CTD rig / 2. Mill 4.30" sidetrack window from whipstock. 3. Drill 4.25" openhole to ....12050' TD with MWD and LWD resistivity as per attached directional plan. 4. Run and cement 3 1/2" x 2 7/8" liner. /' 5. Run memory CNUGR/CCL. 6. Perforate. 7. RDMO. Mud Program: . Phase 1: Seawater . Phase 2: Mill with seawaterlbiozan, drill with Flo-Pro (8.6 - 8.7 ppg) /" Disposal: . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: / . The 3 ¥2"x 2 7/8" production liner will be cemented frï:v' D, (12050' MD, 8944' ss), to approx. 9850'MD,8300'ss. Cement volume is planned to b 28 bls.'/ . The liner will be selectively perforated. Well Control: . BOP diagram is attached. / . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. ) -) Directional . See attached directional plan. Max. planned hole angle is 90 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray log will be run over all of the open hole section. LWD resistivity is optional. . A Memory CNL will be run in the cased hole. Hazards . The highest H2S recorded to date on H-Pad was 120 ppm from H-22A on 5/5/01. / . Crossing two faults, but with low risk of lost circulation. Reservoir Pressure Res. press. is estimated to be 3170 psi at 8800'ss (7.0ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2290psi. MOJ 9/15/02 ~6'V-5",Þ 2'tO-~-'1, TREE = 6" MCEVOY rWElLHEAD~ MCEVOY: 'jÄCTUÄrÕR-;--"-"--'-'--'-OTIS! 'kif-êi:Ë\/-.;----'-------------t32:2S;-' i 'BF:--Ëla¡;m_--__-------m'46:47;~ tK:op-;--'-"-'--"'-"----"--'--"32ÕO;': ~§~~~-~~!!~~-'-~~~~~'_~~i~~~~_~; t~-~-~~~~~~:::::~~~-_ã~~~~~J ~ L~3-3/~" ~G, ~~#, L~80, ID ~ 12.347~- 1'1 ~~? - m~ ) H-148 ' '):rv NOTES: 70o@ 10627' & 90o@ 11251' Proposed CTD Sidetrack ~ I s: 112" TèG,17!èL~80, .~~~¡'I, I) = 4sgT H 9499' ¡ -~- ( -¡ 1 . r8-j ~~""'-~-""I t (""-~"'~U"i ~ ~ I:!;~~~~~~:" p~~ :A~~-~-I 1-m .m - -.. ¿'-' '-""m.... i j ,~~..~::. ti;~:;~~~~R,I)=4875" ] , (0 0 O¡ ~.e . -'~ ..- --1 .~, F- --j9399; H9-5iÍl;X5-1i2;BKRsAàF;¡¿¡;¡;¡)~4.7~! I Top 01 3 112" Liner i I 9440' m.._..., t 8 ! 'M , -c' - L .9458':' H 5-112" OTIS ~ NI"',II) ~ 4.562" .J ~ ~~, ~' ! ~ -..I__._~__m..r l ¡ : ~ , I ! " ¡ :~ 2000' j-{~~~/2"-OTIS RQM-SSSV LÃND NIP:!D-=._4.562': - j GAS LIFT MANDRaS ist---MO-- --WDTw" TYPE!- - VL V -¡LATCH 1 PÒRT T DATEm :--s--30õ3'i2920-j -s------ÕmTDifMMYj -RA I - ------iÕ6Ï11ïo2' i 4 5685 5127 ¡ 43 OTIS ¡ DUMMY ¡ RA =,' i06/11/02 ¡ , 'I . ! 3 8417: 7180! 37 OTIS j DUMMY I RA i 106/11/02 ; 2 9202!7784 40 OTIS : DUMMY' RA ¡ :06/11/02, ¡ 1 9355 : 7903 ¡ 38 OTIS; DUMMY IRA! 06/11102 I ~ - --- ------ ~..t... ~ ---.- -- -- .-- --'II' ---- _...t._- - ------ ..A.. --' ---- r --- 9481,m_-1-i5-1/2" OftS-XN-NIP, ïD= 4~4s5~' I L_._~~~___Ji~:' -~~~-~~~-~~~~--~!~- S~-~~.J r ----9501'------1-i-ELMDTI LOGGED-~õï1Õï91 -1 f;:Õ¡;-ÕF"7;-"LÑrQ-f- --9008- -_.oJ ~ ---, .- L!?!~~~~iF'S!~]im-1-Ö155----- ÆRFORA TON SUMMARY REF lOG: SWS CNUGR ON 06/21/98 ANGLE AT TOP PERF: 54 @ 10560' Note: Refer to Production DB for historical perf data I ~- - s~~ _J- ~~_f - _~NT~ÿA~_~~~__.--~pnt~_g~J. DAT( - J ¡, 2" 4 10560 -10564 ' isolated, proposed I : i 1-11/16"! 4 11090-11480 isolated i proposed' I . I 1-11/16"14 11530-11560 isolated proposed i , 1-11/16" = 4 11610-11640 isolated: proposed: I i j 1-11/16" I 4 : 11790-11820 ~solated proposed ~ : 1-11/16" ¡ 4 : 11850-11880 ISolated proposed: j ¡ 1-11/16" ¡ 4 12080 - 12129 isolated, proposed: I : : 1-11/16" 4 12172 - 12370 isolated: proposed' i . . : 1-11/16" ¡ 4 12420 - 12470 isolated' proposed: ¡ : I ¡ ! ¡ , I 7" lNR, 29#, L-80, .0371 bpf, ID = 6.184" H 10940' ~IJ. ! ' , r-----9SŠÕï-m-HYop-Of ceñ;ñt-----------------l , ~a \ ,,'..: ["-- ~1/2;-X -2=7/8" cñt'eèiäñd- perf~d -1-1 ---1-205ö' --1 \ »J~''f-' 10180' --1-12-7/8-ïñ;cut and p~Ued 1 I ~~?'8:_?!.