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193-024
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ECEll V IALI nn �n!n 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutA �n dSuspentl ❑ Perforate 0 Other Stimulate 0 Alter Casing ❑ Change ApprtllT�rtla�l9y Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Mud Acid 0 2. Operator Name: BP Exploration (Alaska), Inc 4, Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 193-024 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigrephtc ❑ Service ❑ 1 6. API Number. 50-029-20212-01-00 7. Property Designation (Lease Number): ADL 028327 e. Well Name and Number: PBU 09-04A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth. measured 10106 feet Plugs measured None feet true vertical 9207 feet Junk measured 10060 feet Effective Depth: measured 10066 feet Packer measured 9315 feet true vertical 9169 feet Packer true vertical 8458 feet Casing: Length: Size: MD: TVD. Buret: Collapse: Structural Conductor 77 20" 34-111 34 - 111 1530 520 Surface 2675 13-3/8" 33-2708 33-2707 5380 2670 Intermediate 8608 9-5/8" 31-8639 31 -7845 8150 / 6870 5080/4760 Production Liner 1635 7" 8471-10106 7708-9207 8160 7020 Perforation Depth: Measured depth: 9495-9916 feet True vertical depth: 8629-9027 feet Tubing (size, grade, measured and true vertical depth) 7" 29k x 7` 260 z 5-1/2" 178 x 41/2" 12.88, 13Cr80 28-9464 28-8599 Packers and SSSV (type, measured and 4-1/2" Baker SABL-3 Packer 9315 8458 true vertical depth) No SSSV installed 12. Stimulation or cement squeeze summary: Load well with 100 bbls of 3% NH4CL & 253 bbls of diesel. Pump 53.6 bbls of 12% HCL & 53.4 bble of 9:1 mud acid in two stages with Sbbls of Oilseeker, reciprocating across parts from 9470' to 9600'. Intervals treated (measured) : 9470 - 9600 Treatment descriptions including volumes used and final pressure: 53.6 bola 12% HCL, 53.4 We 9:1 Mud Acid Final Pressures. OA = 667 psi, IA = 1635 psi, TBG = 277 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 608 0 11685 1677293 Subsequent to operation: 599 13928 12961 1658 297 14. Attachments: (reamrea per 20 A4c 25.07025.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ I GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Suntlry Number or N/A if C.O. Exempt: WA Authorized Name: Alatalo, Travis Contact Name: Alatalo, Travis Authorized Title. Production Engineer Contact Email Tmvis.Alatalo(Mbp.com Authorized Signature: Date: 01, Contact Phone: +1 9075645351 Form 10-404 Revised 04/2017 Ma'R-`Z RgDMS-JAN 0 3 1019 �/ r� Submit Original Only TED W/ 10'x 2-7/8" DUMMY GUN W/ TEL, /2.50" SAMPLE BAILER ATED TT @ 9,437' SLM (9,547' MD) (+20' correction) TD @ 9,903' MD (-9' FILL) ri i r, - N TACT PAD OPERATOR AND SHUT IN WING PERFORATING) PIAL T/I/O = 800/2400/800 PSI UP, PT LUBRICATOR TO 3700 PSI W/ 5'X 2.88" POWERJET OMEGA HSD, 6 SPF, 60 DEG PHASE. DAL = 29', CAW = 300 MAX OD = 3.16" (GUN SWELL IN FLUID). INTO SCHLUMBERGER PERFORATING RECORD DATED 22 -MAR -1993. ;FORAYED INTERVAL = 9571' - 9 76'. CL TO TOP SHOT = 3.4', CCL STOP DEPTH = `L T/I/0 = 2000/1700/750 PSI. VbR ....,m 'ucu on 7Z-04-18... - ...... -1 , ,..,u ndnaung, continued from 12-03-18••• (LRS Unit 70 - Freeze Protect TBG &Flowline) Sze Protect Flowline w/ 5 bbls 60/40 followed by 55 bbIs crude. Freeze Protect Tubing w/ 95 bbls le. WV, SSV= closed; MV, CV's= open 4P'c _ SSV.Swab continue from WSR 12/05/18, S/B for W/CS,IdleMant barnme, pop flow v -,-S well continue on WSR 12/7/18 CTU#8 1.75". Job Scope: Acid Stimulati RIH 2.24" JSN. Kill well. Tag 10'. Load well with 100 bbls of 3% NH4CL & 253 bbls of diesel. 1. on Pump 53.6 bbls TD at 99of 12% HCL & 53.4 bbls of 9:1 mud acid in two stages with 6bbls of Aseeker per SOR, reciprocating across perfs from 9470' to 96001. Pooh. Rig down CTU. Turn well Wer to Well Testers. "Job Comnlera••• mit 1. Inlet 1,ell09-O = Continue WSR from 12/07/18utlet well 09-02. Curcent barriers IL - Hardline, Separator. OL - , POp 09.04, flow to tanks with acid returns, well PH7 L2 tp prodUCtion SI & re poo flow well. Contini ,I -- -02._ Test Unit 1. Inlet well 09-04, Outlet well 09-02. Current barriers IL -Hardline, Separator. OL - Swab Continue WSR from 12/08/18, flow well, stablize well Continue inon WSR 12/10/18 Test Unit 1. Inlet well 09-04, Outlet well 09-02. Current barriers IL - Hardline, Separator. OL - Swab Continue WSR from 12/09/18, flow Well. 12 hr }ccs on I-- . THEE 6-3/8' (TN VYBLFEAD= FMC A(.'RIATOR= OTS OKB. ELEV = 54' BF. ELEV = WA KOP= 3500' Max Angle = 39' @ 5509' Datum MD= 9733' Datum TVD = 88OVSS 13CR NSOC, .0383 bpf, D = 6276- -31W CSG,72#, MN -80, D= 12.347" Minimum ID = 3.726" @ 9446- 4-112" OTIS XN NIPPLE SGA 7#, 13CR NSCT, .0232 bpf, D = 4.892" TOPOFTWTEIACKSLV --F 19-5/8" X 7" TIW DTHS HGR I 647W 9-51" CSG, 47#, MN -80, D = 8.681 • —8638 D = 3.958' PERFORATION SLIA"RY REF LOG: BHCS ON 0225193 ANGLEATTOPPERF 18"09495 Note: Refer to Production DB for historical perf data SIZE SPF HTERVAL Opn/Sgz SHOT SQZ 2-7/8" 6 9495-9525 O 0721/15 3-318" 6 9515-9525 O 12/06/11 3-3/8" 4 9528-9654 O 04/03193 2-718" 6 9528-9554 O 0721/15 33/8" 4 9538 - 9554 O 09/18!95 2-718" 6 9559-9565 O 0721/15 2-718" 6 9573-9578 O 12/03/18 3318" 4 9604-9612 O 0022193 2-71' 6 9604 - 9612 O 0721115 3318' 4 9622-9650 O 03127/93 2-71' 6 9622-9635 O 0721/15 331' 6 9658-9665 O 072578 3316" 4 9814-9818 O 1223194 3318" 8 9814-9818 O 09118M 2-71" 6 9814-9818 O 0720115 2-71" 6 9856 -9863 O 05/18/17 331' 4 9866-9880 O 09/18195 2-71" 6 9866-9888 O 0720115 3-3/8' 4 9912-9916 O 1223194 09-04A SAFETY NOTES: CHROME TBG BLNR--' 1 9467' 1 CAMOO BAL-0 SSSV N, D = 5.937" 1.ii:AriN CP -F711 261,',1: 1::::161 ST MD TVD DEV TYPE VLV LATCHIPOgrl DATE 1 3257 3256 6 OTIS DOME RM 16 04/05/15 2 4036 4014 15 OTS OW RA 0 03/01/93 3 4534 4494 21 OTS DMI' RA 0 06111/93 4 5114 5003 35 OTS DM' RA 0 03/01/93 5 5731 5491 38 OTS DOME RM 16 04/05/15 6 6389 6010 38 OTS DMV RA 0 03/01/93 7 7009 6506 35 OTIS DW RA 0 030/93 8 7630 7013 35 OTIS SO RM 32 0327/16 9 8170 7461 34 OTIS DAA/' RA 0 03101/93 10 8396 7646 35 OTS DMY FW 0 06/03/14 1 9-5/8" FLOUT ffl DOW (09-04A) 8639' - 8680' (SEM)OtQ 9293' H4-12" OTS X NP, ID= 3.813" 1 9308' 7" X 4-12" BKR SABL-3 HYD ROt, 1).4.000" 7" LNR, 29#, 19 -CR .0371 bpf, D = 6.184" 1-i 10106' DATE RE/ BY COMMENTS DATE REV BY COATBWS 05!76 ORKANAL COMPLETION 07/30/18 J ADPERFS (07)25/18) 03/01193 FVGSIDETRACK(09-04A) 08101/18 VWMME DEPTH COFJWnON TO ADPERFS 03/30116 W"JME GLV C/O (03r27116) 12/13118 IXWIJME ADPERFS (12!03/18) 06/14/16 CIWJMD PULLED ROCK SCREEN(06/12116) 0522/17 lAW/JME ADPEWS (05118/17) 05!30/18 BS/JMD PERF OOWECT10PS 14-12"OTS XN W,, D=3.725" 1 9646' 1-J7"MARKER PRRl1I HOE BAY U94r WELL: 09-04A PEFWr No: 1930240 AR No: 50-29-20212-01 T10N. R15E 406 FSL 8 7,W FB BP Exploration (Alaska) STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate RI Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 193-024 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20212-01-00 7. Property Designation(Lease Number): ADL 0028327 8. Well Name and Number: PBU 09-04A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL iiK� 11.Present Well Condition Summary: `E C E'V E D Total Depth: measured 10106 feet Plugs measured feet t JUN I � O 2 0 i true vertical 9207 feet Junk measured 10060 feet J '' 1I 7 Effective Depth: measured 10066 feet Packer measured 9315 feet w�� true vertical 9169 feet Packer true vertical 8458.4 feet (�„/1fVr1 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20"94#H-40 35-111 35-111 1530 520 Surface 2674 13-3/8"72#MN-80 33-2708 33-2707 5380 2670 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment 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 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED JUL 212017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 440 1290 8112 1637 261 Subsequent to operation: 487 1223 10211 1670 263 14.Attachments:(required per 20 AAC 25.070.25.071,a 25283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Stechauner,Bernhard Contact Name: Stechauner,Bernhard Authorized Title: FS2 Lead PE Contact Email: Bernhard.Stechauner@bp.com Authorized Signature: -.....,;,;.--''' Date: (.3/(9/ 1 7 Contact Phone: +1 907 564 4594 Form 10-404 Revised 04/2017 ����j7 V f `111 C i RBDMS V_ JUN 2 6 2017 Submit Original Only • S RECEIVED JUN 2 0 2017 AOGCC Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary June 19, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Adding of Perforations for Well 09-04A, PTD # 193-024. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • S .O• O O O O O O O O O O O O to N N N N CON- CO CO CO CO CO O CO 0 0 0 I— IN- O O Cr O N LO 0 N O LO LO V' V N- N- LO I— CO IN- U (n• 0 0 0 0 0 0 0 0 0 0 0 0 0 ti- CO CO LO LO O ti N- CO CO c O V CO • LO CO CO CO m LO co co co co CO co co N- co N- CO I� 6) Cr CO I- O 6) CO CO CO LO 6) O •— CO N N LO ' CO 6) I� M O N co co N N N CO CO CV N N N I- N CO O N CO f— CO H O V CO N- CO 6) CO CO LO LO M CO N N O Cr CO CO CO CO co -4' L1) N N- CO N N N CO N N N I- N- CO N CO IN- ++ QDCO O CO N- LO 6) NCD Cr 6) Cr CO N 00 Cr 6) N- co LO co CO r `O N N N N N N I— 00 O N CO CO 6) V 0 Q0) NI- CO 0) co v 6) 0 LC) M CO N CO I- 6) 00 CO co co co •T LO CO d' '— N N CV Cr =Q) N N N I- CO 6) N CO CO co I— O L1) LO p CO a OcornLrn0co OpoCO L AZO O ZOOC, DoCUM ' OcnOZ2 °oUUUco ,- ti C N 4:k CNI 00 V CO V 00 _ N CO N O M O L[) DO 11) co CV CV N CV LU 0) LU 6) O N- N- N 6) 6) d) O ' V t • CO L) O co co co CO O Lf) C N- O N (0 M N '— 6)LO CO ON O d N N LO 1� 1- C) N 6) LO J ZZZZZ cm 0 0 0 0 0 CF— wHHHF- f- V) 0000000 LaDQ » DDD 0000 U 0 u. 0 0 0 0 0 c Z Z Z Z Z W O O O O O w w m COm m O 0 CCCCCCCCZ Z 0 0 0 0 Ucn0_ ddCL F- F- F- F— • • • 0 N 0 CO O 1� O OD = V CflCr V r- v- co co s IC) O CO LO in LC) LC) N V N 1` 4- CO Co) CO IL O (xcr O O CO r- Lo QD r- N O co y 4- LC) co ti ") coCO CO cco 1` r, N- co O) O N O QD CO 00 CO co CO N- N- N- N 6) 6) O) O O 00 CO CO 00 Co OD Co OD O CO OD O O > I- o.Q O I- = 6) NO) N N V CO N N OD N- •- co .c CO LL) 6) OD M O) 6) LO N V ,- Lo 4- co O a OD OD O r- w CO N c O N LC) Cfl N- co M V LO CO M N- 0- OD 6) N W 0 CO CD QD CD CO N- 0- N- N- 6) O) CD 6) CD O > O OD OD Co CO CO OD Co OD CO CO CO OD CO Co o) 0 > 2 1- w CC 0 W Z 0 0 O w 0 I- H w O0 0 O m O O w Y Y F-C) CD LijC cC ++ aLij � NC") IC) Ccr OO � CC") CC"CD )�) LLUv 00 Lo COOODCOOOD � J J < < Z d LO 41 LO 40 LO Ln CO CO Cfl QD Co Co Co Co Co CD < < 0 w0 0 0 0 0 W 0 O O O O O O O O O O O O O O O O O _ _ ZO -JD O D CD v) O 0 J Wa 0 a a E m OHO .0 E wwwQZ O Z ~ ¢ o 0 Q 2 O i) 0) vcn 0)) a 0. C C « Lo LO ao oo CO O cr N O LC) Nr CO CO CO O N O = O- d) r- NCO LO C") Lo O NCO CO Lo CO CO CO N- M d 4. Lo co LO Lo co coco CD Co CO Co co co o) . W a O) O O CS) O O C)) 0 0 0 0 0 0 0 0 O) N 0a2 rIcn 00 cn W It 20W0 coco0) a) a. O 0 c 2 LL LL LL u_ LL LL LL LL LL_ oc LL LL_ LL LL LL LL a d d CL CL d d CL d CL W d d CL CL 11 11 CD Q Q Q Q Q Q Q Q Q a Q Q Q Q Q Q a O t m a a) F- O 40 LO u) L1) LL) 40 LC) Ln Ln Lo Ln 0- LO 41 Lo c0 0 c CD 0 0 0 CD CD 0 0 0 0 0 0 0 0 0 °) w Z O N N N N N N N N N N N N N N N Z Z 1717 < W N N N N N N N N N N N 00 O N N CO 0 a w 0 1J OW LLI CC W w W o_ ti N- N- I N- ti N- I f N- N- LO N- 1- N " a a J 1- J J D J D CC a O J J < < a cwi) u. Li ..On Lai d a w m E Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Z v v v v v v v v v v v 4- c) CD 0 0 CD 0 0 0 0 CD 0 CD0 0 0 0 w LL a Ch O LL N CC 0 0 0 0 0 0 0 0 0 0 1 I I 0 0 0 0 0 0 030- 0_ 0_ 0 _, a a a 0 J 0 0 W a O O O O O O O O O O O O C) O OO < a m m LL LL Ch Cn a W 4110 • Packers and SSV's Attachment PBU 09-04A SW Name Type MD TVD Depscription 09-04A PACKER 8479.73 7714.77 7" TIW Liner Top PKR 09-04A TBG PACKER 9315.41 8458.4 4-1/2" Baker SABL-3 Packer 0 0 Z:7) / k 03 / • § I G 2 \ 0 \ iii ± b _ \ / E / = z0 R % 0W _1 / 0 \D co O 7 ± * I ® � • # / f 7 / E 0 ■ >- 2 \ \ \ \ ± o >- / '- 0 ƒ I 2 / e cc D O) = u kI / 6 E ■ < O o .a E o 0 < _\ \ k 0 7 k ©\ W \ — v a_ x cl/ / / / -1 / / _/ 9 cG / d �� a / f 15— ° CO/ E ® � � 4- ± _ / _JZI---- 0 : i 2 E a ,? < c 0 _, t 03 _1 0 = I « G R O e R < 0 / O $ 2 : < 7 I - \ J \ ■ 2 / § 0 ƒ EI / 2 % 0g Ce < O HD < Ian ® m Z p E / ± Z / / < < Li] / « CI 0 0 f u ƒ 0 \ / \ I < - Z 6 ° 0 0 Z 2 0- % I- \ I- " ® ° c -I I � 0 e a < g2 = R E / H $ / / - \ < 0 \ 0 y / 2 \ A ct 0 w 7 O 2m20 -I ± yH2F- j a / \ / \ % C / IE ? w / § ; R c / » E _ % t 5 L I I- 0 % % 0 0En / C. / & 5 \ \ / < IILL= 6-3/8"CMf 0 r WELLHEAD= AMC', 0 9_O4 4 SAFETY NOTES:CHROME TBG&LNR"'" ACTUATOR= OTIS' OKB.ELEV= 54 BE ELEV= N/A 2153' ---1 7"CAMCO BAL-O SSSV N,ID=5.937" KOP= 3500' Max Angle= 39"@5509' Datum MD= 9733' Datum TVD= 8800'SS /c " 2333' —9.5/8"FOC /r" ..