~_,- ~~~,-.~~~_O,--~D ~ 8~6~~: J-i - _~1' - r-----' r ---10196'- --J-IRA MÃRKËRl . I M ILLOUT WINDOW I 10190'-10196' i i ~ 10220' !-iCIBP I r -pßTD -1-{-- 12482' I I 12-7/8" LNR, 6.16#, L-SÕ::0O579 bpf, -10=-2-.37- l-f 1255Ëf -~. . ! , - : DATE i REV BY : COMMENTS ~-----""'-.A - +-_-"'A.~"--I- ~",\.--,,--...- ... -'IA,--,,_.I' - - k- -"'---""'''U"\.'''~k"''''''''''- . 1981: ORIGINAL COMA-ErION . .... 06/24/98 ¡ : SDETRACK . I ---- : 02/17/01 ¡ SIS-SLT . CONVERTED TO CANVAS ,03/01/01-¡ SIŠ-:LG .... FINÃL , I ~ 03/10/02: RNlTP : CORRECTIONS .. , i ¡ DATE, REV BY r COMlnENTS ¡ , -:"V'I_---, St.."""A""'''''''''''''- "- -^--- -..... "'-';"'\.__:..10._--'--------"'-;';"----- ,;,...."...--......-,,; ---;..,.""........_.....~ , lO_6/15/02 :_m~UTP :GLV D~MMYS -! I I ¡ I I f-- j ~ i ! i ¡ ¡ ~ . ~ i " PRUDHOE SAY UNIT W8-L: H-14A PERMIT No: 1980680 API No: 50-029-20580-01 SEe 21, T11N, R13E BP Exploration (Alaska) I I i ~ J \, 1 TREE = 6" fvCEV OY WELLHEAD = fvCEVOY Act{jdti'R~... - ..-.. .-'---.otS" -RB:', ËlËV ;""""""""'-82:25' ï3F:iiËV";;---...".--.m"'46":4:]í KOF) ;;.. ------.--- u-..-.-.-h_--.. 32Ötf '~x"Ãñ'g¡ë'-;;""95'@f1-22ä6Î 'öätü"ñïMD;;.m.mm..m;¡ö49Š; ~.. ...... ....... ~ . r r". r-.......... .... _..- -- ".- Datum TVD = 8800' SS ') 113-3/8" CSG,72#, L-80, 10 = 12.347" 1-1 2692" Minimum ID = 2.35" @ 9450' 5-112" X 2-718" PROD PACKER ~ "', s r ( ~ (r ITOPOF2-7/8"LNR 1-1 9471" 1 5-1/2" TOO, 17#, L-80, .0232 bpf, 10 = 4.892" 1'1 9499' TOPOF 7" Lt>R 1-1 9505' H-14A f) ~ l ~ " 'It, ) I SAFElY tÐTES: 7ft @ 10627 & 90o@ 11251' 2000" 1-i5-112" OTIS RaM SSSV LA(\{) NIP, 10 = 4.562" 1 GAS LIFT MANI:RELS ~ ST fvÐ TVD DEV TYÆ VLV LATOi PORT DATE 5 3003 2920 5 OTIS DU~ RA 06/11/02 4 5685 5127 43 OTIS DU~ RA 06/11/02 3 8417 7180 37 OTIS DUtt!NY RA 06/11/02 2 9202 7784 40 OTIS DU~ RA 06/11/02 1 9355 7903 38 OTIS DUtt!NY RA 06/11/02 I 1 &-i r 9450" 1 9458' 1 9471' I 9481' 1 9499' I 9501" 8 g r ~ 19-5/8" CSG, 47#, L-BO, 10 = 8.681" 1-; 9981" ~ PffiFORA TION SUMvtARY REF LOG: &/VS CN.JGR ON 06/21198 ANGLEA TTOP FERF: 54 @ 10560' NJte: Refer to Prcx:luction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ',l' 4 10560 -10564 0 O5/fJl/OO 1-11116" 4 11090 - 11480 0 05101199 1-11116" 4 11530 - 11560 0 12/Zl /98 1-11116" 4 11610-11640 0 12/Zl/98 1-11116" 4 11790 - 11820 0 12/Zl/98 1-11116" 4 11850-11880 0 12/Zl/98 1-11116" 4 12080-12129 0 00/24/98 1-11116" 4 12172 - 12370 0 00/24/98 1-11/16" 4 12420-12470 0 00/24/98 1 TOP OF WHIPSTOCK 1-1 10187' 1 TOPOF CEM:NT H 10229' 17" Lt>R,29#, L-BO, .0371 bpf, ID = 6.184" 1--1 10940" 1 2,1/8 /J 1 ~ - 9385" 1-;5-1/2" X NIP, D = 4.562" I 9396" H5-1/2" BKRK-22ANOiOR, D =4.875" 1 9399" 1-19-5/8" X 5-1/2" BKR SAB A<R, ID = 4.75" 1 HS-112" X 2-71fr' HES RCP PKR, 10 = 2.35" 1 1-15-112" OTIS X NIP, ID = 4.562" 1 HBAKERDIR.OYtvENT SUB I H5-1/2" OTIS XN NP, ID = 4.455" 1 1-17" BKRSEAL ASSY W/O SEALS 1 1'1 ELfvÐ IT LOGGED 1 0/1 0/91 1 n ~ MILLOur WINDOW 10190' - 10196' 10196' HRA MARKffi 1 , - 10>'°"-/0-;"'1/- I PBID H 12482" l-t 12556' 1 --1. - DATE REV BY COM\1ENTS Oð.1E REVBY COMfÆNTS 1981 ORIGINAL COf..R..ETION 0&'15102 R../1P GLV DUtt!NYS 06/24/98 SlDETRA CK 02/17/01 SIS-SLT COMlffiTID TO CAMI AS 03/01/01 SIS-LG RNAL 03/10/02 RN'TP CO~TIONS PRLDI-DE BA Y UNIT WElL: H-14A PERvtIT No: 1980680 AA No: 50-029-20580-01 SEC21, T11N, R13E BP Exploration (Alaska) h...tW..