______......4,_ 2456' H9-5/8"FOC 7"TBG,26#,13CR NSCC,.0383 bpf,13=6.276" — 2210' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,MN-80,D=12.347" H 2701' v. 1 3257 3256 6 OTtS DOME RM 16 04/05/15 2 4036 4014 15 OTIS DMY RA ' 0 03/01/93 7"MG,29#,13CR NSCC,.0371 bpf,ID=6.184" — 3208' ! �� 3 4534 4494 21 OTIS WV RA ' 0 06/11/93 / 7"X 5-1/2" XO,D=4.892" --I 3210' / 4 5114 5003 35 OTIS DMY RA 0 03/01/93 L 5 5731 5491 38 OTIS DONE RM ' 16 04/05/15 6 6389 6010 38 OTIS DMY RA ' 0 03/01/93 Minimum ID = 3.725" @ 9445' 7 7009 6506 35 OTIS DMY RA ' 0 03/01/93 4-1/2" OTIS XN NIPPLE 8 7630 7013 35 OTIS SO RM ' 32 03/27/16 9 8170 7461 34 OTIS DMY RA ' 0 03/01/93 10 8396 7646 35 OTIS DMY RM ' 0 06/03/14 5-1/2"TBG,17#,13CR NSCT,.0232 bpf,D=4.892" —I 8413' TOP OF TIW TRACK SLV --F- 8465' \ f 8415' —j 5 112"X 4-112"XO,ID=3.958" 9-5/8"X 7"TNV LG-6 PKR —I 8474' 9-5/8"X 7"11W DTHS HGR 8479' 7 9-5/8"MLLOUT WINDOW (09-04A)863V-8680' (SECTION) 9-5/8"CSG,47#, t4-80,ID=8.681" — —8639 '� 9293' H4-1/2"OTIS X NP,13=3.813" -1. 9309' -17"X 4-1/7 BKR SABL-3 HYD FCR,D=4.000" TA' 9427' H4-112"PARKER SWS NIP,ID=3.813' 4-1/2"TBG,12.6#,13-CR,.0152 bpf,ID=3.958" — 9457' 1 9445' H4-1/2'OTIS XN la',13=3.725" PERFORATION SLL?AARY REF LOG: BHCS ON 02/25/93 9457' —I4-112"WLEG,D=3.958" ANGLE AT TOP FERE: 18°@ 9495' ` Note:Refer to Roduction DB for historical perf data 9546' 7"MARKER JT 20 SIZE SPF INTERVAL Opn/Sqz SHOT SQZ ( ) 2-7/8" 6 9495-9525 0 07/21/15 3-3/8' 6 9515-9525 0 12/06/11 3-3/8" 4 9528-9548 0 04/03/93 ` 10060' —FISH-BOW SPRING 2-7/8" 6 9528-9554 0 07/21/15 DEC ENTRALIZER 3-3/8' 4 9538-9554 0 09/18/95 ` (LOST 04/01/93) 3-3/8" 4 9548-9554 0 04/03/93 2-7/8' 6 9559-9565 0 07/21/15 3-3/8' 4 9604-9612 0 03/22/93 2-7/8" 6 9604-9612 0 07/21/15 ` 3-3/8" 4 9622-9630 0 03/22/93 2-7/8" 6 9622-9635 0 07/21/15 3-3/8" 4 9814-9818 0 12/23/94 S -1111401, 3-3/8" 8 9814-9818 0 09/18/95 MID 10066' ���1�`�11 2-7/8" 6 9814-9818 0 07/20/15 t`\`\��\i�► 2-7/8" 6 9856-9863 0 05/18/17 `�;��► 3-3/8" 4 9866-9880 0 09/18/95 7"LNR 29#,13-CR, 0371- bpf,D=6.184" --I 10106' �► 2-7/8" 6 9866-9888 0 07/20/15 3-3/8" 4 9912-9916 0 12/23/94 IDATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/76 ORIGINAL COMPLETION 03/30/16 MGS/JMD GLV C10(03/27/16) WELL: 09-04A 03/01/93 RIG SIDETRACK(09-04A) 06/14/16 CJWJMD FULLED ROCK SCREEN(06/12/16) PERMIT No:'1930240 04/07/15 SWC/JML"1GLV C/O(04/05/15) 05/22/17 NXW/JMC ADFERFS(05/18/17) AR No: 50-029-20212-01 08/07/15 DLW/JMD ADPE FS(07/20-21//15) SEC 2,MN,R15E,405'FSL&746'FEL 08107/15 JTG/JMD SET ROCK SCREEN(07/23/15) 03/30/16 DLI-VJMD PULL/RESET ROCK SCREEN BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMA. • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 193-024 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20212-01-00 7. Property Designation(Lease Number): ADL 0028327 8. Well Name and Number: PBU 09-04A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: /@ f D Total Depth: measured 10106 feet Plugs measured None feet AUG2 �( true vertical 9207 feet Junk measured 10060 feet A 1 2015 Effective Depth: measured 10066 feet Packer measured 8486.09,9321.77 feet true vertical 9169 feet Packer true vertical 7719.97.8464.42 feet AAOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20"94#H-40 36-112 36-112 1530 520 Surface 2674 13-3/8"72#MN-80 35-2710 35-2709 5380 2670 Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 728 7"29#L-80 8478-9205 7713-8355 8160 7020 Liner 913 7"29#13CR80 9205-10119 8355-9219 8160 7020 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feeo NOVMO I Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 304 377 10330 1739 245 Subsequent to operation: 237 4067 4428 1714 522 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Summerhays,Nita M IPRO Technologies) Email Nita.Summerhays@bp.com Printed Name Suufm/merhay Nit- (WIPRO Technologies) Title Petrotechnical Data Manager Signatukv`�� %�L/J / , Phone +1 907 564-4035 Date 08/12/2015 Form 10-404 Revised 5/2015 V "L /2 LA ��� �� RBDMS C AUG 1 4 2015 7.7 Submit Original Only • • Daily Report of Well Operations PBU 09-04A ACTIVITYDATE SUMMARY ASRC Test Unit 1. Flow back/Monitoring for Crystal Seal. Unit Move, NPT-ASRC Equipment, 7/11/2015 Begin Rig-up. ***Continued on WSR 7-12-15""" ASRC Test Unit 1. 09-04A Flowback/Monitor for Crystal Seal. ***Continued from WSR 7-11-15 """ Continued Rig-Up, STBY For Gen Set, Complete Rig Up, Pressure Test, STBY for DSO, POP Well, Flow Stabilize Well. Inlet Well 09-04A, Outlet Well 09-05. ***Job in Progress Continued on WSR 7- 7/12/2015 13-15 """ ASRC Test Unit 1. 09-04A Flowback/Monitor for Crystal Seal. ***Continued from WSR 7-12-15""" Continued to Flow Stabilize Well. Begin 12 Hr Well Test Inlet Well 09-04A, Outlet Well 09-05. """ 7/13/2015 Job in Progress Continued on WSR 7-14-15""" ASRC Test Unit 1. 09-04A Flowback/Monitor for Crystal Seal. ***Continued from WSR 7-13-15""" 7/14/2015 Complete 12 Hr Well Test. Rig Down Inlet Well 09-04A, Outlet Well 09-05. ***Job Complete""" ***WELL S/I UPON ARRIVAL***(perforating) RIG UP SWCP 4518 7/15/2015 ***WSR CONTINUED ON 07/16/15*** T/I/O=ssv/150/450 Assist Well Tester's with freeze protects-Spear in to F-line with 5 bbls of meth followed by 30 bbls of 100*crude shut IGV& psi up to 500 psi with 1.2 bbls of meth Wing shut 7/15/2015 swab shut ssv shut master open casing valves open to gauges Final Whp's=ssv/150/450 T/I/0=1900/650/0 Temp=SI Assist ASE testers F-protect Spear in to TBG with 2 bbls of meth followed by 93 bbls of crude Wing shut swab shut ssv shut master open casing valves open o 7/15/2015 gauges Final Whp's=1883/650/0 ***WSR CONTINUED FROM 07/15/15"""(perforating) DRIFT W/30'x 2-7/8" DUMMY GUN, 4-1/2"TEL& 1.75" S. BAILER, LOC TT @ 9,430' SLM(+27' CORR) = 9,457' MD, TAG TD @ 9,866' SLM/9,893' MD(+27'CORRECTION) MADE 3 RUNS W/ 15'x 3" PUMP BAILER @ 9,852' SLM RAN 4 1/2" BRUSH, 3" GAUGE RING TO 9,855'SLM. CONTINUE RUNNING 15'x 3" PUMP BAILER (4 RUNS- RECOV—8 GALS OF FORMATION SAND) 7/16/2015 ***CONT WSR ON 7/17/15""" ***CONT WSR FROM 7/16/15"""(perforating) MADE 4 RUNS W/ 15'x 3" P-BAILER. MADE 1 RUN W/ 10'x 2.50" P-BAILER RECOVERED —11 GALLONS OF SAND FROM 9,865' SLM. 7/17/2015 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** ***WELL SHUT IN ON ARRIVAL*** (perforating) RAN 3.50"CENT, STAR BIT CHISEL TO 9866'SLM LOCATED TUBING TAIL AT 9,434'SLM WITH A CORRECTION OF 23' &TAG TD AT 9,818' CORRECTED MD MADE 4 RUNS TO 9,895' SLM W/ 15'x 3.0 PUMP BAILER & RECOVERED—17 GALLONS OF CRYSTAL SEAL/CEMENT MIX 7/18/2015 ***CONTINUE ON 7/19/2015*** """CONTINUE FROM 7/18/2015""" (perforating) MADE 7 RUNS W/ 15'x 3.0" PUMP BAILER TO 9,895' SLM (RECOVERED—18.5 GALLONS OF CEMENT/CRYSTAL SEAL MIX) 7/19/2015 ***CONTINUE ON 7/20/2015""" o • Daily Report of Well Operations PBU 09-04A ***WELL S/I UPON ARRIVAL*** (ELINE-PERFORATING) INITIAL T/I/O = 1850/700/0 PSI RIH W/4' POWERJET OMEGA HSD GUN/TAG UP AT 9907'/UNABLE TO REACH INTERVAL FROM 9910'-9914'/CHANGE TO NEXT 4' INTERVAL/CCL TO TOP SHOT=4.45'/CCL STOP DEPTH = 9807.55'/ PERFORATE FROM 9812'-9816'/CORRELATED TO SLB PERFORATION RECORD DATED 22-MAR-1993/SHOTS CONFIRMED AT SURFACE RIH W/22' POWERJET OMEGA HSD GUN/CCL TO TOP SHOT= 7.29'/CCL STOP DEPTH = 9856.71'/ PERFORATE FROM 9864'-9886'/CORRELATED TO SLB PERFORATION RECORD DATED 22-MAR-1993/SHOTS CONFIRMED AT SURFACE. RIH W/ 13' POWERJET OMEGA HSD GUN/CORRELATED TO SLB PERFORATION RECORD DATED 22-MAR-1993 7/20/2015 ***JOB CONTINUED ON 21-JUL-2015*** ***CONTINUE FROM 7/19/2015*** (perforating) RAN 15'x 3.0" PUMP BAILER TO 9,893' SLM (recovered —2 gallons of cement/cystal seal mix) 7/20/2015 ***WELL LEFT SHUT IN ON DEPARTURE, DSO NOTIFIED*** ***JOB CONTINUED FROM 20-JUL-2015*** (SLB ELINE- PERFORATING) RUN 3 (CONT): CCL TO TOP SHOT= 10.33'/CCL STOP DEPTH = 9609.67'/PULL INTO POSITION/UNABLE TO SEND ENOUGH VOLTAGE BEFORE CURRENT PEGS OUT/UNABLE TO POWER UP UPCT/BASED ON RESISTANCE FROM LOGGER, NO SHORT IN HEAD/ POOH TO CHANGE TOOLS. RUN 3 (ATTEMPT 2): RIH W/20' HSD LOADED WITH 13' POWERJET OMEGA HMX/CCL TO TOP SHOT= 10.33'/CCL STOP DEPTH = 9609.67'/PERFORATE INTERVAL 9620'-9633'/ CORRELATED TO SLB PERFORATING RECORD DATED 22-MAR-93/CONFIRMED SHOTS AT SURFACE. RUN 4: RIH W/ 10' HSD GUN LOADED WITH 8' OF POWERJET OMEGA HMX/CCL TO TOP SHOT= 5.29'/CCL STOP DEPTH = 9596.71'/PERFORATE INTERVAL 9602'- 9610'/ CORRELATED TO SLB PERFORATING RECORD DATED 22-MAR-1993/CONFIRM SHOTS FIRED AT SURFACE. RUN 5: RIH W/ 10' HSD GUN LOADED WITH 6' OF POWERJET OMEGA HMX/CCL TO TOP SHOT= 7.29'/CCL STOP DEPTH = 9549.71'/PERFORATE INTERVAL 9557'-9563'/ CORRELATED TO SLB PERFORATING RECORD DATED 22-MAR-1993/SHOTS CONFIRMED FIRED AT SURFACE. RUN6: RIH W/26' HSD GUN LOADED WITH 26' OF POWERJET OMEGA HMX/CCL TO TOP SHOT= 3.46'/CCL STOP DEPTH = 9522.54'/ PERFORATE INTERVAL 9526'-9552'/ CORRELATED TO SLB PERFORATING RECORD DATED 22-MAR-1993/SHOTS CONFIRMED FIRED AT SURFACE. RUN7: RIH W/30' HSD GUN LOADED WITH POWERJET OMEGA HMX/CCL TO TOP SHOT= 4.3'/CCL STOP DEPTH = 9488.7'/ PERFORATE INTERVAL 9493'-9523'/CORRELATED TO SLB PERFORATING RECORD DATED 22-MAR-1993/SHOTS CONFIRMED FIRED. SLB RIG DOWN. WELL S/I AND SECURED. HAND OVER TO DSO. FINAL T/I/O = 1865/700/0 PSI 7/21/2015 ***JOB COMPLETE*** • • Daily Report of Well Operations PBU 09-04A ***JOB CONTINUED FROM 20-JUL-2015 ***(SLB ELINE- PERFORATING) RUN 3 (CONT): CCL TO TOP SHOT= 10.33'/CCL STOP DEPTH = 9609.67'/PULL INTO POSITION/UNABLE TO SEND ENOUGH VOLTAGE BEFORE CURRENT PEGS OUT/ UNABLE TO POWER UP UPCT/BASED ON RESISTANCE FROM LOGGER, NO SHORT IN HEAD/ POOH TO CHANGE TOOLS. RUN 3 (ATTEMPT 2): RIH W/20' HSD LOADED WITH 13' POWERJET OMEGA HMX/CCL TO TOP SHOT= 10.33'/CCL STOP DEPTH = 9609.67'/PERFORATE INTERVAL 9620'-9633'/ CORRELATED TO SLB PERFORATING RECORD DATED 22-MAR-93/CONFIRMED SHOTS AT SURFACE. RUN 4: RIH W/ 10' HSD GUN LOADED WITH 8' OF POWERJET OMEGA HMX/CCL TO TOP SHOT= 5.29'/CCL STOP DEPTH = 9596.71'/ PERFORATE INTERVAL 9602'-9610'/ CORRELATED TO SLB PERFORATING RECORD DATED 22-MAR-1993/CONFIRM SHOTS FIRED AT SURFACE. RUN 5: RIH W/ 10' HSD GUN LOADED WITH 6' OF POWERJET OMEGA HMX/CCL TO TOP SHOT= 7.29'/CCL STOP DEPTH = 9549.71'/ PERFORATE INTERVAL 9557'-9563'/ CORRELATED TO SLB PERFORATING RECORD DATED 22-MAR-1993/SHOTS CONFIRMED FIRED AT SURFACE. RUN6: RIH W/26' HSD GUN LOADED WITH 26' OF POWERJET OMEGA HMX/CCL TO TOP SHOT= 3.46'/CCL STOP DEPTH = 9522.54'/PERFORATE INTERVAL 9526'-9552'/ CORRELATED TO SLB PERFORATING RECORD DATED 22-MAR-1993/SHOTS CONFIRMED FIRED AT SURFACE. RUN7: RIH W/30' HSD GUN LOADED WITH POWERJET OMEGA HMX/CCL TO TOP SHOT= 4.3'/CCL STOP DEPTH = 9488.7'/PERFORATE INTERVAL 9493'-9523'/CORRELATED TO SLB PERFORATING RECORD DATED 22-MAR-1993/SHOTS CONFIRMED FIRED. SLB RIG DOWN. WELL S/I AND SECURED. HAND OVER TO DSO. FINAL T/I/O = 1865/700/0 PSI 7/21/2015 ***JOB COMPLETE*** ***WELL S/I ON ARRIVAL*** (Perforating) RIG UP SWCP 4520 7/22/2015 ***WSR CONTINUED ON 7/23/15*** ***WSR CONTINUED FROM 7/22/15***(Perforating) DRIFTED TO & BRUSHED XN-NIP @ 9,445' MD w/3.80" G-RING &4-1/2" BRUSH. SET 4-1/2"WEATHERFORD SLIM-PAK SCREEN ON XN-LOCK @ 9,445' MD. RAN 4-1/2"CHECK SET TO 9,445' MD. (Sheared) 7/23/2015 ***JOB COMPLETE*** T/I/O = SSV/1980/800. Temp = SI. IA& OA FLs. (Pre OART). AL SI @ lateral valve, No IA companion. IA FL @ 7630' (Sta#8 SO, 280 bbls). OA FL @ 70' (5 bbls). 