~ TI8- MD. 1UtI. "81._"" v..= ~.: C:~= -.... I'" I'" BP Amoco MLL"ATH DnAlL8 ~~~JI~\" ...14.1. 11100'" "_Ie 1 10 .18 '/17/11'1 00000 1..Hft :::...~ I'" REFERENCE INFORMATION Co-ordtn8ta~! Raference: Wall Centre: H-14, True North v=c:n (VS ~:~::::: ~r:~~ ;~~~~ Measured Depth Raference: 20: 145117/1981 00:00 82.30 Calculation Mathod: Minimum Curvatura 8400 = . ? :. ;S 8450 =:-: Õ 8500-::: : I!!. ::=" , . I: ~:;'r ...:'::: jr~::--::-,,~- I::~'I~::~J:J~~::- ..... .,' ~:~':~d ' .. "'ll\ m :, .. :: 8850- ........ Ad , tet........ ...... . f..ILOO Þ.f. I.,... I '1..,..00...81 IOn . f""''' ....1. ai' . fNla.1I 101.87 ....... . f0M8." 80.00 Uf.tl ,. fO'...,." "00 ItT." . fOllf." 10.00 ..,.... . ffMf." ...00 ....., ,. 'f.U." 88.00 ...... U ttaa.lf 88.00 ""'1 U ..,tHo" ...... MO.f. f.ff....11 ..... a.M." 'I" faote... ..... 81IA8 AllHO'I'ATIOH' TVD MD _10- ...."a 1a1"'" "" ....", i."'''' KO" ..ft", 1.171... 1 '8Ia.s. 1....... . '7I..'a 1N8I." t ""'711._.18 8 .....711.781.18 . .....711...1.18 . ""'7111081." 7 ".IAll1ltl." . '1".11 11818"1 I ....", 1,.18"1 11 :!!!-U :::~.!~ ~ 8250 ~ ::1 ::: . 8300 ::. -. 8350 :;: :::: IIC'T1OM 811TAtU .". ..... - ...... 1487.7' IMP.. UILO' M08.ff "70." ::n::¡ r.u:n CU::t 1?...1O ....... "'27.. IIM.n ",.... nlf.1? lI....n aua... noa.'l 18M.n "''1. na.,o MM.,. ..,81." 1.,.,4.11 ....... 4H8." ""''18 ".LfO aot"f f"'.OI ...." aoe." f"'.12 ..aa.18 ...... u...,. ......00 alGA' tt8l.07 ..... TIM. Y'88c T-..' 0.00 0.00 -'aM '.04 »a.'" -11a,10 8.00 »0.00 .., 88.14 '8.00"'00 -.,.,... .8.00 110.00 -1ot." fLOG "'.00 ...,. '18.00 170.00 1.,.81 18.00 80.00 228.,. 18.00 210.00 42.... 11.00 180.00 "'.2' 1LOG .4.00 1841a 11.00 80.00 "I'" 18.00 1'10.00 101U' ".00 80.00 fll3.1' TNÐET DET"'LS TVD 4fU.ð 4£lJIt ShIpe :t~::~,1 ~gg =::.:: =:: ~ ...t48T12 883$00 419o.ot 2101.45 PoW'C K-t48TU ~oo 4300'1 11".48 Point K-U8 T84 1944.00 4220.54 1t82'" P08'It ObP B.- .-.. INTEQ Direct: (907) 267.6613 Baker Hughes I~T~~; ~f)~~~qcom T ^M ¿ LEGEND = :t1~ ~:1~k) -- H.14 (H.14APB1) - H-14 (H-14APB2) - H-14 (H-14APB3) - H-14 (H.14APB4) - Plan#8(CTO) H.14B - Plan #8 Plan: Plan #8 (H-14/Plan#8(CTD) H-14B) Created By: Brij Potn!s Data: 9/412002 Azimuths to True North Magnetic North: 26.04' Magnetic Field Strength: 57524nT Dip Angle: 80.79' Date: 8/21/2002 Model: BGGM2002 .~~rî..:/j ~. f\i:,. :~;I 7 ",<.: - )( Contact Information: I 4500 = . ? .- 4000 - ~ 3900 ~ 0 - ""' -3800 .::::: - -~ + -' F ~ttc;cci""f"Bf---. . 3500-'";¿-~::' f 3400 ;" =O'1;¡¡¡'ifi~:o-cc - '........,.c . fI) 3300 : : ' . ~ IIII 1III III IIII III IIII ~II IIII .111 1111 ¡,II 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 West(-)IEast(+) [100ft/in] '~ :~-.:l::~:?~~.:.:~: - ... :1- /, 89SO::: :::: :.:: : ::: J; ---- ,I . , 9000-' '" I': : :: '; . - A. H.14 (H-14 ' ' 1 1111 I'll 11 II 1 111111/11111 -400 -350 -300 -250 -200 -150 -100 -50 0 50 8900 = . , - .--'0" ... h_*- . III: 11 300 350 400 450 500 550 600 650 700 750 800 850 Vertical Section at 302.00. [SOltlln] 9/'112002 3:08 PM ObP ) ') II.. BAICØ IUGIIH INTEQ BP Baker Hughes INTEQ Planning Report Company: Field: Site: Well: WeUpath: Field: BPArrioco .PJ'IJ<.ttiQeBay PB HPad . H-14 Plani#ß(CTD}H-148 Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea level Date: 9/412002 11oIe: . 