8/6/2015 SV, SSV= C. WV= LOTO. MV= O. IA&OA= OTG. 14:45 Fluids Summary BBLS Type 8 METH 30 CRUDE 99 OIL 6 DIESEL 143 Total • • G) 0 m• CA r- CA 00 r- V co 0- c- 00 LC) t LC) O d. 00 LC) LC) LO LC) N NT N .4 co M co ate) LC) co N- 0o0 CO 0) LCD 6 SC) UP 0- C 00 OD O N CP co Co CO CO CO CO 0- 0- 0- 0- 00 CA CA O O 00 00 00 CO 00 CO 00 00 00 00 0) CA > i- 0.0. 0 I- r- CT NCA N d' N- CO N 00 N- r- CO t CO Lf) CA . 00 C) CA CA L N t LC) 00 O 0. 00 N- CA CT CO C D 00 Cfl - O C3) N C`') m N rt Cn LU N- co C) V LO CO Com) N- CO CA N p CO CO Co N CO CO N- N- N- N- CA C D CA CA O p CO CO CO 00 00 00 CO 00 00 00 CO 00 CO CA > 1- 0 C) w Y m 2 W Y.U W a L LU CO 00 00 V LC) N C) CC) O 00 00 C) 00 CO w J Q U W 4 o. . N C'') V Lf) CO r- C'") C') 4) CO 00 00 a Q W a z C W LC) Ln LC) LC) LC) LC) CO CO Cfl CO 00 CO CO 00 CD U J w O J C) O CD CD CA CD (A (T (T (A O) CD CD 0) (T J JZOcu 0 p p p CP LIJ E d. gg = pa w a Zwu) Z p1_ p O .0 ooo Wcn• 4 2 o o cn CC CU 4 �I a 0 C Cli= n L.C) (N0 0 e4 0 O N O LM rV- fl 00 O N O = 0 d Ln L) C) LCL) D fl CO co co co co 00 cn :1173 CO p CT CA CA CA C ) 0) C)) o) CT C3) 0) 0) CA Ch Ch N aSa ; O E a cn Y 0 0 Ln a c 2 2 2 O ccnn c~n can cn an G) a. 0 730 0 c u. LL u_ a. u. u. LL_ u. LL. ct LL a. LL LL a. m a_ d a_ d d d O O d W d d 0 dn_ `m Q Q Q Q Q Q Q Q Q 0_ Q Q Q Q Q a O a, m a Cu H Q C) Lf L ) LC) Ln LC) Ln Ln LC) LC) LC) LC) LC) LC) LC) . p 0 0 0 0 C) 0 0 C) 0 0 0 0 0 C) C) w z O N N N N N N N N N N N N N N Z I Q W w _ \ \ O O O O M O w N N LL OS N N N N N N N N N N N N N N N p aIli J W p W a y N- N- N- N- N- N- N- N- Nc\I Z J U W W W LL W 0. 0- 0- L` 0- 0- 0- 0- C` r- L` r- ti r- r- < a J 1- -J J D J p a s O m O 0 W J -10R- O W W < < a cn Il LL cn LL cn a a C) E 2 « « « « « « « a ,rd- � � vvvvvvvNI- vv- v o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 , , 1 1 [ 1 1 Ll a cn O w N a LL CA 6) CA i (A CA (3) CA CA m a g a 0 J 0 0 W a O C) 0 0 C) 0 C) 0 0 0 0 0 0 C) 0 < < m m LL LL cn Cl) a s • • p.0 0 0 0 0 0 0 0 0 _O O O O N N- O M CO cr...? CO N N N 00 O _ Cfl O O O N- O O Lo O N Lf) • N In ti ti LU N- co N- U y co 0 0 0 0 0 0 0 0 0 0 0 0 i CO CO LO LO LO N- N- CO CO V (S) t CO • LO CO c- CO CO r N N- V M 1— LO CO CO CO CO CO CO 00 N- CO I- CO N CA I— O O) LO LO (7) N '— CV LO O NCO CO N LO LC) N— N N N- I� M LO N CO CO CV N N CO CO N N N N- N- CO CA N Cr) N- CO F▪- — N- O 0) M LO N r- N Cfl LO co N Co co N LO LO N N N- M CO Cr) Cr) LC) N N- Com) CO N N CO N N N I- N- co N M C Q� N O NN- — O N LO M N CO O N CO M O) LO O N N N N CO NT LC) CO CO N O N N cr N N N N I- CO O) N Cr) CO 0) III v o Q N I� C) CO Ln Cr) N CO CO LO M N CO M O I� O LO N N N CL CO CO CO CO LO CO V N CO N N 'Cr O) N N N N- CO Cr) N M CO 0 O LO LO O O coO d co ) LnrnOao c) (3,2 CDz0 C) OODzoCOco00 �) 2OO OZ2mvUUM M .� N k N *k Ns k �# *k CO • W m _ .4- - 4:k 4# U O M a0 00 CO N N N N N N C) L 0 LO N- N- N- O O 0) LO ✓ MLn O LO N M Cr) CO O LO N CO N- O COCN CO (") N- N O O ON O C) N N LO N LO Z Z Z Z Z 00 00000 '• 0 0 0 0 0 0 0 mD < DDDDD 0000 U O w O O O O O c Z Z Z Z Z rx0 0 0 0 0 w w m m m m ODCCCCIXZZDDDD U (n 0- Q_ d d d J J H f- F- TREE= 6-3/6'CNV 110 WFLLFfAD= FMC SA NOTES:CHROME TBG&LNR ACTOR= Crr►s 09-0 4A OKB.ELEV= 54' BF.ELEV= NA KOP= 3500 2153' —7'CAMCO BAL-O SSSVN,D=5.93r Max Angle= 39°©5509' I s Datum PA)= 9733' 2333' 9-5/8'FOC Datum TVD= 8800 SS 2456' 9-5/8'FOC r TBG,26#,13CR NS(X;,.0383 — GAS LFT M4PDF2ElS bpf,D=6.276" 2210' ST MD ND DEV TYPE VLV LATCH FORT DATE 13-3/8'CSG,72#,MN-80,D=12.34T -4 2701' , 1 3257 3256 6 OTIS DOME FINI. 16 04/I)5/15 2 4036 4014 15 OTIS DMY RA ' 0 03/01/93 3 4534 4494 21 OTIS DMY RA r 0 06/11/93 r TBG,29#,13CR NSC;,.0371 bpf,D=6.184' — 3208 4 5114 5003 35 OTRS DMY RA r 0 03/01/93 r X 5-1/7 XO,D=4.892" —I 3210' 5 5731 5491 38 OTIS DOPE RM r 16 04/05/15 L 6 6369 6010 38 OTIS DMY RA ' 0 03/)1/93 7 7009 6506 35 OTIS DMY RA ' 0 03/01/93 Minimum ID =3.726" @ 9445' 8 7630 7013 35 OTIS SO RM ' 32 04/05/15 4-1/2" OTIS XN NIPPLE 9 8170 7461 34 OTIS DMY RA ' 0 03/01/93 10 8396 7646 35 OTIS MY FIN ' 0 06/03/14 5-1/7 TBG,17#,13CR NSCT,.0232 bpi,D=4.892" — 8413' TOP OF TNV TIEBACK SLV —{ 8465' 8415' —5-1/2'X 4-1/2'XO,ID=3.958' 9-5/8'X 7"TIW LG-6 R<R H 8474' L J 9-58'X r TIW DTHS HGR — 8479' 8 / 9-5/8"MLLOUT Wr1DOW (09-04A)8639'-8680' (SECTION) 9-5/8"CSG,47#,144-80,D=8.681" — —8639 9293' 1H4-12"OTIS X NP,D=3.813' .% 9309' —{7'X 4-1/7 BKR SA BL-3 HYD PKR D=4.000" ik Yj 9427' —14-12"PARKER SW5 NP,D=3.813' 4-1/2'1.4k1)SLMPACK ROCK SCREEN(0723/15) ^ 9446' k 9445' —4-1/7 OTIS XN NP,D=3.725' 4-1/7 TBG,12.6#,13-CR.0152 bpf,ID=3.958' — 9457' 94.57' —4-1/2"WLE1G,D=3.958' ai R32FORATION SUMMARY REF LOG: BHCS ON 02/25/93 ANGLE AT TOP F . 18°©9495' 9546' I—7"MARKER JT(20') Note:Refer to Production DB for historical perf data SIZE SPF MERVAL C*n/Sgz SHOT SQZ 2-7/8" 6 9495-9525 0 07/21/15 10060' —FLS1-$-BOW SFRING 3-3/8" 6 9515-9525 0 12/06/11 OECENTRALTZER 3-3/8" 4 9528-9548 0 04/03/93 (LOST 04/01/93) 2-7/8" 6 9528-9554 0 07/21/15 3-3/8" 4 9538-9554 0 09/18/95 3-3/8' 4 9548-9554 0 04/03/93 2-7/8" 6 9559-9565 0 07/21/15 3-3/8' 4 9604-9612 0 03/22/93 2-78' 6 9604-9612 0 07/21/15 3-3/8' 4 9622-9630 0 0322193 \\, 2-78" 6 9622-9635 0 07/21/15 ;\111 , 3-38" 4 9814-9818 0 12/23/94 PBTD J 10066' 4%%\�\\\i' 3-3/8" 8 9814-9818 0 09/18/95 ��;�►, 2-78" 6 9814-9818 0 0720/15 7"LNR,29#,13-CR .0371 bpf,D=6.184",--I 10106' 3-3/8' 4 9866-9880 0 09/18/95 2-7/8" 6 9866-9888 0 0720/15 3-3/8" 4 9912-9916 0 12/23/94 DATE RE/BY CX)1VIENTS DATE REV BY (X*I&JTS PRLOI-DE BAY MT 05/76 ORIGINAL COMPLETION 04/07/15 S'M/JMC GLV GO(04/05/15) WELL: 09-04A 03/01/93 FIG SIDETRACK(09-04A) 08/07/15 DLW/JPO ADF6S(07/20-21/115) PERMIT No: 1930240 04/04/12 LECJJMD PULL PXN RUG(04/03/12) 08/07/15JTG/JMD SET ROCK SCREEN(07/23/15) AR No: 50-029-20212-01 04/19/12 PJC TI/814G CORRECTIONS SEC 2,T1ON,R15E,405'FSL&746'FEL 06/05/14 MJC/JMD GLV GO(06/03/14) 04/07/15 PJC TBG CROSSOVER D CXR RECTOtN BP Exploration(Alas ka) STATE OF ALASKA • AL .A OIL AND GAS CONSERVATION COMM. .JN REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well ❑ Plug Perforations 11 Perforate❑ Other 0 Crystal Seal Performed. Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WEI 2 Operator 4.Well Class Before Work 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development 0 Exploratory 193-024-0 3 Address P O Box 196612 Stratigraphic ❑ Service❑ 6.API Number Anchorage,AK 99519-6612 50-029-20212-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028327 PBU 09-04A 9 Logs(List logs and submit electronic and pnnted data per 20AAC25 071) '10 Field/Pool(s) PRUDHOE BAY,PRUD E LS El V E D 11.Present Well Condition Summary Irl (2 Total Depth measured 10106 feet Plugs measured None feet J A N 3 V 2015 true vertical 9206 78 feet Junk measured 10060 feet Effective Depth measured 9515 feet Packer measured See Attachment feet A'"'�l^�) GCC true vertical 8647 59 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 76 4 20"94#H-40 34 3-110 7 34 3-110.7 1530 520 Surface 2674 31 13-3/8"72#MN-80 33 8-2708 11 33 8-2707.89 5380 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment 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 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) p��ppucc Treatment descriptions including volumes used and final pressure jC/+lA�6D I -,r y ;� 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation 304 377 10330 1739 245 Subsequent to operation: 0 0 0 0 0 14 Attachments 15 Well Class after work. Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work Oil ❑ 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 0 Exempt N/A Contact Garry Catron Email Garry.Catron( BP.Com Printed Name Garry Catron Title PDC PE Signature (µ , — Phone 564-4424 Date 1/30/2015 v( r 7-1, 2/16 / 15- RBDMS\' JAN 3 0 2015 Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028327 SW Name Type MD TVD Depscription 09-04A PACKER 8481.66 7716.34 7" TIW Liner Top PKR 09-04A PACKER 9317.34 8460.23 4-1/2" Baker SABL-3 Packer Q O o 0 0 0 0 0 0 0 0 0 0 0 fd N N N (U OO (O M OO N- O = N CO O O N- O (`-- O O CO LC) O N U 1-4. 00000000000000 t- M CD CO N- U) C— U) LO OO M V' CO V m r- OO C7O CO OO CO OO OO U7 aO N- C O N- N OO = N N O r- LO M M O N- Lf) U) O O) a0 L!) 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K \ X 1 \ 0 z / / \ a) ^ \ O. 0 3 / k \ { b / / \ � \ / � ( � o t m A _ - � * < \ \ L ) - 0) / �® ) Nti 2 Rq ƒ 7 < Lij ? / \ k2 » / % \ k £ - 0 3 O 0 5 a " _ _ \ .2 U • t » / k k ; 2 / k f \ \ @ % / \ / I- I— t O D D / < 0 E b J G 2 7 e 5 \ »o o Q — m U ; 5 E ' '- ° E '--p k 5 " 1,I- 1— L LLI_ 3 = \ _ * « % & o £ < o 0 2 co e O H .- 0c2 E c 2 wo ¥ O >, E $LL a_ 2 2-, / / c / k - \ c » � ± _ : c m - ± c 2 ± z m 0 ¥ 5 e L E / _ ƒ $ } \ 5 f f / < O ± < O © O o I W — ° cu ,- (1) 3 - iii / E R 0 / / 2 ® 3 'E E 2 / g � f2 - Qa) : ---- 0 (c22» q ° _ R ® & _ m / o / / 2 / w / 0 \ / 0_ } © \ ± / o " E % < 7W - / 02 ? ka._ \ ° 2 / $ / a2 mow a - - O 2 < A a r 0 �� o - _ = t o c / f � \ - ƒ < 5. -° > / / 3 \ - / ? 2 / / , - R O - ® u L O Q - t o > c o t o \ $ 6 5 - m o t m R 2 il m _im u_ t « ,- ± -, c t O I D e 4 6 E 2 # \ Ni- N N N / / .- ,- \ + a \ & N • .• I HEE= 6-3/8"CNV VVELLFEAD= FMC 09-04A SAFETY NOTES:CHROME TBG& ACTUATOR= OTIS OKB. = 54' BF.ELEV= NIA KOP= 350(7 4111 2153' —7'CANKX)BAL-0 SSSVN,13=5.93T Max Angle= 39'@ 550W 2333' —9-5/8"FOC Datum MD= 9733' 2456' H9-5/8"FOC [ turn ND= 8800 SS GAS LFT MAICREIS T TBG,26#,13CR NSCC,.0383 bpf,U=6276" — 2210ST MD ND [EV TYPE VLV LATCH FORT DATE 3257 3256 6 'OTIS DMY RM r 0 06/03/14 13-3/8'CSG,724,1.44-80, =12.34T — 2701' I-4 2 4036 4014 15 OTIS DMY RA ' 0 03/01/93 3 4534 4494 21 OTIS DIN RA 0 06/11/93 T TBG,29#,13CR NSCC,.0371 bpf,ID=6.184" 3208' 4 5114 5003 35 ORS DMY RA ' 0 03/01/93 r x5-1/7 XO,ID=4.892" H 3210' 5 5731 5491 38 OTIS DRAY RM ' 0 06/03/14 6 6389 6010 38 OTIS DMY RA ' 0 0 /01/93 7 7009 6506 35 OTIS DMY RA ' 0 03/0193 Minimum ID = 3.726" @ 9446' 8 7630 7013 35 OTIS DMY R41 r 0 06/03/14 4-1/2" OTIS XN NIPPLE 9 8170 7461 34 OTIS DMY RA ' 0 03/01/93 10 83;; 7646 35 OTIS 01W RM ' 0 06/03/14 5-1/2"TBG,17#.13CR NSCT,.0232 bpf,0=4,897H 8413' 8415' TOP OF TPN TEBACK SLV H 8465' 9-518"X 7'TNV LG-6 R(R 8474' 9-5/8'1&L0111-WNJOW (09-04A)863W-8680' (SECTION) 9-5/8"X T TNV DT16 HGR — 8479' 9-5/8"CSG,47#,MN-80, =8.681' — —8639 9293' —14-1/2"OTIS X NP,ID=3.813- dA 930W —17"X 4-1/2"BKR SABL-3 HYD FKR, =4.000' VPik. 9427' —14-1/2'PARKER SWSIAD, =3.813" 9445' —4-1/7 OTIS XN M.U=3.725' 9457' —4-1/2-WLEG, =3,958" [4-1/2'TBG,12.6#,13-CR,.0152 bpf, =3.958" — 9457' 4.4 RRFORATION SUMMINRY 9546' T MA. R1.03R JT(201 REF LOG: BHCS ON 02/25/93 ANGLE AT TOP PERF: 18' .0 9515' Note:Refer to Roducbon DB for historical perf data 4.4 10060 I-1-BOW SPFING SIZE SPF IATERVAL Opn/Sqz SHOT S(')7 CECEMRA LEER 3-3/8" 6 9515-9525 0 12106/11 3-3/8' 4 9528-9548 0 04/03/93 • (LOST 04/01/93) 3-3/8" 4 9538-9554 0 09/18/95 3-3/8' 4 9548-9554 0 04/03/93 3-3/8" 4 9604-9612 0 03/22/93 3-3/8" 4 9622-9630 0 03/22/93 3-3/8' 4 9814-9818 0 12/2394 3-3/8' 8 9814-9818 0 09/18/95 * 3-3/8' 4 9866-9880 0 09/18/95 Atiric 010, 3-3/8" 4 9912-9916 0 12/23/94 ParD 10066' 1.%411i4itlitillIko.' 7"UR,29#,13-CR,.0371 bpf, =6,184' H 10106' DATE REV BY COMMENTS DA lb FEV BY COWANTS PRUDHOE BAY lilT 05/76 ORIGINAL COMPLETION ()4/04/12 LEC/J14) GLV GO(04/84/12) WELL 09-04A 03/01/93 RIG SIDETRACK(09-04A) 04/04/12 I Fria.0 PULL PXN PLUG(04/03/12) PERAK No:'1930240 12/11/11 RVVIISPJC FERFS(12/06/11) 04/19/12 PJC TUBING CORRECTIONS API No: 50-029-20212-01 01/12/12 LEGPJC GLV GO 06/05/14 MJC/JA ) GLV GO(06/03/14) SEC 2,T10N,R15E,405'FSL&746'FE_ 02/21/12 SWGJAAJ SET 4-1/7 PXN PLUG(02/20/12) 02/21/12 SCG/JPA)GLV LATCH CORRECTIONS H BP Exploration(Alaska) • ?r3i/L. C fi - CAA Prb Regg, James B (DOA) q30 From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] 3 Sent: Tuesday, March 12, 2013 9:18 AM -' f1 I 31'3 To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr Cc: AKD &CDHDWeIIIntegri @bp.com; Ryan.Holt @bp.com; Arend, Jon Subject: UNDER EVALUATION: Producer 09 -04A (PTD #1930240) Sustained OA Casing Pressure Above MOASP Attachments: Producer 09 -04A (PTD #1930240) Wellbore Schematic.pdf; Producer 09 -04A (PTD # 1930240) TIO Plot.docx All, Producer 09 -04A (PTD #1930240) was found with sustained outer annulus pressure above MOASP. The wellhead pressures were found to be at tubing /IA /OA 203/ 1724/1320 psi on 03/10/2013. The well is reclassified as Under Evaluation and is placed on a 28 -day clock, and may remain on production to facilitate evaluation. Plan forward: 1. DHD: Warm OART 2. Wellhead: PPPOT -IC 3. WIE: Evaluate potential Seal -Tite retreatment based on OART and PPPOT -IC results A copy of the TIO plot and wellbore schematic are attached for your review. Please call with any questions. Thank you, s A- Sel SCANNED J '22203 Jack Disbrow 1325r,. BP Alaska - Well Integrity Coordinator MN, a 5-3 60 GW Iokai Wens Organization ` tu:�`f' a4.52 Office: 907.659.5738 "' ofr- WIC Email: AKDCWelllntegrityCoordinator@ bp.com per` CO 4�7— i PBU 09 -04A PTD #1930240 3 -12 -2013 TIO Pressures Plot We l: 09-04 3,000 - - E— IA --&— OA 2.000 - OOA + 000A — 1.000 - On 1211 122222112 12129112 01/05/13 01/12/13 01;19/13 01/26/13 02/02/13 02109/13 02/1613 02,23/13 03/02113 03/09/13 i ,. TREE = 6-3/8 CM/ III _D %AEU: hEAD = FMC- 09 -04A SAFETY NOTES: CHROME TBG & LKIR*** ACTUATOR = OTIS BF. NA KOP = 3500' 4110 I 2153' - 7" CAMCO BAL-0 SSSVN, ID = 5.937" 1 2333' 9-51 1 Datum MD = 9733' 1 Datum TVD = 88G3 SS 2456. 91 5/8111M LIFT MANDRELS IT TBG, 26N, 13CR NSCC, 0383 bpf, ID = 6.276' - 2210' . ST MD - ND DEV TYPE VLV LATCH FORT DATE 1 13-3/8" CSG,72#, MN-80, ft D»' 12.347" I- 2701' 1 ■ 1 3257 ' 3256 6 OTIS DOME RM "16 04/03/12 2 4036 4014 15 OTIS MAY RA r 0 03/01/93 it&-f- 53bors■ 3 4534 4494 21 OTIS DMY A r 0 06/11/93 Ir TBG, 29#, 13CR NSCC, .0371 bpf , ID = 6.184" H 3208' 4 5114 5003 35 OTIS DVY RA r 0 03/01/93 17" X 5-1/2" X0, ID -= 4.892" 1-12" ----------. 1 0' 5 5731 5491 38 OTIS DOME RM r 16 04/03112 L 6 6389 6010 38 OTIS DMY RA ' 0 03/01/93 7 7009 6506 35 OTIS DMY RA ' 0 03/01/93 Minimum ID = 3.726" @ 9446' 8 7630 7013 35 OTIS DOME RM '16 04/036 4-112" OTIS XN NIPPLE 9 8170 7461 34 OTIS we RA ' 0 03/01/93 10 8396 7646 35 OTIS SO RM '32 04/03/12, 1 5-1 /2" TBG,17H, 13CR NSCT, .0232 bpf, ID -= 4,892' - 8413' - ___ \ i 8415' . - 15-1/2" X 4-1/2" XO, ID = 4.;.1.2" TOP OF TIW TIB3ACK SLV - 1 8465' 9-5/8" X 7" TAN LG-6 PKR H 8474' ',......... CI i 9-5/8" MILLOUT WINDOW (09-04A) 8639' - 8680' (SECTION) 9-5/8" X 7" TM/ DTI-IS HGR - 8479' 1 9-5/8" CSG, 47#, MN-80, ID = 8,681" - - 8639 1--- 9293' 4-1/7' OTIS X NIP, ID = 3.813" 9309' H7"' X 4-1/7' BKR SABL-3 HYD PKR, 0= 4.00G ... ya „IA I 9427' H4-1/2" PARKER SWS NIP, ID = 3.813" V/Ir 1 9445' H4-1/2' OTIS XN NIP, ID = 3.725" 9457 ,2 1 4-1/7' TBG,12.6#, 13-CR, 0152 bpf, ID = 3.958" H 9457. • H4-1/" WLEG, ID = 3.958" PERFORATION SUMMARY • REF LOG: 91-CS ON 02/25/93 9546' 1H7" MARKER JT (20') ANGLE AT TOP PERF: 18° s ..i 9515' Note: Refer to Production DB for historical perf data SIZE SF INTERVAL Opn/Sqz DATE ‘ 10060' - FISH•BOW SPRING 3-3/8" 6 9515 - 9525 0 12/06/11 CECENTRA LIZ ER 3-3/8" 4 9528 - 9548 0 04/03/93 ‘ (LOST 04/01/93) 3-3/8" 4 9538 - 9554 0 09/18/95 3-3/8" 4 9548 - 9554 0 04/03/93 3-3/8" 4 9604 • 9612 0 03/22/93 3-3/8" 4 9622 - 9630 0 03/22/93 3-38" 4 9814 - 9818 0 12123/94 3-3/8" 8 9814 - 9818 0 09/18/95 3-3/8" 4 9866 - 9880 0 09/18/95 l esk it ok, 3-3/8" 4 9912 - 9916 0 12/23/94 .44 I FBTD H 10066' %,11,, Q114.0 •to. I T. LNR, 29#, 13-CR, .0371 bpf, ID = 6.184" H 10106' I DATE REV BY COMMENTS II DATE REV BY COMMENTS PRUDHOE BAY UNIT ° 05176 ' ORIGINAL COMPLETION 04104/12 LEC/JMD GLV C/O (04/04/12) WELL: 09-04A 03/01/93 RIG SIDETRACK (09-04A) 04/04/12 LEC/JMD PULL PXN PLUG (04/03(12) PERMIT Kb: '1930240 12/11/11 RWMIPJC PERFS (12/06/11) 04/19/12 PJC TUBING CX)RRECTONS AP1No 50-029-20212-01 01/12112 LEC/PJC GLV CJO SEC 2, T10N, R15E405' NSL & 747' WB_ 02/21/12 SWUM() SET 4-1/7' PAN PLUG (02/20/12) 02/21/12 SCG/JMD GLV LATCH CORRECTIONS 1 BP Exploration (Alaska) TREE = 6-3/8" OVV • __Ai ,WELtl-EAD = FMC 09-04A SAFETY NOTES: CHROME TBG & LNR''"•• ACTUATOR = OM KB. ELEV = 54' BF EIEV= NYA KOP = 3500' 1 2153' 1-r CAMCO BAL-O SSSVN, 0 = 5.937" Max Angle = 39°@ 5509' . 2333' 9-5/8 FOC DatUttl IVID = 9733' f ..c V 0 03/01/93 • atlrn 8800' SS ND = ' . ' = " I— 2210' , 1111=31111 2 4036 4014 9-51/5 OTIS 8" 0 FOC D Dmy RA ST MD WD DEV M LATCH PORT DATE T' TBG, 26#, 13CR NSCC, .0383 bpf, ID 6.276 ■ 1 3257 3256 6 OTIS DOME RM '16 04/03/12 1 13-3/8" CSG,72#, AN- :: , ID = 12.347' 1--I 2701' AXSAIN 5350 r s ; 3 4534 4494 21 OTIS (Ti' RA ' 0 06/11/93 17' TBG, 29#, 13CR NSCC, .0371 bpf ,IG-= 6.184" H 3208' 4 5114 5003 35 OTIS DMY RA ' 0 03/01/93 17' X 5-1/2" X0, ID = 4.892" 1---12-11:7-7------------ 5 5731 5491 38 OTIS DOVE RM " 16 04/03/12 L 6 6389 6010 38 011S DVY RA ' 0 03/01/93 Minimum ID = 3.726" @ 9446' 7 7009 6506 35 OTIS CMY RA ' 0 03/01/93 8 7630 7013 35 OTIS DOME RM " 16 04/036 4-1/2" OTIS XN NIPPLE 9 8170 7461 34 OTIS [MY RA IF 0 03/01/93 10 8396 7646 35 OTIS SO RM " 32 04/03/12 1 5-112" TBG,17#, 13CR NSCT, .0232 bpf, ID = 4.892' H 8413. ----- 8415' H5-1/2' X 4-1/2" XO, ID = 4.897' 1TOP OF TW TIEBACK SLV H 8465' H 9-5/8" X 7" TW LG-6 PKR --- 8474' I i2 9-5/8" X 7" TW DTHS HGR — I 8479' 1------ I 9-5/8" MILLOUT WINDOW (09-04A) 8639' - asacr (SECTION) I 1 9-5/8" CSG, 47#, MN-80, 10 = 8.681" -1 - 8639 1 ---- I 9293' 1--14-1/2" OTIS X NIP, ID = 3.813' I 9309' —jr . X 4-112" BKR SABL-3 HYD PKR, 10 . 4.000" Vat ...A. VP I 9427' —14-1/2" PARKER SWS NIP, ID -= 3.813" I 9445' --I4-12' OTIS XN NIP, ID= 3.725" I , 1 4-12' TBG,12 6#, 13 .0152 bpi, ID = 3 958" 9457' H4-1/2" WLEG 0 = 3.958" I 848 PERFORATION SUIVAAARY REF LOG: BI-CS ON 02/25/93 9546 3 MARKER JT (20') . ANGLE AT TOP PERF: 18° 1.‘ 9515' Note: Refer to Production DB for historical perf data SIZE SPF : INTERVAL ' Opn/Sqz DATE ‘ 10060' — F1SH-BOVV SPRING 3-3/8" 6 9515 - 9525 0 12/06/11 06CENTRALIZER 3-3/8" 4 9528- 9548 0 04/03/93 • (LOST 04/01/93) 3-3/8" 4 9538. 9554 0 09/18/95 3-318" 4 9548 - 9554 0 04/03/93 \ 3-3(8" 4 9604 - 9612 0 0322/93 3-3/8" 4 9622 - 9630 0 0322/93 3-3/8" 4 9814 - 9818 0 12/23/94 3-3/6" 8 9814 - 9818 0 09/18/95 . . 3-3/8" 4 9866 - 9880 0 09/18/95 3-3/8" 4 9912 - 9916 0 12/23/94 I FBTD H 10066' gilit4400141 441114% . .. tivt 7" LNR, 29#, 13-CR .0371 bpf, ID = 6.184" — I 10106' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT osas ORIGINAL COMPLETION '' LECOMID GLV C/0 (04)04/12) WELL: 09-04A 03101/93 RIG SIDETRACK (09-04A) 04/04/12 LEC/JMO PULL PXN PLUG (04/03/12) PERMIT No 9930240 12/11/11 RWNVPJC PERFS (12/06/11) 04/19/12 PJC TUBING CORRECTK)NS AR No: 50-029-20212-01 01/12/12 LEC/PJC GLV C/0 SEC 2, T1ON, R15E405' NSL & 747' VVEL _ . 02)21/12 SVVC/JMD SET 4-1/2" PXN PLUG (02/20/12) 02/21/12 SCG/JMO GLV LATCH CORRECTIONS _ - BP Exploration (Alaska) , ' RECEIVED STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMM ION DEC 3 12012 ` REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well IA Plug Perforations U Perforate U Other wet one .1 Sea )17 !1t' Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension yLt✓ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 1) 3) 13 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development le Exploratory ❑ „ 193 -024 -0 3. Address: P.O. Box 196612 Stratigraphit❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 i. 50- 029 - 20212 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028327 - - PBU 09 -04A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): s To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10106 feet Plugs measured None feet true vertical 9206 feet Junk measured 10060 feet Effective Depth measured 10066 feet Packer measured See Attachment feet true vertical 9168.85 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 76 20" 94# H -40 28 - 104 28 - 104 1530 520 Surface 2674 13 -3/8" 72# MN -80 27 - 2701 27 - 2700.78 5380 2670 Intermediate None None None None None None Production 8613 9 -5/8" 47# MN -80 26 - 8639 26 - 7844.52 6870 4760 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 FEB 2 8 2013. Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 285 1643 12851 1739 225 Subsequent to operation: 298 336 12092 1751 227 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development EI " Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . 0 Gas ❑ WDSPIJJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC-❑ 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 Garry Catron Email Garry.CatrOtl(C�BP.COm Printed Name Garry Catron Title PDC PE Signature 3' dAAAT C Phone 564 -4424 Date 12/27/2012 ABDMS JAN 0 1 2013. �° 31/ 1 / ; n ' � Form 10-404 Revised 10/2012 " / i Submit Original Only • • Packers and SSV's Attachment ADL0028327 SW Name Type MD TVD Depscription 09 -04A PACKER 8474 7656.08 7" TIW Liner Top PKR 09 -04A PACKER 9309 8398.34 4 -1/2" Baker SABL -3 Packer • • Packer Count = 2 SSSV Count = 0 Casing / Tubing Attachment ADL0028327 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20" 94# H-40 28 - 104 28 - 104 1530 520 LINER 728 7" 29# L -80 8465 - 9193 7702.71 - 8342.97 8160 7020 LINER 913 7" 29# 13CR80 9193 - 10106 8342.97 - 9206.78 8160 7020 PRODUCTION 8613 9 -5/8" 47# MN -80 26 - 8639 26 - 7844.52 6870 4760 SURFACE 2674 13 -3/8" 72# MN -80 27 - 2701 27 - 2700.78 5380 2670 TUBING 2185 7" 26# 13Cr80 25 - 2210 25 - 2209.87 7240 5410 TUBING 1000 7" 29# 13CR80 2210 - 3210 2209.87 - 3208.63 8160 7020 • • Perforation Attachment ADL0028327 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 09 -04A 12/6/2011 APF 9515 9525 8647.59 8657.07 09 -04A 9/18/1995 APF 9528 9538 8659.92 8669.4 09 -04A 9/18/1995 RPF 9538 9548 8669.4 8678.89 09 -04A 9/18/1995 RPF 9548 9554 8678.89 8684.58 09 -04A 3/22/1993 PER 9604 9612 8731.94 8739.51 09 -04A 3/22/1993 PER 9622 9630 8748.97 8756.54 09 -04A 3/22/1993 PER 9630 9650 8756.54 8775.44 • 09 -04A 9/18/1995 RPF 9814 9818 8930.42 8934.2 09 -04A 9/18/1995 RPF 9866 9868 8979.58 8981.47 09 -04A 9/18/1995 RPF 9868 9880 8981.47 8992.81 09 -04A 9/18/1995 PER 9880 9888 8992.81 9000.38 09 -04A 12/23/1994 APF 9912 9916 9023.06 9026.85 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • • Daily Report of Well Operations ADL0028327 ACTIVITYDATE SUMMARY °' T /I /0= SSV /0/0, Temp =SI. Assist Sealtite, well head leak. Sealtite reported 2 LDS assemblys on casing head with small Teaks during casing hanger treat. Verified hanger test void was bled to 0 psi. Adjusted all gland nuts on 12/1/2012 casing head. Sealtite continued treatment with LDS leaks mitigated. T /I /0 = SSVT65 /250. Temp = SI. Assist Seal -Tite, 10 PO Sealant (IAxOA comm). AL SI @ lateral valve. IA FL © 8396'. OA FL @ 300'. Bled IAP to OT tank from 65 psi to 0 psi and OAP from 250 psi to 0 psi in 2.5 hrs. Held open bleed on both during Seal -Tite operations. Established IC PO LLR of: 50 mL /min @ 1000 psi, 75 mL /min @ 2000 psi, 150 mL /min @ 3500 psi. Pumped 1 liter Tur -Flow pressuring IC to 1000 psi. IC LDS @ 3 & 4 o'clock showed comm with slight bubbling. Cameron tightened all IC LDS. Established initial seal on IC PO © 1000 psi and held pressure for 30 min, increased IC pressure in 500 psi increments to 3500 psi, held 30 min each step. 3500 psi left on IC to cure overnight. Heater left in WH. Job complete. Final WHPs = SSV /0/0. 