14:51:54 Co-onlinate(NE) Reference: Well: H-14, True North . Vertical (TVD) Reference: System:.Mean Sea level Section (VS) Reference: Well (0.ooN,O.00E.302.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Page: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre 8GGM2002 P8 H Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5957572.25 ft 641366.07 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 30.055 N 148 51 19.802 W True 1.08 deg H-14 H-14 Well Position: Well: Slot Name: 14 70 17 46.149 N 148 50 21.676 W +N/-S 1636.67 ft Northing: 5959246.00 ft Latitude: +E/-W 1994.21 ft Easting: 643329.00 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: Plan#8(CTD) H-148 500292058002 Current Datum: 20: 145/17/1981 00:00 Magnetic Data: 8/21/2002 Field Strength: 57524 nT Vertical Section: Depth From (fVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0.00 H-14A 10100.00 ft Mean Sea level 26.04 deg 80.79 deg Direction deg 302.00 Height 82.30 ft Targets . Map Map <- Latitude..--> ~ Longitude --> Name Description TVD +N/-5 +EI-W Northing Easting Deg Min See Deg Min Sec Dip. Dir. ft ft ft ft ft H-14B Polygon8.1 0.00 3616.11 2560.62 5962910.00 645820.00 70 18 21.709 N 148 49 7.004 W -Polygon 1 0.00 3616.11 2560.62 5962910.00 645820.00 70 18 21.709 N 148 49 7.004 W -Polygon 2 0.00 4116.21 2300.09 5963405.00 645550.01 70 18 26.628 N 148 49 14.597 W -Polygon 3 0.00 4354.71 2119.59 5963640.00 645365.00 70 18 28.974 N 148 49 19.859 W -Polygon 4 0.00 4402.64 1180.26 5963670.01 644425.00 70 18 29.448 N 148 4947.254 W -Polygon 5 0.00 4132.66 1175.11 5963400.00 644425.00 70 18 26.793 N 148 49 47.405 W -Polygon 6 0.00 4160.88 2055.88 5963445.00 645305.01 70 18 27.068 N 148 49 21.719 W -Polygon 7 0.00 3877.57 2225.52 5963165.00 645480.00 70 18 24.281 N 148 49 16.774 W -Polygon 8 0.00 3534.46 2384.02 5962825.00 645645.01 70 18 20.907 N 148 49 12.155 W H-14B T8.1 8835.00 3874.16 2351.49 5963164.00 645606.00 70 18 24.248 N 148 49 13.101 W H-148 T8.2 8835.00 4190.01 2101.45 5963475.00 645350.00 70 18 27.355 N 148 49 20.390 W H-148 T8.3 8925.00 4300.91 1793.48 5963580.00 645040.00 70 18 28.446 N 148 49 29.370 W H-148 T8.4 8944.00 4220.54 1182.79 5963488.00 644431.00 70 18 27.657 N 148 49 47.181 W Annotation MD TVD ft ft 10100.00 8508.86 TIP 10155.00 8555.07 KOP 10175.00 8571.67 1 10250.00 8630.28 2 10453.75 8769.70 3 10666.58 8834.73 4 10741.58 8834.73 5 10851.58 8834.73 6 11061.58 8834.73 7 ObP ) BP ') ..8 BAIC8JIII ..... Baker Hughes INTEQ Planning Report INTEQ Company: BPAmoCö Date: ....9/412002 Time: 14:51:54 Page: 2 Field: PrudhqeBay Co-c)~inate(NE)R,~e~..~: . Well:H-14.TrueNorth Site: 'PBHPad Ve~aI(I'VI)~eference: SyStEtm:Mea.,S~a level Well: H-14 ~n.(VS)R~ference: Well(0.ooN,0.00E.~02.ooAzi) Wellpath: Plan#8(CTD) H-14B SUi'VeyCakulâdon Method: Minimum Curvature Db: Oracle Annotation MD TV» ft ft 11211.58 8869.42 8 11430.31 8925.10 9 11530.31 8928.57 10 11830.31 8938.15 11 12050.00 8944.00 TD Plan: Plan #8 Date Composed: 8/21/2002 Identical to Lamar's Plan #8 Version: 7 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD loci -Azåm TV» +N/-S :.:-+EI-W . DLS Build. Turn TFO Target ft deg deg ft ft ft degl100ft deQ/10Qft degl100ft deg 10100.00 32.58 52.29 8508.86 3487.78 2347.40 0.00 0.00 0.00 0.00 10155.00 33.10 51.85 8555.07 3506.11 2370.92 1.04 0.95 -0.80 335.17 10175.00 34.67 50.27 8571.67 3513.12 2379.59 9.00 7.85 -7.91 330.00 10250.00 42.83 32.97 8630.28 3548.31 2410.01 18.00 10.89 -23.07 300.00 10453.75 53.97 345.36 8769.70 3691.04 2427.48 18.00 5.47 -23.36 270.00 10666.58 90.00 331.35 8834.73 3874.59 2351.87 18.00 16.93 -6.59 337.00 10741.58 90.00 317.85 8834.73 3935.58 2308.52 18.00 0.00 -18.00 270.00 10851.58 90.00 337.65 8834.73 4028.14 2250.10 18.00 0.00 18.00 90.00 11061.58 90.00 299.85 8834.73 4183.17 2114.13 18.00 0.00 -18.00 270.00 11211.58 63.00 299.85 8869.43 4255.09 1988.78 18.00 -18.00 0.00 180.00 11430.31 88.00 268.10 8925.10 4301.81 1787.02 18.00 11.43 -14.52 304.00 11530.31 88.04 280.10 8928.57 4308.94 1687.52 12.00 0.04 12.01 90.00 11830.31 88.42 244.09 8938.15 4268.36 1395.39 12.00 0.12 -12.01 270.00 12050.00 88.58 270.46 8944.00 4220.41 1183.07 12.00 0.07 12.00 90.00 Survey MD ft 10100.00 32.58 52.29 8508.86 3487.78 2347.40 5962777.64 645609.28 -142.46 0.00 0.00 TIP 10125.00 32.82 52.09 8529.89 3496.06 2358.07 5962786.12 645619.79 -147.12 1.04 335.17 MWD 10150.00 33.05 51.89 8550.88 3504.43 2368.77 5962794.69 645630.34 -151.77 1.04 335.34 MWD 10155.00 33.10 51.85 8555.07 3506.11 2370.92 5962796.42 645632.45 -152.70 1.04 335.50 KOP 10175.00 34.67 50.27 8571.67 3513.12 2379.59 5962803.59 645640.98 -156.34 9.00 330.00 1 10200.00 37.10 43.80 8591.93 3523.12 2390.28 5962813.79 645651.48 -160.11 18.00 300.00 MWD 10225.00 39.84 38.06 8611.51 3534.87 2400.44 5962825.73 645661.42 -162.50 ~8.00 305.24 MWD 10250.00 42.83 32.97 8630.28 3548.31 2410.01 5962839.35 645670.72 -163.49 18.00 309.74 2 10275.00 43.02 26.37 8648.60 3563.09 2418.43 5962854.29 645678.86 -162.79 18.00 270.00 MWD 10300.00 43.59 19.85 8666.80 3578.85 2425.14 5962870.17 645685.27 -160.14 18.00 274.84 MWD 10325.00 44.51 13.52 8684.77 3595.48 2430.12 5962886.89 645689.93 -155.55 18.60 279.58 MWD 10350.00 45.78 7.42 8702.41 3612.89 2433.33 5962904.36 645692.81 -149.04 18.00 284.13 MWD 10375.00 47.35 1.62 8719.61 3630.98 2434.75 5962922.47 645693.88 -140.66 18.00 288.43 MWD 10400.00 49.20 356.12 8736.26 3ß49.62 2434.37 5962941.10 645693.14 -130.46 18.00 292.43 MWD 10425.00 51.30 350.94 8752.25 3668.70 2432.19 5962960.13 645690.60 -118.50 18.00 296.09 MWD 10450.00 53.61 346.07 8767.49 3688.11 2428.23 5962979.46 645686.27 -104.85 18.00 299.40 MWD 10453.75 53.97 345.36 8769.70 3691.04 2427.48 5962982.38 645685.4 7 -102.67 18.00 302.37 3 10475.00 57.51 343.59 8781.66 3707.96 2422.78 5962999.20 645680.44 -89.71 18.00 337.00 MWD 10500.00 61.69 341.68 8794.31 3728.53 2416.34 5963019.65 645673.61 -73.35 18.00 338.00 MWD 10525.00 65.91 339.91 8805.35 3749.71 2408.95 5963040.68 645665.83 -55.87 18.00 338.97 MWD 10550.00 70.14 338.26 8814.70 3771.36 2400.68 5963062.16 645657.14 -37.37 18.00 339.75 MWD 10575.00 74.38 336.69 8822.32 3793.34 2391.55 5963083.97 645647.60 -17.99 18.00 340.37 MWD 10600.00 78.64 335.18 8828.15 3815.53 2381.64 5963105.96 645637.26 2.18 18.00 340.85 MWD 10625.00 82.90 333.72 8832.16 3837.79 2371.00 5963128.01 645626.20 23.00 18.00 341.20 MWD 10650.00 87.17 332.29 8834.32 3859.98 2359.70 5963149.98 645614.48 44.34 18.00 341.43 MWD 10666.58 90.00 331.35 8834.73 3874.59 2351.87 5963164.44 645606.37 58.72 18.00 341.56 4 k,l1 -g}) ObP ) BP ") ... -=- Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Daté:/'9/412002 " " Tbnè':14:51:54 " Påg~: Field: Prudhoe Bay ~Ï'dina~)..'~et~JJ~: ' . w~n:ti~.14;.'TrM~'N~ Site: PB H Pad Vertiea1(TVJ.»J,tef~~~:' ~~!~rn:M~~:~~l..~¥~1 WeD: H-14 SectiÖo (VS)R~ference: ' WeU.(q.QON,Q.