12/1/2012 SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 18:00 hrs. T /I /0 = SSV /5/30. Temp = Si. Assist Seal -Tite monitor IC (IAxOA comm). AL SI @ lateral valve. IC © 3500 psi, no pressure loss overnight. Bled IC to 2500 psi. Turned well over to OPS to POP. Heater removed from WH. 12/2/2012 SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 09:00 hrs. T71 /0 = 250/1/50/100. Temp = 132 °. Monitor IC pressure (Post Seal - Tite). AL online, ALP = 1750 psi. IC pressure @ 4000 psi, bled back to 2050 psi @ 08:30 hrs. Installed gauge on IC. Stopped back @ 16:30 hrs WHPs and IC pressure unchanged. 12/3/2012 SV = C. WV, SSV, MV = 0. IA, OA = OTG. NOVP. 16:30 hrs. T /l/0 = 250/1750/260. Temp = 132 *. Monitor IC pressure (Post Seal - Tite). AL online, ALP = 1750 psi. IC pressure @ 2140 psi. IC hanger increased 90 psi, OAP increased 160 psi. 12/5/2012 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 0800 T /I/0 = 270/1750/300. - Temp = 132 *. WHPs & IC void pressure (Post Seal - Tite). AL online, ALP = 1750 psi. IC pressure © 2140 psi. IC hanger unchanged, TP increased 20 psi, OAP increased 40 psi. 12/6/2012 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 0930 T /I /0 = 250/1710/380. Temp = 132 *. WHPs & IC void pressure (Post Seal - Tite). AL online, ALP = 1710 psi. IC pressure @ 1910 psi. IC hanger decreased 230 psi, TP decreased 20 psi, IAP &ALP decreased 40 psi, OAP increased 80 psi. 12/7/2012 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 0800 T /I /0 = 250/1710/500. Temp = 132 *. WHPs & IC void pressure (Bleed OA to -100 psi, retreat !CPO with Tur - Flow). AL online, ALP = 1710 psi. Bled OAP to bleed trailer (gas) 3 hrs = 120 psi. Pumped 200m1 Tur -Flow into IC hanger, IC hanger 2300 psi. Final WHPs 250/1710/100. 12/9/2012 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 1500 T /I/0= 220/1740/180. Temp= 148 °. WHPs & IC void pressure (Post Seal - Tite). AL online. IC hanger= 2220 psi. TP decreased 30 psi., IAP increased 30 psi. OAP increased 60 overnight. Note: Heater installed in wellhouse. Tree cap bled to 0 psi. 12/10/2012 S= C. WV, SSV, MV= 0. IA & OA OTG. NOVP. 1320 hrs. • • Daily Report of Well Operations ADL0028327 T /I /0= 250/1760/250. Temp = 146 *. WHP's & IC void pressure. (Post Sealtite). TP increased 30 psi, IAP increased 20 psi & OAP increased 70 psi overnight. IA void pressure = 2020 psi. 12/11/2012 SV = C. WV, MV &SSV = O. IA & OA = OTG. NOVP. 1145. T /I /O = 260/1750/300. Temp = 142 °. WHP's & IC void pressure. (Post Seal - Tite). ALP = 1750 psi, AL open @ casing valve. IC void = 1860 psi. TP increased 10 psi, IAP decreased 10 psi, OAP increased 50 psi, and IC void decreased 160 psi overnight. 12/12/2012 SV = C. WV, SSV, MV = 0. IA, OA = OTG. NOVP. 1030 hrs. T /I10 = 260/1750/3/0. Temp = 134 *. WHP's & IC void pressure (post Seal Tite). ALP = 1750 psi. AL open @ casing valve. IC void @ 1750 psi. IC void decreased 110 psi, TP & IAP unchanged & OAP increased 70 psi overnight. 12/13/2012 SV = C. WV, SSV & MV = 0. IA & OA = OTG. 1530. T /I /O = 260/1750/420. Temp = 134 °. WHPs & IC void pressure (Post Seal - Tite). No IA companion valve. AL online, ALP = 1750 psi. IC void increased 50 psi & OAP increased 50 psi overnight. 12/14/2012 SV = C. WV, SSV, MV = 0. IA, OA = OTG. IC void = OTG. NOVP. 08:10. TREE= 6-3/8" Cw • • . WELLHEAD = FMC 09-04A SAFETY NOTES: CHROMETBG & LNR' ACTUA = -- OTIS KB. ELEV = 54' KOP = 3500' I I 2153' 1-17" CAMCO BAL -O SSSVN, ID = 5.937° I _ Max A* @ = 39° :5509' 2333' 9 -5/8'" FOC Datum MD = 9733 /" Datum TVD = 8800' SS — 2456' 95/8 FOC GAS LIFE MANDRELS 17' TBG, 26#, 13CR NSCC, .0383 bpf, ID = 6.276" H 2210' ST MD TV D DEV TYPE VLV LATCH PORT DATE 113 -3/8" CSG,72#, MN-80, ID= 12.347" H 2701' 1 3257 3256 6 OTIS DOW RM " 16 04/03/12 2 4036 4014 15 OTIS DMY RA r 0 03/01/93 1r TBG, 29#, 13CR NSCC, ,0371 bpf, ID = 6.184" H 3208' 3 4534 4494 21 OTIS DMY RA r 0 06/11/93 4 5114 5003 35 OTIS DAY RA r 0 03/01/93 17" X 5-1/2" X0, ID = 4.892" 3210' 5 5731 5491 38 OTIS DOME RM r 16 04/03/12 L 6 6389 6010 38 OTIS DMY RA IF 0 03/01/93 7 7009 6506 35 OTIS DAY RA ' 0 03/01/93 Minimum ID = 3.726" @ 9446' 8 7630 7013 35 OTIS DOME RM r 16 04/036 4 -1/2" OTIS XN NIPPLE 9 8170 7461 34 OTIS DMY RA ' 0 03/01/93 10 8396 7646 35 OTIS SO RM r 32 04/03/12 1 5-1/2" TBG,17 #,13CR NSCT, .0232 bpf, ID = 4.892' H 8413' 1-------t . 1 8415' H5-1/2" X 4-1/2" X0, ID = 4.892" I TOP OF TAN TIEBACK SLV H 8465' 19 -5/8" X 7" TiW LG-6 PKR H 8474' 0 I9 5/8" X 7" TAN DTHS HGR H 8479' 9-5/8" MBLLOUT WINDOW (09-04A) 8639' - 8680' (SECTION) I 1 9 -5/8" CSG, 47 #, I04-80, ID = 8.681" H — 8639 I' 9293' 4-12" OTIS X NIP, ID = 3.813" I H I 9309' HT" X 4-1/7' BKR SABL -3 HYD PKR, [) = 4.000"1 s'i 9427' I-14.1 R PARKER SWS NIP, ID = 3.813" I 9445' 4-1/2' OTIS XN NIP, ID = 3.725" 1 4-1 /7' TBG,12.6#,13 -CR, .0152 bpf, D = 3.958" H 9457' 9457` —1 WLEG, ID = 3,958" I PERFORATION SUMMARY ` REF LOG: BHCS ON 0225/93 9546' HT" MARKER JT (20') I ANGLE AT TOP PERF: 18° @ 9515' ` Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE '% I 10060' I — FISH -BOW SPRING 3-3/8" 6 9515 - 9525 0 12/06/11 DECENMALIZER 3-3/8" 4 9528 - 9548 0 04/03/93 ` (LOST 04 /01/93) 3-3/8" 4 9538 - 9554 0 09/18/95 3-3/8" 4 9548 - 9554 0 04/03/93 ` 3-3/8" 4 9604 - 9612 0 03/22/93 3-3/8" 4 9622 - 9630 0 03/22/93 3-3/8" 4 9814 - 9818 0 12123/94 3-3/8" 8 9814 - 9818 0 09/18/95 3-3/8" 4 9866 - 9880 0 09/18/95 ■ 3-3/8" 4 9912 - 9916 0 1223/94 iQ PBTD 10066' �, % ;; � ., .• I T' LNR, 29#, 13 -CR .0371 bpf, ID = 6.184" IH 10106' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05176 ORIGINAL COMPLETION x 04/04/12 LEC/JMD GLV C/0 (04/04/12) WELL: 09-04A 03/01/93 RIG SIDETRACK (09 -04A) 04/04/12 LEC/JMD PULL PXN PLUG (04/03/12) PERMIT No: 1930240 12/11 /11 RWNVPJC PERFS (12/06111) 04/19/12 PJC TUBING CORRECTIONS API No: 50- 029 - 20212 -01 01/12/12 LEC/PJC GLV C/0 SEC 2, T10N, R15E405' NSL & 747' WEL 02/21/12 SWC/JMD SET 4 -112" PXN PLUG (02/20/12) 02/21/12 SOUND GLV LATCH CORRECTIONS 1 BP Exploration (Alaska) RECEIVED RECEIVED APR 1 3 2012 c ALASKA OIL AND G S OF ERVAT ON COMMISSION 1 3 `' • AOGCC REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well LJ Plug Perforations LJ Perforate LJ Other U Seal -Tite 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 © Exploratory ❑ 193 -0240 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number_ Anchorage, Alaska 99519 -6612 50- 029 - 20212 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADLO- 028327 PBU 09 -04A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10106 feet Plugs measured None feet true vertical 9207 feet Junk measured 10060 feet Effective Depth measured 10066 feet Packer measured SEE BELOW feet true vertical 9169 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 94# H -40 28' -104' 28' -104' 1530 520 Surface 2674' 13 -3/8" 72# MN -80 27' -2701' 27' -2701' 5380 2670 Intermediate Production 8613' 9 -5/8" 47# MN -80 26' -7845' 26' -7845' 6870 4760 Liner 1641' 7" 29# 13Cr80 8465'- 10106' 7703' -9207' 8160 7020 Perforation depth Measured depth SEE ATTACHED feet True Vertical depth feet 7" 26# 13Cr80 25'-2210' 25'-2210' 7" 293 #t 13Cr80 2210' -3210' 2210' -3209' 5 -1/2" 17# 13Cr80. .... - 32.10" =8415' 3209' -7662' Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 8415' -9457' 7662' -8593' 7" Camco BAL -0 SSSVN 2513' 2513' Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker SABL 3 PER ER 9309' 8452' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 3 :I 'U' 2. 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: 343 1897 13476 227 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development © , Service ❑ Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work: Oil - © 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: Contact Nita Summerhays Printed Name .1 it it- S m- ays Title Data Manager //7 Phone 564 -4035 Date 4/12/12 4 A PR 16 2012 RBDMS �_ ` 49 - Form 10-404 Revised 11/2011 Submit Original Only - z 0/ 09 -04A 193 -024 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 09 -04A 3/22/93 PER 9,604. 9,612. 8,731.94 8,739.51 09 -04A 3/22/93 PER 9,622. 9,630. 8,748.97 8,756.54 09 -04A 3/22/93 PER 9,630. 9,650. 8,756.54 8,775.44 09 -04A 3/22/93 PER 9,866. 9,868. 8,979.58 8,981.47 09 -04A 3/22/93 PER 9,868. 9,888. 8,981.47 9,000.38 09 -04A 4/3/93 APF 9,528. 9,548. 8,659.92 8,678.89 09 -04A 4/3/93 PER 9,548. 9,554. 8,678.89 8,684.58 09 -04A 12/23/94 APF 9,912. 9,916. 9,023.06 9,026.85 09 -04A 12/23/94 APF 9,814. 9,818. 8,930.42 8,934.2 09 -04A 9/18/95 RPF 9,538. 9,554. 8,669.4 8,684.58 • 09 -04A 9/18/95 RPF 9,814. 9,818. 8,930.42 8,934.2 09 -04A 9/18/95 RPF 9,866. 9,880. 8,979.58 8,992.81 09 -04A 12/6/11 APF 9,515. 9,525. 8,647.59 8,657.07 09 -04A 1/12/12 BPS 9,429. 9,916. 8,565.97 9,026.85 09 -04A 1/13/12 BPP 9,429. 9,916. 8,565.97 9,026.85 09 -04A 2/20/12 BPS 9,445. 9,916. 8,581.16 9,026.85 09 -04A 4/2/12 BPP 9,445. 9,916. 8,581.16 9,026.85 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 l i • • 09 -04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/22/2012!T/1/6= SSV 70/0, Temp =Sl. Flush plastic from IC test void. 'Hoke valves installed on IC test ports. DHD holding open bleed on IA & OA. RU to ;test port (0 psi). Removed LDS, one at a time, and flushed Ferminite plastic from 'test void. Removed aprox 1/2 gal of plastic. Replaced 2 damaged LDS assemblys.1 ;Test void is ready for Seal Tite treatment. 3/22/2012T/I/0= SSV /0 +/10. Temp= SI. Assist Seal -Tite & Cameron (IAxOA comm). AL ;spool removed. Integral installed on IA. Bled OA to 0 psi in 1 min. Held open bleed on IA & OA. Seal -Tite & Cameron removed each LDS in IC spool & flushed Furmanite packing from void with air & hydraulic fluid. Re- tapped & replaced LDS i& gland nut @ 11 o'clock position. Retaped and replaced pin @ 2 o'clock position. ' Retapped LDS port @ 3 o'clock position. Re- torqued LDS & gland nuts to spec. Final WHPs = SSV /0 +/0 +. 3 SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 20:30. 3/25/2012 T /I /0= SSV /1/1. Temp= SI. Assist Seal -Tite (IAxOA). AL spool removed. Integral ±installed on IA. Pumped 1 liter GIy -Flow into IC void stepping u• pressure to 3500 Passed 30 _min pressure test @ 3500 psi. Void left © 2000 psi. Job complete. Final WHPs- SSV /1/1. 