()OE.3Q2.0QAzj) WeUpatb: Plan#8(CTD) H-14B SurveyCalculåtioD . MethOCJ: Minimum Curvature Db: Oracle Survey MD loci AWn SSTVD E/W ft deg deg ft ft 10675.00 90.00 329.83 8834.73 3881.92 2347.73 5963171.69 645602.10 66.11 18.00 270.00 MWD 10700.00 90.00 325.33 8834.73 3903.02 2334.34 5963192.52 645588.30 88.66 18.00 270.00 MWD 10725.00 90.00 320.83 8834.73 3923.00 2319.32 5963212.21 645572.91 111.98 18.00 270.00 MWD 10741.58 90.00 317.85 8834.73 3935.58 2308.52 5963224.58 645561.87 127.81 18.00 270.00 5 10750.00 90.00 319.36 8834.73 3941.89 2302.95 5963230.79 645556.19 135.87 18.00 90.00 MWD 10775.00 90.00 323.86 8834.73 3961.48 2287.43 5963250.08 645540.30 159.41 18.00 90.00 MWD 10800.00 90.00 328.36 8834.73 3982.23 2273.49 5963270.55 645525.97 182.23 18.00 90.00 MWD 10825.00 90.00 332.86 8834.73 4004.01 2261.23 5963292.09 645513.29 204.17 18.00 90.00 MWD 10850.00 90.00 337.36 8834.73 4026.68 2250.71 5963314.56 645502.34 225.10 18.00 90.00 MWD 10851.58 90.00 337.65 8834.73 4028.14 2250.10 5963316.01 645501.71 226.39 18.00 90.00 6 10875.00 90.00 333.43 8834.73 4049.45 2240.41 5963337.13 645491.61 245.91 18.00 270.00 MWD 10900.00 90.00 328.93 8834.73 4071.35 2228.36 5963358.79 645479.15 267.73 18.00 270.00 MWD 10925.00 90.00 324.43 8834.73 4092.24 2214.63 5963379.41 645465.03 290.44 18.00 270.00 MWD 10950.00 90.00 319.93 8834.73 4111.98 2199.31 5963398.86 645449.33 313.90 18.00 270.00 MWD 10975.00 90.00 315.43 8834.73 4130.46 2182.48 5963417.01 645432.15 337.96 18.00 270.00 MWD 11000.00 90.00 310.93 8834.73 4147.56 2164.26 5963433.76 645413.61 362.48 18.00 270.00 MWD 11025.00 90.00 306.43 8834.73 4163.18 2144.74 5963449.01 645393.80 387.30 18.00 270.00 MWD I 11050.00 90.00 301.93 8834.73 4177.23 2124.07 5963462.65 645372.86 412.28 18.00 270.00 MWD 06/ 11061.58 90.00 299.85 8834.73 4183.17 2114.13 5963468.41 645362.81 423.86 18.00 270.00 7 ~ 11075.00 87.59 299.85 8835.02 4189.85 2102.49 5963474.86 645351.05 437.26 18.00 180.00 MWD 11100.00 83.09 299.85 8837.05 4202.24 2080.89 5963486.84 645329.22 462.16 18.00 180.00 MWD 1 11125.00 78.59 299.85 8841.03 4214.52 2059.49 5963498.71 645307.59 486.81 18.00 180.00 MWD 11150.00 74.09 299.85 8846.93 4226.61 2038.42 5963510.39 645286.30 511.08 18.00 180.00 MWD II'1jO 11175.00 69.59 299.85 8854.72 4238.43 2017.82 5963521.81 645265.48 534.81 18.00 180.00 MWD 11200.00 65.09 299.85 8864.36 4249.91 1997.82 5963532.90 645245.26 557.86 18.00 180.00 MWD 11211.58 63.00 299.85 8869.43 4255.09 1988.78 5963537.91 645236.13 568.27 18.00 180.00 8 11225.00 64.37 297.63 8875.37 4260.87 1978.24 5963543.49 645225.48 580.27 18.00 304.00 MWD 11250.00 67.00 293.62 8885.67 4270.71 1957.70 5963552.94 645204.76 602.91 18.00 304.98 MWD 11275.00 69.73 289.77 8894.89 4279.29 1936.11 5963561.11 645183.01 625.76 18.00 306.63 MWD 11300.00 72.54 286.06 8902.97 4286.56 1913.61 5963567.94 645160.37 648.70 18.00 308.05 MWD 11325.00 75.42 282.46 8909.87 4292.47 1890.33 5963573.41 645136.98 671.58 18.00 309.26 MWD 11350.00 78.36 278.96 8915.54 4296.99 1866.41 5963577.47 645112.98 694.26 18.00 310.25 MWD 11375.00 81.33 275.52 8919.95 4300.09 1842.00 5963580.10 645088.53 716.59 18.00 311.04 MWD 11400.00 84.33 272.15 8923.07 4301.74 1817.26 5963581.29 645063.76 738.45 18.00 311.65 MWD 11425.00 87.36 268.80 8924.89 4301.95 1792.33 5963581.02 645038.83 759.70 18.00 312.07 MWD 11430.31 88:00 268.10 8925.10 4301.81 1787.02 5963580.77 645033.53 764.13 18.00 312.31 9 11450.00 88.00 270.46 8925.79 4301.56 1767.35 5963580.15 645013.87 780.68 12.00 90.00 MWD 11475.00 88.01 273.46 8926.66 4302.41 1742.39 5963580.53 644988.89 802.30 12.00 89.92 MWD 11500.00 88.02 276.46 8927.53 4304.57 1717.50 5963582.21 644963.97 824.56 12.00 89.81 MWD 11525.00 88.04 279.46 8928.38 4308.03 1692.76 5963585.20 644939.17 847.37 12.00 89.71 MWD 11530.31 88.04 280.10 8928.57 4308.94 1687.52 5963586.00 644933.92 852.29 12.00 89.61 10 11550.00 88.05 277.74 8929.24 4311.99 1668.09 5963588.68 644914.43 870.39 12.00 270.00 MWD 11575.00 88.05 274.74 8930.09 4314.70 1643.25 5963590.92 644889.55 892.89 12.00 270.08 MWD 11600.00 88.06 271.74 8930.94 4316.11 1618.31 5963591.86 644864.59 914.79 12.00 270.18 MWD 11625.00 88.08 268.73 8931.78 4316.22 1593.33 5963591.48 644839.61 936.03 12.00 270.28 MWD 11650.00 88.10 265.73 8932.61 4315.01 1568.37 5963589.80 644814.68 956.55 12.00 270.39 MWD 11675.00 88.13 262.73 8933.43 4312.50 1543.52 5963586.82 644789.88 976.30 12.00 270.49 MWD 11700.00 88.17 259.73 8934.24 4308.69 1518.82 5963582.54 644765.27 995.22 12.00 270.58 MWD 11725.00 88.20 256.73 8935.03 4303.59 1494.36 5963576.98 644740.91 1013.26 12.00 270.68 MWD 11750.00 88.25 253.73 8935.80 4297.22 1470.20 5963570.15 644716.88 1030.38 12.00 270.78 MWD 11775.00 88.30 250.73 8936.56 4289.60 1446.41 5963562.07 644693.24 1046.51 12.00 270.87 MWD 11800.00 88.35 247.73 8937.29 4280.73 1423.05 5963552.76 644670.05 1061.63 12.00 270.96 MWD 11825.00 88.40 244.72 8938.00 4270.66 1400.18 5963542.26 644647.38 1075.68 12.00 271.05 MWD ) ') .Ii. BAIC8It IUGIIIS INTEQ ObP BP Baker Hughes INTEQ Planning Report COIIIpany: BPAmoco Fiéld: Prùdh~8ay Site: PBH Pad Well: H-14 Wellpath: Plan#8(CTD)H-14B Survey MD lod AZim SSTVD ft deg ~Øg ft 11830.31 88.42 244.09 8938.15 11850.00 88.42 246.45 8938.69 11875.00 88.42 249.45 8939.38 11900.00 88.43 252.45 8940.06 11925.00 88.45 255.45 8940.74 11950.00 88.47 258.45 8941.42 11975.00 88.49 261.46 8942.08 12000.00 88.52 264.46 8942.73 12025.00 88.55 267.46 8943.38 12050.00 88.58 270.46 8944.00 ¡Þate:>914/20Q2 -.- 'Time: >14:51:54. .- . ~r~iA~~)Re(~~~~: Well: H~1~tTm~NóJth .ve"'cal~)Ref~..ee: SY$!~m:M~n>~t¥lL~vel Sectio~(VSrRefeNDçe: .. Wen(0'(~O~10.00E,3()2.00Azi) 'Surv~yçalelllatioD1\tetb04: - Minimum Curvature . Db: Oracle .Page: 4 NlS Tool ,ft 4268.36 1395.39 5963539.87 644642.64 1078.53 12.00 271.13 11 4260.13 1377.52 5963531.30 644624.93 1089.32 12.00 90.00 MWD 4250.75 1354.36 5963521.48 644601.95 1103.99 12.00 89.93 MWD 4242.60 1330.74 5963512.88 644578.49 1119.70 12.00 89.85 MWD 4235.69 1306.73 5963505.51 644554.62 1136.41 12.00 89.77 MWD 4230.05 1282.38 5963499.41 644530.39 1154.06 12.00 89.69 MWD 4225.69 1257.78 5963494.58 644505.87 1172.62 12.00 89.61 MWD 4222.63 1232.98 5963491.05 644481.14 1192.03 12.00 89.53 MWD 4220.86 1208.05 5963488.81 644456.25 1212.23 12.00 89.45 MWD 4220.41 1183.07 5963487.88 644431.28 1233.18 12.00 89.37 TD ) Nordic CTD BOP Detail ') /UI I o~ " CT Injector Head I 1 --- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ ~ Methanol Injection .ðJLð Otis 7" WLA Quick I J Connect - . I 7-1/16" ID, 5000 psi working pressure i- Ram Type Dual Gate BOPE - 7" Riser I I I ~ Annular BOP (Hydril),7-1/16" 10 5000 psi working pressure Manual over Hydraulic \.. ..J I I I I TOT k I CJ=I I Blind/Shear I t=e= ~ 12'318" Combi PipelSlI~ HCR I ~()) ~ [@~~ lt0mffiJlr~: I l . . 