3/26/2012'T/I/O = SSV /0 +/2. Temp = SI. OART (Post Seal - tite). AL spool removed, integral installed on AL line & IA. Heater in WH upon arrival & working properly. OA FL @ surface. Increased IAP using AL gas from 0 psi to 1100 psi, OAP unchanged. Monitor for 1 hr. IAP unchanged, OAP increased 1 psi. (Crystal gauge) installed on OA, tags hung on IA, OA valves. Job complete. Final WHPs = SSV /1100/3. SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 1200 FLUIDS PUMPED LITERS 1 Seal -Tite 1 TOTAL TREE = 6-3/8" CM! • VVELLHEAD = FMC 09-04A SAFE CHROME TBG & LNR 7" TBG CROSSES OVER FROM 26# TO 2911 112 2210' - ACTUATOR = ,. OTIS KB. BF. ELEV = N/A ............„ .„„ _.. „. _ KOP = 3500' Maix 39 6 5509 Datum MD = 9733' 41=10 I 2153' H T' CAMCO BAL-O SSSVN, ID = 5.937" DatUMT/D = 8800' SS 19-5/8" FOC I—I 2333 .... I 19-5/8" FOC 1--1 2458' — — I YPE VLV LATCH PORT GAS LIFT WLNDRELS ST MD TVD DEV T DATE 13-3/8" CSG,72#, MIN-80, ID = 12.347" IH 2701' — 1 3257 3256 6 OTIS DOME RM r 16 04/04/12 2 4036 4014 15 OTIS DMY RA ' 0 03/01/93 3 4534 4494 21 OTIS DMY RA ' 0 06/11/93 IT' TBG, 2911, 13-CR .0371 bpf, ID= 6.18e I— 3208' \ / 4 5114 5003 35 OTIS DMY RA ' 0 03/01/93 IT' X 5-1/2" X0,10 = 4.897 H 3210' — 5 5731 5491 38 OTIS DOME RM ' 16 04/04/12 • L 6 6389 6010 38 OTIS DMY RA ' 0 03/01/93 7 7009 6506 35 0115 DMY RA " 0 03/01/93 Minimum ID = 3.726" ( 9446' 8 7630 7013 35 OTIS DOME RM ' 16 04/04/12 4-1/2" OTIS XN NIPPLE 9 8170 7461 34 OTIS DMY RA ' 0 03/01/93 10 8396 7646 35 OTIS SO RM ' 32 04/04/12 I 5-1/2" TBG,17#, 13-CR, .0232 bpf, ID = 4.897' IH 8413' ‘ ) I 8415' I-15.1/2" X 4-1 rr X0, ID = 4.892" I TOP OF TM! TIEBACK SLV H 8485 I------__ l 19-5/8' X 7" TM! LG-6 PFI 8474' I 1 . 9-5/8" CSG MLLOUT WNOOW 19-5/8" X 7" - nw DTHS HGR I 8479' 1 8639' - 8680' (SECTION MILL) I 9-5/8' CSG, 47#, Nri ID = 8.681" H —6639 ------ I 9293' I--14-1/2" OTIS X NIP, ID = 3.813' I ,A 9309' I X 4-1/2" BKR SABL-3 1-if D PKR, ID = 4000" VP 9427' I PARKER SVVS NIP, ID = 3.813" 1 V/ I 9445' —14-1/2' OTIS XN NIP, ID = 3725" 9457' VVLEG I 1 4-1 / 2 " TBG,12.6#, 13-CR, .0152 bpi, ID= 3.955" H 9457 I H4-1 ir , 0= 3.958" PERFORATION SUMMARY ‘ REF LOG: BI-ICS ON 02/25/93 9546' I -- 17" MARKER JT (20') I ANGLE AT TOP FERF: 18° a 9515' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE \ 10060' — FISH-BOW SPRING 3-3/8" 6 9515 - 9525 0 12/06/11 DECENTRALIZER 3-3/8" 4 9528- 9548 0 04/03/93 \ (LOST 04/01/93) 3-3/8" 4 9538 - 9554 0 09/18/95 3-3/8" 4 9548 - 9554 0 04103/93 \ 3-3/8" 4 9604- 9612 0 03/22/93 3-3/8" 4 9622 - 9630 0 03/22/93 3-3/8" 4 9814 - 9818 0 12/23/94 3-3/8" 8 9814 - 9818 0 09/18/95 . . 3-3/8" 4 9866 - 9880 0 09/18/95 niiq■ 3-3/8" 4 9912 - 9916 0 12/23/94 III I 10066' Ii ,11 110■ 14 14, 1 4.• ,vo .• 1 LNR, MS, 13-CR .0371 bpi, ID= 6.184" H 10106' I DATE REV BY CONVENTS , DATE REV BY COMMENTS PRUDHOE BAY UNIT P 05/76 ORIGINAL COMPLETION 04/04/12 LEC/JMD GLV CJO (04/04/12) Vikl.L: 09-04A 03/01/93 RIG SIDETRACK (09-04A) 104/04/12 LEMMA) PULL PXN PLUG (04/03/12) PERMIT No: '1930240 12/11/11 RIAMPJC PERFS (12/06/11) API No: 50-029-20212-01 01/12/12 LEG/RIC GLV C/O SEC 2, T1ON, R15E 405' NSL & 747' WEL 02/21/12 SVICIJNID SET 4-1/2" PXN PLUG (02/20/12) 02/21/12 SCG/JMD GLV LATCH CORRECTIONS 11 BP Exploration (Alaska) A + STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMMISSI 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 151 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ - 193 -0240 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: 1 Anchorage, AK 99519 -6612 f" 50- 029 - 20212 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: r ADLO- 028327 PBU 09 -04A 10. Field /Pool(s): j PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10106 feet Plugs (measured) None feet true vertical 9206.78 feet Junk (measured) 10060 feet Effective Depth measured 10066 feet Packer (measured) 8474 9309 2513 feet true vertical 9168.85 feet (true vertical) 7710 8452 2513 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 94# H -40 28 - 104 28 - 104 1530 520 Surface 2674' 13- 3/8 "72# MN -80 27 - 2701 27 - 2701 5380 2670 Production 8613' 9 -5/8" 47# MN -80 26 - 8639 26 - 7845 6870 4760 Liner 728' 7" 29# L -80 8465 - 9193 7703 - 8343 8160 7020 Liner 913' 7" 29# 13CR80 9193 - 10106 8343 - 9207 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ - _ -:- Tubing: (size, grade, measured and true vertical depth) 7" 26# 13CR80 25 - 2210 25 - 2210 7" 29# 13CR80 2210 - 3210 2210 - 3209 5 -1/2" 17# 13CR80 3210 - 8415 3209 - 7662 4 -1/2" 12.6# 13CR80 1- - 9457 7662 - 8593 Packers and SSSV (type, measured and true vertical depth) 7" TIW Liner Top PKR , 74 7710 4 -1/2" Baker SABL -3 Packet � AS309 8452 NI 7" Camco BAL -O SSSVN � 4:1 25113 a 2513 12. Stimulation or cement squeeze summary: q'1, -- 4 "'-w Intervals treated (measured): R$�� �., �\ t � 1 5, 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: 343 1,897 13,476 227 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development IS / Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - 0 Gas ❑ WDSPL ❑ GSTOR p WINJ ❑ WAGE' GINJ ❑ SUSP❑ SPLUG p 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 Joe Lastufka JAN hs 4 zulz- Printed Nam e Last fk Title Data Manager Signatu Phone 564 -4091 Date 12/28/2011 Form 10 -404 Revised 10 /201RBDMS DEC 2 9 2011 ! ' • Z.-- Submit Original Only s 09 -04A 193 -024 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 09 -04A 3/22/93 PER 9,604. 9,612. 8,731.94 8,739.51 09 -04A 3/22/93 PER 9,622. 9,630. 8,748.97 8,756.54 09 -04A 3/22/93 PER 9,630. 9,650. 8,756.54 8,775.44 09 -04A 3/22/93 PER 9,866. 9,868. 8,979.58 8,981.47 09 -04A 3/22/93 PER 9,868. 9,888. 8,981.47 9,000.38 09 -04A 4/3/93 PER 9,548. 9,554. 8,678.89 8,684.58 09 -04A 4/3/93 APF 9,528. 9,548. 8,659.92 8,678.89 09 -04A 12/23/94 APF 9,814. 9,818. 8,930.42 8,934.2 09 -04A 12/23/94 APF 9,912. 9,916. 9,023.06 9,026.85 09 -04A 9/18/95 RPF 9,866. 9,880. 8,979.58 8,992.81 09 -04A 9/18/95 RPF 9,538. 9,554. 8,669.4 8,684.58 09 -04A 9/18/95 RPF 9,814. 9,818. 8,930.42 8,934.2 • 09 -04A 12/6/11 APF 9,515. 9,525. 8,647.59 8,657.07 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 • • 09 -04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FAIW'ZiMe :401 .0.4440 12/5/2011 1 ** *WELL SHUT IN ON ARRIVAL*** WELL SHUT IN ON ARRIVAL 'T /1 /O = 150/1100/500 PSI 'ARRIVE AT LOCATION AND CONFIRM WINDS 20 MPH, SUPPORT EQUIPMENT 'WORKING AND PAD NEEDS ADDITIONAL SNOW REMOVAL. DRIVE BACK TO THE SHOP TO PICK UP THE EQUIPMENT AND EXPLOSIVES. ARRIVED TO DS 9 AND WAITED FOR SNOW REMOVAL TO REMOVE DRIFTED SNOW. SPOTTED EQUIPMENT AND BEGIN RIG UP. ** *JOB CONTINUED ON 06- DEC - 2011 * ** 12/6/2011 ***JOB IN PROGRESS FROM 5- DEC - 2011 * ** COMPLETED RIG UP AND PERFORMED PRESSURE TEST. DID HOT CHECK, ARMED GUN AND RIH. CORRELATED TO SLB PERFORATION RECORD LOG DATED 22- MAR -1993, CONFIRMED PERF INTERVAL = 9515' - 9525'. TO !TOP SHOT = 3.7'. CCL STOP DEPTH = 9509.3'. 3 -3/8" HSD POWERJET HMX, 6 'SPF, 60 DEG PHASE. PENETRATION = 36.5 ", ENTRANCE HOLE = 0.37 ". MAX EXPLOSIVE LOAD = 22.7 G GOOD CONFIRMATION AT SURFACE OF FIRING. POOH. RIG DOWN. FINAL T /I /O = 185/1100/450 PSI ** *JOB COMPLETE * ** (WELL SHUT IN UPON DEPARTURE) FLUIDS PUMPED BBLS 1 DIESEL 5 METH 6 TOTAL SEE = 6 -3/8" CM/ WELLHEAD = FMC ACTUATOR = OTIS 09-04A SA E FROM 6S# CHROM # E BG 2210' LNR. 7" TBG CROSSES - KB. ELEV = 54' BF. ELEV = N/A - KOP = 3500' Max Angle = 39 @ 5509' Datum MD = 9733' I 2153' I --1 " CAMCO BAL -O SSSVN, ID = 5.937" I Datum TV D = 8800' SS 1 9 -5/8 "" FOCI —I 2333 I-- — GAS LIFT MANDRELS 19 -5/8" FOCI -1 2456' I — _ — ST MD TVD DEV TYPE VLV LATCH PORT DATE 113 -3/8 "" CSG,72 #, MN-80, ID = 12.347" H 2701' I---4 , 1 3257 3255 6 OTIS DOME RA r 16 08/09/06 2 4036 4014 16 OTIS DMY RA 0 03/01/93 3 4534 4494 20 OTIS DMY RA r 0 03/01/93 I7 " TBG, 29 #, 13 -CR, .0371 bpf, ID = 6.184" H 3208' / 4 5114 5003 33 OTIS DMY RA r 0 03/01/93 17" X 5 -1/2" TBG XO, ID = 4.892" H 3210' -� 5 5731 5491 39 OTIS DOME RA r 16 08/09/06 L • 6 6389 6010 37 OTIS DMY RA 0 03/01/93 7 7009 6506 37 OTIS DMY RA r 0 03/01/93 Minimum ID = 3.725" @ 9445' 8 7630 7013 36 OTIS DOME RA r 16 08/09/06 4 -1/2" OTIS XN NIPPLE 9 8170 7461 35 OTIS DMY RA r 0 03/01/93 10 8396 7646 34 OTIS SO RA r 28 08/09/06 5-1/2" TBG,17 #, 13 -CR, .0232 bpf, ID = 4.892" I-I 8413' I 'TOP OF TM! TIEBACK SLV H 8465' I 8415' I — I5 - 1/2" X 4 -1/2" TBG XO, ID = 4.892 " I L J 19-5/8" X 7" TM/ LG -6 PKR I — { 8474' I 9 9-5/8" CSG MILLOUT WINDOW 8639' - 8680' (SECTION MILL) 19-5/8" X 7" TIW DTHS HGR H 8479' I 1 9 -5/8" CSG, 47 #, MN-80, ID = 8.681" H 8639' I I 9293' I - 14 - 1/2" OTIS X NIP, ID = 3.813" I ,./A. 9309 I—1 "" X 4 -1/2" BKR SABL -3 HYD PKR, ID = 4.000"1 V' 11‘ 1 9427' H4 -112" PARKER SWS NIP, ID = 3.813" I I 9445' I-- I4 - 1/2" OTIS XN NIP, ID = 3.725" I I 9457' H4 -1/2" WLEG I 14 -1/2" TBG,12.6 #, 13 -CR, .0152 bpf, ID = 3.958" I—I 9456' ` PERFORATION SUMMARY ` REF LOG: BHCS ON 02/25/93 ANGLE AT TOP PERF: 18° @ 9515' ` Note: Refer to Production DB for historical perf data 10060' — FISH -BOW SPRING SIZE SPF INTERVAL Opn /Sqz DATE i ` DECENTRALIZER 04/01/93) 3 -3/8" 6 9515 - 9525 0 12/06/11V 17" MARKER JT (20') I-I 9546' ` 3-3/8" 4 9528 - 9548 0 04/03/93 3 -3/8" 4 9538 - 9554 0 09/18/95 3-3/8" 4 9548 - 9554 0 04/03/93 3 -3/8" 4 9604 - 9612 0 03/22/93 3 -3/8" 4 9622 - 9630 0 03/22/93 3-3/8" 4 9814 - 9818 0 12/23/94 • 3 -3/8" 8 9814 - 9818 0 09/18/95 4 ., 3-3/8" 4 9866 - 9880 0 09/18/95 4�\ 4 -11, 3 -3/8" 4 9912 - 9916 0 12/23/94 I PBTD 1-I 10066' .."'�,�;�% \► 17" LNR, 29 #, 13 -CR, .0371 bpf, ID = 6.184" I — I 10106' I DATE REV BY COMMENTS ' DATE REV BY COMMENTS PRUDHOE BAY UNIT ® 05/76 ORIGINAL COMPLETION 9/19 JCM TTP PULLED WELL: 09 -04A 03/01/93 RIG SIDETRACK(09 -04A) 12/11/11 RWM/PJC PERFS (12/06/11) PERMIT No: x 1930240 09/24/05 PJC GLV CORRECTIONS API No: 50- 029 - 20212 -01 09/24/05 EZL /PJC WAIVER SFTY NOTE DELETED SEC 2, T1ON, R15E405' NSL & 747' WEL 08/09/06 RCT /PJC GLV C/O 09/02/06 MSS /PAG SET HES XXN @ 9440' SLM I BP Exploration (Alaska) UNDER EVALUATION: 09-04A~TD #1930240) Sustained Casing Pres~e on the OA Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWe111ntegrityEngineer@BP.comJ Sent: Tuesday, February 16, 2010 4:18 PM !~~~ 2~ 6~ + ~u To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer ~ Subject: RE; UNDER EVALUATION: 09-04A (PTD #1930240) Sustained Casing Pressure on the OA Attachments: 09-04A TIO Plot.doc Hi Jim, There is a delay in the computer data systems that generate the plot so the plot includes data up to the prior day. ;.~ Here is a current TIO plot. Thank you, Anna Dube ~.a~,~s~~~.~ ~L~ ~"~ ~' ~.Q1 From: Regg, James 6 (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, February 16, 2010 4:09 PM To: NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: 09-04A (PTD #1930240) Sustained Casing Pressure on the OA I'm not seeing the 1700psi OA pressure on the TIO plot; is this a typo? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Saturday, February 06, 2010 9:10 PM To: Regg, James B (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSU, ADW Well Integrity Engineer; Nash, Justin Subject: UNDER EVALUATION: 09-04A (PTD #1930240) Sustained Casing Pressure on the OA All, Well 09-04A (PTD #1930240) has been confirmed to have sustained OA casing pressure. The wellhead pressures were tubing/IA/OA equal to 1890/1890/1700 on 2/06/10. The well has been reclassified as Under Evaluation for diagnostics. The plan forward is to install a heater on the wellhead and monitor for OA pressure build-up rate in addition to a pack-off test to evaluate the integrity of the wellhead seals. A TIO plot and wellbore schematic have been included for reference. «09-04A TIO Plot 02-06-10.doc» «09-04A.pdf» Please call with any questions or concerns. Thank you, 2/16/2010 UNDER EVALUATION: 09-04A~TD #1930240) Sustained Casing Pres~e on the OA Page 2 of 2 Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 2/16/2010 PBU 09 -04A PTD #1930240 2/16/2010 TIO Pressures Plot 4,000 3,000 - • - - -- Tbg f IA 2,000 - — A--- 0A 00A 000A �On 1,000 - 11/21/09 11/28/09 12/05/09 12/12/09 12/19/09 12/26/09 01/02/10 01/09/10 01/16/10 01/23/10 01/30/10 02/06/10 02/13/10 • • PBU 09 -04A PTD 1930240 2/6/2010 TIO Pressures Not 4.000 • 3.000 - —0— Tbg — IN — IA 2.000 - -4- OA 00A — OOOA On 1,000 A — 12/12/09 12/19/09 12/26/09 01 '02110 01 /09/10 01/16/ 10 01 /23/10 01 /30/10 02/06110 TREE = 6 -3/8" CIW WEL • =" FMC ACTUATOR = OTIS 09-04A SAFETY NO :CHROME TBG & LNR. 7" TBG CROSSES KB. ELEV = 54' OVER FROM 26# TO 29# @ 2210' - BF. ELEV = N/A KOP = 3500' Max Angle = 39 Datum MD = 9733' ( 2153' I 7" CAMCO BAL -O SSSVN, ID = 5.937" I Datum ND = 8840' S5 19-5/8" FOCI -1 2333' I GAS LIFT MANDRELS 19 -5/8" FOC -1 2456' I -'- ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3257 3255 6 OTIS DOME RA P. 16 08/09/06 113 -3/8" CSG,72 #, MN -80, ID= 12.347" H 2701' I 4 2 4036 4014 16 OTIS DMY RA r 0 03/01/93 3 4534 4494 20 OTIS DMY RA r 0 03/01/93 7" TBG, 29 #, 13 -CR .0371 bpf, ID = 6.184" H 3208' ( 4 5114 5003 33 OTIS DMY RA " 0 03/01/93 17" X 5 -112" TBG XO, ID = 4.892" I 3210' 5 5731 5491 39 OTIS DOME RA r 16 08/09/06 E L 6 6389 6010 37 OTIS DMY RA r 0 03/01/93 7 7009 6506 37 OTIS DMY RA r 0 03/01/93 Minimum ID = 3.725" @ 9445' 8 7630 7013 36 OTIS DOME RA r 16 08/09/06 4 -1/2" OTIS XN NIPPLE 9 8170 7461 35 OTIS DMY RA ' 0 03/01/93 10 8396 7646 34 OTIS SO RA r 28 08/09/06 15 -1/2" TBG,17 #, 13 - CR, .0232 bpf, ID = 4.892" I—I 8413' I \ / I 8415' 1— I5 -1/2" X 4 -1/2" TBG XO, ID = 4.892" I 'TOP OF TIW TIEBACK SLV H 8465' I 19 -5/8" X 7" TM/ LG -6 PKR H 8474' I 0 9 -5/8" X 7" TIW DTHS HGR 479' I 9 -5/8" CSG MILLOUT WINDOW H 8 8639' - 8680' (SECTION MILL) 1 9-5/8" CSG, 47 #, MN -80, ID = 8.681" H 8639' I 9293' 1 I4 -1/2" OTIS X NIP, ID = 3.813" I .4. 9309' I-17" X 4 -1/2" BKR SABL -3 HYD PKR, ID = 4.000"1 .r vf 9427' --I4 -1/2" PARKER SWS NIP, ID = 3.813" I I 9445' H4-1/2" OTIS XN NIP, ID = 3.725" I 9457' H4-1/2" WLEG I 4 -1/2" TBG,12.6 #, 13 -CR, .0152 bpf, ID = 3.958" I - 1 9456' PERFORATION SUMMARY ` REF LOG: BHCS ON 02/25/93 ANGLE AT TOP PERF: 18 @ 9528' N N1 Note: Refer to Production DB for historical perf data 10060' — FISH -BOW SPRING SIZE SPF INTERVAL Opn /Sqz DATE DECENTRALIZER 3 -3/8" 4 9528 - 9548 0 04/03/93 17" MARKER JT (20') H 9546' I (LOST 04/01/93) 3 -3/8" 4 9538 - 9554 0 09/18/95 3 -3 /8" 4 9548 - 9554 0 04/03/93 3 -3/8" 4 9604 - 9612 0 03/22/93 3 -3/8" 4 9622 - 9630 0 03/22/93 3 -3/8" 4 9814 - 9818 0 12/23/94 3 -3/8" 8 9814 - 9818 0 09/18/95 • 3 -3/8" 4 9866 - 9880 0 09 illi` 3 -3/8" 4 9912 - 9916 0 12/23/94 # "P4 ' I PBTD I 10066' t� 14 0% 1 17" LNR, 29 #, 13 - CR, .0371 bpf, ID = 6.184" I—I 10106' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05176 ORIGINAL COMPLETION 9/19 JCM/TLH TTP PULLED WELL: 09 -04A 03/01/93 RIG SIDETRACK (09 - 04A) PERMIT No: 1930240 09/24/05 PJC GLV CORRECTIONS API No: 50- 029 - 20212 -01 09/24/05 EZL/PJC WAIVER SFTY NOTE DELETED SEC 2, T1 ON, R15E 405' NSL & 747' WEL 08/09/06 RCT /PJC GLV C/O 09/02/06 MSS /PAG SET HES XXN @ 9440' SLM BP Exploration (Alaska) OPERABLE: Producer 09 -04A (PTD .30240) OA pressure manageable by b ds Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] re=, "fl 71/1i( Sent: Saturday, February 05, 2011 8:14 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead Cc: Holt, Ryan P (ASRC); AK, D &C Well Integrity Coordinator; Longden, Kaity Subject: OPERABLE: Producer 09 -04A (PTD #1930240) OA pressure manageable by bleeds All, An OA repressurization test was conducted on Producer 09 -04A (PTD #1930240) between 1/31 -2/5. The OA pressure increased —42 psi /day making it manageable by bleeds. Therefore, 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 XAMIED MB 2< .01 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, January 22, 2011 10:03 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, RES GPB •st Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D: ell Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Longden, Kaity Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); King, Whitney Subject: Producer 09 -04 (PTD #1930240) Sustained OA Casing Pressure A..ve MOASP All, Producer 09 -04 (PTD #1930240) has confirmed OA casing pressure above MOASP The wellhead pressures were tubing /IA/OA equal to 1970/1990/1070 on 20/2011. The well has been reclassified as Under Evaluation. Plan forward: 1. DHD: Outer Annulus Represurization Te: (OART) A TIO plot and wellbore schematic h. e been included for reference. « File: Producer 09 - 04 (PT #1930240) TIO Plot.doc » Please call if you have q - stions or concerns. 2/7/2011 A ,L.:\."t:,v I:.U OCT 1 0 2006 ALASKA Oil AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons Com . . . miSSIOn REPORT OF SUNDRY WELL OPERATIONS Anchorage . STATE OF ALASKA . 1. Operations Performed: Repair WellŒJ Abandon 0 Plug PerforationsD Stimulate 0 OtherŒJWH REPAIR Alter CasingD Pull TubingD Perforate New Pool 0 WaiverD Time ExtensionD Change Approved ProgramD Operation Shutdown 0 Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œ1 ExploratoryD u 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphìcO ServiceD 50·029-20212-01·00 7. KB Elevation (ft): 9. Well Name and Number: 50.20 09-04A 8. Property Designation: 10. Field/Pool(s): ADL-028321 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10106 feet true vertical 9208.0 feet Plugs (measured) None Effective Depth measured 10066 feet Junk (measured) Bow Spring Decentralizer @ 10060 (04101/93) true vertical 9170.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20" 94# H·40 28 - 104 28.0 - 104.0 1530 520 SURFACE 2614 13-3/8" 72# MN·80 27 . 2701 27.0 - 2101.0 5380 2670 PRODUCTION I 8613 9-5/8" 47# MN·80 26 - 26.0 . 6870 4160 PRODUCTION 9-5/8" 47# SOO·95 - 8639 . 7S45.0 8150 50S0 LINER 1623 7" 29# 13CrSO 8483 - 10106 1717.0 - 9207.0 8160 7020 ~~CAN~~EJ) <D' 'í 2nnÇ:, <!J ,J... ,..............'....¡ Perforation depth: Measured depth: 9528-9554,9604-9612,9622·9630,9814-9818, 9866·9880, 9912·9916 True vertical depth: 8660-8685, S732-8740, 8149-8157, 8930-8934, 8980·8993, 9023-9027 Tubing ( size, grade, and measured depth): 7" 29# 13Cr80 @ 23 - 3210 5-1/2" 11# 13CrSO @ 3210 . 8415 4-1/2" 12.6# 13CrSO @ 8415 - 9451 Packers & SSSV (type & measured depth): 9·5/S" TIW LG·6 Packer @ 8414 7" Baker SABL-3 HYD Packer @ 9309 7" Cameo BAL-O SSSVN @ 2153 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDM58Ft , 1 7006 } Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaqe Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubing Pressure Prior to well operation: 330 6540 10149 .-- 204 Subsequent to operation: SI 0 0 -- 112 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development[!J ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¡Sundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature h?l. ¿p .5l1/ .-/ Phone 564-5114 Date 10/5/06 Form 10-404 Revised 4/200 tP\C:~ r~ f.\ ; J ' \ D, . . 09-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/19/2006 *** WELL SI ON ARRIVAL *** (post wh repair) EQUALIZED & PULLED 4.5" XXN PLUG FROM 9431' SLM.RDMO *** WELL LEFT S/I *** 09/08/2006 TII/O = 33/5/20. SI. AL line shut-in at manifold building & lateral valve. Bleed WHPs to 0 psi (pre Valve c/o). TBGP increased 28 psi, OAP increased 15 psi overnight. TBG & IA FL @ 30', OA FL @ 36'. Bleed WHPs to bleed trailer 66-237 to 0 psi (7 hrs). RDMO. Final WHPs = 0+/0+/0+. 09/07/2006 TII/O = 330/1010/580. SI. AL line shut-in manifold building & at lateral valve, had grease crew service lateral valve. Bleed WHPs to 0 psi (pre Valve c/o). TBG & IA FL @ 3257' (Sta # 1) 83 bbls, OA FL @ 240'. Bleed WHPs to U/T # 071 to 5 psi (9.5 hrs). RDMO. Final WHPs = 5/5/5. 09/03/2006 ** CONT FROM 9-2-06 WSR**(SECURE WELL) PERFORMED GOOD TEST ON PLUG TO 2000 PSI. ** TURNED WELL OVER TO DSO, LEFT SHUT IN** 09/03/2006 (continue from 9/2/06) MIT TBG T02000 PASSED Pumped 8 bbls to reach test pressure tbg lost 125 psi in first 15 min lost 100 psi in first 15 min of second test and 25 psi in second 15 min for a good test FWHP=0/1000/600 09/02/2006 TII/O= 2000/1000/580 Assist S/L, Load and kill well. Freeze Protect w/ crude. 09/02/2006 ***WELL SI ON ARRIVAL *** {secure well for tree repair} LRS DISPLACED WELL FOR H2S SET 41/2" XXN W/ 18" FILL EXT @9440' SLM (T/I/O- VAC/1000/600 WHEN SET) ATTEMPTING TO TEST PLUG ** JOB IN PROGRESS ** 08/12/2006 TII/O= 2000/2000/1020. Temp= SI. TIFL PASSED eval high lAP & OAP (DSO call in). IA FL @ 6992' above sta# 7. OA FL @ 216'. Blocked AIL line in manifold building. Bled AIL line to DHD UR from 2000 psi to 0+ psi in 30 minutes. Sllateral valve on AIL line. Bled lAP from 2000 psi to 970 psi in 3 hours. Bled OAP from 1020 psi to 390 psi in 30 minutes (all gas). Monitored for 1 hour. Final WHP'= 2000/970/390. 08/10/2006 (gllrate) PULLED WHIDDEN CATCHER SUB. RIG DOWN. *** TURN WELL OVER TO DSO *** 08/09/2006 (gl for rate) PULLED 1.5" GLVs FROM STA. # 1,5,8, & 10. SET 1 .5" DOME VALVES & RA IN STA #1 (3254' SLM),STA #5 (5734' SLM), STA #8 (7632' SLM), & OGLV IN STA #10 (8392' SLM). *** JOB IN PROGRESS *** 08/08/2006 *** WELL SI ON ARRIVAL *** (gl for rate) SET WHIDDON CATCHER SUB @ 8398' SLMPULLED STA #10 S/O GLV @ 8386' SLM. PULLED STA #8 DOME GLV @ 7628' SLM. PULLED ST A #5 DOME GL V @ 5736' SLM. 08/07/2006 TII/O = 740/1950/850. Temp = SI. WHPs (eval high lAP). AIL is connected. No companion on the IA. 08/03/2006 TII/0=180/2000/700 Temp=SI TBG & IA FLs TBG FL @ 2153' SSSV. IA FL @ 7473' between ST# 7 & 8. Page 1 . . 09-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/28/2006 TIO = 920/1830/740. Temp = SI. TBG & IA FL (for DSO). TBG FL @ 3540'. IA FL @ 7540' (OGLV @ 8396'). 07/20/2006 TIO = 2000/2000/900. Temp = 51. TBG FL (DSO call in for FP). TBG FL @ 7610'. 07/10/2006 TestEvent --- BOPD: 330 BWPD: 10,749 MCFPD: 6,540 AL Rate: 4,001 FLUIDS PUMPED BBLS 2 Diesel --- PT Surface Equipment 10 Neat Methanol 493 Crude 505 TOTAL Page 2 TREE = WElLHEAD = . CTUA TOR = KB. 8..BI = BF. ElBl = KOP= IVIax Angle = Datum MD = Datum lVD = 6-3/8" CrN FMe OTIS 54' NlA 3500' 39 @ 5509' 9733' 8800' SS 09-04A SAFETY NOTES: CHROMETBG & LNR 7" TBG CROSSES OVER FROM 26# TO 29#@ 2210'- 19-5/8" FOC I 19-5/8" FOC I \13-3/8" CSG,72#, MN-80, ID = 12.347" H DATE 08/09/06 03/01/93 03/01/93 03/01/93 08/09/06 03/01/93 03/01/93 08/09/06 03/01/93 08/09/06 2153' - 7" CAMeO BAL-O SSSVN, ID = 5.937" I GAS LIFT MANDR8..S ST MD lVD DEV 1YÆ VLV LATCH PORT 1 3257 3255 6 OTIS DOME RA 16 2 4036 4014 16 OTIS DMY RA 0 3 4534 4494 20 OTIS DMY RA 0 4 5114 5003 33 OTIS DMY RA 0 5 5731 5491 39 OTIS DOME RA 16 6 6389 6010 37 OTIS DMY RA 0 7 7009 6506 37 OTIS DMY RA 0 8 7630 7013 36 OTIS DOME RA 16 9 8170 7461 35 OTIS DMY RA 0 10 8396 7646 34 OTIS SO RA 28 7"TBG,29#,13-CR. .0371 bpf, 10=6.184" 17" X 5-1/2" TBG XO, 10 = 4.892" H Minimum ID = 3.725" @ 9445' 4-1/2" OTIS XN NIPPLE 15-1/2" TBG,17#, 13-CR, .0232 bpf, 10 = 4.892" I I TOP OF TIW TIEBACK SL V I 9-5/8" X 7" TrN LG-6 PKR H 19-5/8" X 7" TIW DTHS HGR H 19.5/8" CSG, 47#, MN-80, ID = 8.681" H 8413' 8465' 8474' 8479' 8639' ] 8415' -15-1/2" X 4-1/2" TBGXO, 10=4.892" I 9-5/8" CSG MILLOUT WINDOW 8639' - 8680' (SECTION MILL) 14-1/2" TBG,12.6#, 13-CR, .0152 bpf.ID= 3.958" I 9456' -14-1/2" PARKER SWS NIP, 10 - 3.813" -14-1/2" OTIS XN NIP, 10 = 3.725" I 14-1/2" WLEG I ÆRFORA TION SUMMARY REF LOG: BHCS ON 02/25/93 ANGLEAT TOP ÆRF: 18 @ 9528' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9528 - 9548 0 04/03/93 3-3/8" 4 9538 - 9554 0 09/18/95 3-3/8" 4 9548 - 9554 0 04/03/93 3-3/8" 4 9604 - 9612 0 03/22/93 3-3/8" 4 9622 - 9630 0 03/22/93 3·3/8" 4 9814 - 9818 0 12/23/94 3-3/8" 8 9814 - 9818 0 09/18/95 3-3/8" 4 9866 . 9880 0 09/18/95 3-3/8" 4 9912 - 9916 0 12/23/94 DATE 05/76 03/01/93 09/24/05 09/24/05 08/09/06 09/02/06 RBI BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK (09-04A) PJC GLV CORRECTIONS EZUPJC WAIVER sm NOTE DElETED RCT/PJC GLV C/O MSS/PA SET HES XXN @ 9440' SLM DATE 9/19 17" MARKERJT(20') H 9546' FISH-BOW SPRING DECENTRALIZ ER (LOST 04/01/93) IPBTD I 10066' [2" LNR, 29#, 13-CR, .0371 bpf, 10 = 6.184" I 10106' REV BY COMMENTS JervvTLH TTP PULLED PRUDHOE BA Y UNIT WElL: 09·04A PERMIT No: 1930240 API No: 50-029-20212-01 SEC 2, T10N, R15E405' NSL & 747' Wa. BP Exploration (Alaska) 08/05/03 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2933 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Color Well Job # Log Description Date Blueline Prints CD D.S. 9-04A I ~,,.~~(")...-~ z~ PROD PROFILE/DEFT 07/3t/03 NK-38 'J ~/~ "/7(~' STATIC PRESSURE SURVEY 08/01/03 E-IOA j cfc/- ©L[~ LDL 07107,03 C-16 I ~-'~"~ t ~ GRAVEL PACK W/RST-C 04/30103 D.S. t1-16 [ ~ (.O" ~'~"~rc'~ PROD PROFILE/DEFT/GHOST 06/05/03 R-34 ~ c~ 5'- \ ~.'~' INJECTION PROFILE 05/17/03 D.S. 7-21 , ~r~ ~-~ '-L'~'~ LDL 07'30'03 D-14A~ ~( ~-" [ ~'-~,"~' '- LDL 07~28~03 P2-03 f _~ ~- C-~[~[ C.~R 05~03~03 A-06 I'-~r~(~'") ~:~ PROD PROFILE/DEFT 06127/03 D.S. 4-11A ~ C_.(.~.-~_ ~.~,, LEE 07/21/03 3-25/M-27 ~'~"~C}~-~ i~. SCMT (REPRINT-DEPTH SHIFTED) 01/04/03 -*S-28B ~..~--~ 23414 CHMEMGR(PDC) 03/09/03 *(PRINTS SENT OUT 5108103) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Schlumberger Ge~)Q~e'st/,-.'~ 3940 Arcbc Blvd,[iSt~,,te..3~0 Anchorage, AK 99503-571 ATTN: Beth ~...~., ~ STATE OF ALASKA ALASK,~~''-~'': AND GAS CONSERVATION CC '-'"41SSION REPORT SUNDRY WELL OPI=rIATIONS 1. Operations performed: Operation shutdown . Stimulate . Plugging , Perforate X . Pull tubing Alter casing Repair well Other ~ . ,' '"~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 405' NSL, 747' WEL, Sec 2, T10N, R15E, UM. At top of productive interval 1238' NSL, 3605' WEL, Sec 2, T10N, R15E, UM. At effective depth At total depth 1351' NSL, 3767' WEL, Sec 2, T10N, R15E, UM. 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevatT5r~(~'F.dr. KB) 54' RKB ~"~'"::i ,'? 7. Unit or Property Prudhoe Bay Unit feet 8. Well number 9-04A 9. Permit number/approval number 93-24 10. APl number 50 - 029-20212-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10106 feet 9208 feet Plugs(measured) PBTD Tagged @ 9910' MD (11/10/95). Effective depth: measured 9910 feet true vertical 9020 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 76' 20" 300 Sx AS 76' 76' Surface 2701' 13-3/8" 6400 Sx AS 2701' 2701' Production 8680' 9-5/8" 1000 sx CIG & 300 sx AS 8680' 7878' Liner 1621' 7" 308 Sx CIG 8465 - 10106' 7849 - 9207' Perforation depth: measured 9528 - 9554'; 9604 - 9612'; 9622 - 9650'; 9814 - 9818'; 9866 - 9888'; 9912 - 9916' true vertical 8660 - 8685'; 8732 - 8740'; 8749 - 8776'; 8931 - 8934'; 8980 - 9000'; 9023 - 9027' 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached 14. Tubing (size, grade, and measured depth) 7", 264¢, 13CR-80 @ 3210' MD; 5-1/2", 17#, 13CR-80 @ 8413' MD; 4-1/2", 12.69, 13CR-80 @ 9457' MD. Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 9309' MD; Camco BAL-O SSSV @ 2153' MD. JAN 0 4 Treatment description including volumes used and final pressure .~;~,~ ¢!it ~i~ f:?-:.'.;~.~ Cons, Comr,~ission Representative Daily Average Production or Iniection D. _a~.~horage OiI-Bbl Qas-Mc'f Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 539 2525 7937 -- 281 Subsequent to operation 784 2137 7518 -- 275 15. Attachments Copies of Logs and Surveys run ,, Daily Report of Well Operations x 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby.certify that the foregoing is true an,,9,C~correct Form~10-.4~4 Rev 06/15/88 to the best of my knowledge. Title Engineering Supervisor cc: KZ, JWP SUBMIT IN DUPLICATE ~.. 9-04A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 9/1 8/95: MIRU & PT equipment. RIH w/perforating gun & shot 34' of reperforations as follows: Reperforated: 9538 - 9554' MD (Z4) 9814 - 9818' MD (Z2) 9866 - 9880' MD (Z2) Ref. Log: BHCS 2/25/93. Used 3-3/8" carriers & shot 4 spf at 60 degree phasing at underbalanced pressures. POOH w/perf guns. Noted all shots fired. Rigged down. I I/1 0/95: RIH & tagged PBTD at 9910' MD. Returned the well to production w/gas lift & obtained a valid welltest. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9930 Company: 12/15/95 Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 4-8 " ~ ~ '/0 ,, , INJEC PROFILE 951109 1 I ,,, ' ..... D.S. 4-13 -7 ~ 31,,, INJECPRORLE 951109 I 1 D.S. 4-17 ~.,O INJEC PROFILE 95111 8 I 1 D.S. 4-19 ~ ~ . ~DUAL BURST TDT-P 9511 1 2 I 1 D.S. 4-28 ~ 3-~rO. ! INJECTION pROFILE 95111.0 I ....... I .. D.S. 5-4 ' ~ ~'-C/ PROD PROFILE 951115 1 1 O.S. 9-04At~ ~,~ !PRODPRORLE 951110 I I '" D.S. 14-16 <~ I'_ PROD LOG WITH DEFT 9 511 0 7 I 1 ,, D.s. 16-02 ~"(~ { ~-(~ MI INJECTION pROFILE LOG 9511 19 I .... 1 '" D.S. 18-23A ~ ~ ' I ~ LEAK DETECTION LOG 951114 1 , 1 ,,, " , ,, ,, 1 ,, , SlGNED:~~_~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9762 Company: 9/27/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date BL Floppy RF Sepia DIR MWD Disk D.S. 1-28 ~-~,~"'" pRODUCTION PROFILE 950921 1' 1 ........ D.S. 1-31 ~'/o ' I ~ ~ PRODUCTION PROFILE 95 0 92 0 I 1 ............ ,, D.S. 2-15 ~- O17 PRODUCTION PROFILE 950920 I I ...... D.S. 9-3 '7(~- 0~'~ BAKER INFLATABLE BRIDGE PLUG 95091 7 I 1 ," PERFORA ONRECOR D.S. 12-15 E,~'~'- BAKER INFLATABLE BRIDGE pLuG 950921 I ' ' I ' ' D...S.; .16-02 ~'0 -I ~O !.NJEC .TION PROFILE 95 0 921 I I ....... D.S.~,,.17.,2! .?~-"12-_.~"' PERFORATION RECORD 950919 ..... I 1 ............... ,, , , ...... ....... · .... , ,, I , , SIGNED: Please sigh/and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 501) w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9739 Company: 9/20/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 1-11 '7 '~ C~.~-, 7 PERFRECORD " 950902 I '1 D.S. 1-10 "7.)'-, ~,L~_~ PROD PROFILE .... 950'902 1 1 .,," ,,, ,' O.S. 1-20 ~"~..:. I. q ~' PROD PROFILE 9 5 0 9 0 5 I 1 D.S. 1-22A ~ ,~ "~ _~.--~.- BAKER INFLA+ABLE BRIDGE PLUG 950906 I I .... D.S. 5-6A ~ ~'~' (.3 ~'~ PERFREcORD ........ 950905 1 1 '~)':S. 9-4A ,,C~,~Z~, 'O'2--'~ RSTB/GR' ' ' , , ,,950813 1 1 D.S,' 11.28 ~"~ .... C~'~ . CHEMICAL CUTTER RECORD 950903 1 I .. D.S. 13-34 c~ I.~ ~ LEAK DETECTION 950904 1 1 D.S. 15-12~' i'~{ (~ BAKER INFLATABLE BRIDGE"PLUG 950901 i' 1 "' , , ,, ~ SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. SEP 2 Alaska 0il &.Gas C......, DATE: A'~Ch~'~ GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9697 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 9/6/95 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 4.7 sT1 95292 CNTD .... '7 ,~"-~ 6'7'7 ' '~ ~/~ ~ ~950809' ' 1 -- D.S. 9r4A.. 95302 CNTG 'O '~---&2~ ~ ~1~ 950819 1 ~.s. ,~.~ ,~ c,~ ~?~ ~.~ (;~ ~ ~0~,,~ ........... ...... ,, ,, ........... , , , , ,, e '~C~I vED SIGNED' ~~_'___~__ ............ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I'TN: Sherrie NO. 9683 Company: 8/31/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 01-33 ~;~.(_o ,J / ,?.__-z_-- LEAK DETECTION 950808 I 1 D.S~,, 4-'i9~J)~ "~-~ 'TEMPERATURE/pRESSURE& 950811 1 I '~ , ........ D.S. 6-17 , ~.~- 4~1 ~ .... LEAK DETECTION LOG 950807 1 1 D.s. 9-4A "CNTG ....... 950819, , , 1 I .................... D.S. 9-41,,, ~-(~ "~IL PRODUCTION PROFILE ..... 950810 I I , D.S. 13-34 ~__ .'~- I .~ (~) pRODUCTION PROFILE 950801 I 1 D.S. 14-18/~! ~,Q~_ STATIC BHP SURVEY 950812 I 1 9.S. 15-12 ~ t !~ ~ BRIDGE PLUG SET RECORD 950805 I 1 ......... ............ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. · . OEP 0 1 1095 DATE: Alaska 0ii & Gas Co~s. Commissio.n Anchorage GeoQuest / 'C~)500 W. InternationalAirport Road , Anchorage, AK 99518-1199 A'I'TH: Sherrie RECEIVED Z "t 95 1995 Nasd Oil ~ Cas ConS. ~o~is~o~ ~~h°¢g0 mas~ 0il & Gas Cons. Commission ... Anchorage NO. 9211 Company: 1/23/95 Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description BL RR Sepia RF Sepia Mylar D.S. 1~3 . ' POGLM SE.T'!~'~.ING RECORD (12-23-94) '" ..~1 . ..... -'"1 ..... . ......... ..... O.S. 1-3. ........... POGLM RECORD (1-3-9.5) v-1 .... vl ...... ,aD.S. lr25 .......LEAK DETECTION (1-3-95) ...... v'l v' 1 D.S. 3-27 .... BAKER IBP RECORD (12-31-94) ...... v-1 .. ~"1 D.S. 4-7 ST ~ .... PERF RECORD (12-30-94} .. ¢'1 ,/1 D. rS. 4-22A. PRO..D PROFILE (12-26-g4) .. ~'1 .., v"l · D.S. 6-4 ..... PERF RECORD (12-25-94) ......... .-'1 . r D.S. 6-14A PERF RECORD (12-26-94) ........ ,,'1.. ,,'1 D.S. 9-4A PERF RECORD {12 23-94) ... ~ D.S. '9-30 ST PERF RECORD (1-2-g5) .... D.S. 9-32 PERF RECORD (12-25-94) .~'1 ,-"1 I D.S. 11-16 ST I LEAK DETECTION (12-.31-94) ~ ,,-'1 D.S. 11-23A . PERF RECORD (12-21~94) ~ ~ .... 7 D.S. 13-15 SBHPS & INJEC PROFILE (12-29-94) ~ ~1 ... ~ D.S. 13-33 ... LEAK DETECTION (12-30-94) I 1 ~ D..S. 13-33 ....... BAKER INFLAT BRIDGE PLUG RECORD (.1-3-95) .,1 ,"1 ............ .~.D.S. 14-21 SBHPS & INJEC PROFILE (12-23-94) ~1 '"1 ~/D.S. 15-7A ..... DUAL BURST TDT-P (12-27-94) . v'l. ~1 .. I D.S. 15-30 ...... LEAK DETECTION (12-27-94) ~1 ~'1 D.S. 15-30 .. DUAL BURST TDT-P (CT/E-LINE) (12-30-94) ,,,1 ,'"1 D.S. 18-9A DUAL BURST TDT-P (12-22-94) ,,q v'1 ... ~_D.S. 18-27 DUAL BURST TDT-P (CT/E-LINE) (12-29-94) SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA ALASKAf 'LAND GAS CONSERVATION CC tllSSIOU REPORT 'F SUNDRY WELL OPI::rlATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate ,,,, ,,, Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 405' NSL, 747' WEL, Sec. 2, T10N, R15E, UM At top of productive interval 1238' NSL, 3605' WEL, Sec. 2, T10N, R15E, UM At effective depth At total depth 1351' NSL, 3767' WEL, Sec. 2, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-04A 9. Permit number/approval number 93-24 10. APl number 50 - 029-20212-01 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10106 feet 9208 feet Plugs(measured) PBTD Tagged @ 9955' MD (12/12/94) Effective depth: measured 9955 feet true vertical 9064 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 76' 20" 300 sx AS 76' 76' Sudace 2701' 13-3/8" 6400 sx AS 2701' 2701' Production 8680' 9-5/8" 1000 sx CL 'G' & 300 sx AS 8680' 7878' Liner 1621' 7" 308 sx CL 'G' 8465-10106' 7849-9207' Perforation depth: measured 9814-9818'; 9528-9554'; 9604-9612'; 9622-9650'; 9866-9888'; 9912o9916' true vertical 8931-8934'; 8660-8685'; 8732-8740'; 8749-8776'; 8980-9000'; 9023-9027' Tubing (size, grade, and measured depth) 7", 26~, 13CR-80 @ 2210' MD; 7", 29#, 13CR-80 @ 3210' MD 5-1/2", 17#, 13CR-80, @ 8413' MD; 4-1/2", 12.6#, 13CR-80 @9457' MD Packers and SSSV (type and measured depth) 7" x 4-1/2" Baker SABL-3 Packer @ 9309' MD; 7" Camco BAL-O-SSSV @ 2153' MD D Ef'El~lEr't 13. Stimulation or cement squeeze summary I'~ L,, ~., I., I I/ L. ~ Intervalstreated(measured) See Attached JAN 2 4 ]995 14. Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation Alaska 0il & Gas Cons. Commission /[nnhnr,~ Representative Daily Average Production or Injection Data. OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1327 · 7826 5753 - 323 1807 /~- 7329 7455 - 326 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 cc: KZ