7-1/16" ID, 5000 psi working pressure ~ 2"Sideoutlets ~ :::I I 2 3/8" X 3 1/2" VBRs Ram Type Dual Gate BOPE I TOT I~. ~= I ~ @ 2 3/8" Combi Pipe/Slip Manual over Hydraulic c::: I I I I XO Spool as necessary \ / 2 flanged gate valves I I @ I I @ I I II THA I L ~ -- ~ Tubing @ ~ Inner Annulus í Spool ~ - I J -_C? @ ~ Outer Annulus Flanged Fire Resistant Kelly Hose to Dual Choke Manifold / Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpip( manifold / Full production christmas tree MOJ 9/15/02 1/ 1/ DATE CHECK NO. H 207046 8/01/02 H207046 VENDOR DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 8/01/02 CK073102M Permit To DriI~ Fee $100.00 H H -116 R E""(."'" -'.,:1 '.. t: r)'. ,,', ,~. t. ~ V lm ~"' ~F¡:') A 7 ''''002 ~",;-,I I. ~ .'--. PIs contactSondra Stewman X4750 for check pickup OH& AnchoraQ 3 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL .... $100.00 ! ' PAY III 20 7 0 ~ b III I: 0 ~ Ii 20 :l a q 51: 00 a ~" Ii q III '~ ~- TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should conûnue to be reported as a function' of the original API number stated above. 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 number (50 70/80) from records, data and logs acquired for well (name on permit). - The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate 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. WELL PERMIT CHECKLIST COMPANY AI)I WELL NAME fJ4Gf, ~/'7' A PROGRAM: Exp - Dev ~ Redrll X Re-Enter - Serv - Wellbore seg - FIELD & POOL t: ~ÓI.5 ~ INIT CLASS "..~y / -ó, J GEOL AREA ~ 7'" UNIT# II '5 ('i ON/OFF SHORE 6V ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ~ 'N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . , . . . . Y N p/lJ &1J;þ. 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N p-n-- I./- """........ 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . \'ú N (Service Well Only) 13. Well located w/in area & strata authorized by injection order #:..-- . Y YA/.,4 ~ (Service Well Only) 14. All wells w/in ~ mile area of review identified. . . . . . . . .. YN ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . CJ) N 16. Surface casing protects all known USDWs. . . . . . . . . . . t5IJ N 17. CMT vol ádequate to circulate on conductor & surf csg. . . . . .y N - 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . .Y. N . L 19. CMT will cover al..1 kno.wn productive horizons. . . . . . . . . . ~ N À-dR~' (AJ. ~,ref .f1-1/' C~ ç <. . 20. Casing designs adequate for C, T, B & permafrost. . .. . . . . N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N c.T PiA. 22. If a re-drill, has a 10-403 for abandonment been approved. .. X- Y N 23. Adequate wellbore separation proposed., . . . . .. .. . . . /5P N 24. If diverter required, does it meet regulations. . . . . . . . . . ~ N ""11t- 25. Drilling fluid program schematic & equip list adequate. . . . . & N 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . IN 27. BOPE press rating appropriate; test to S~ 00 psig. e N ýV/):; P ¿2ßtO (J~r. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N WC; It- 'l/lq! DL 29. Work will occur without operation S.h.utdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . .. N 31. Mechanical condition of wells within AOR verified. . . . . . . . Y N lli/I!r Y~ 1 jU,(1. RESERVOIR ENGINEERING UIC ENGINEER JDH ,,~ JBR APPR DATE (Service Well Only) GEOLOGY APPR DATE 1ft: m,42- (Exploratory Only) Rev: 07/12/02 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact name/phone for weekly progress reports. . . . . . . . GE~ RP PETROLEUM ENGINEERING: TEM SFD- WGAWG/r- MJW G:\geology\permits\checklist.doc COMMISSIONER: COT DTS () /1 ( ?j 0 ?.. ) Comments/lnstructions:
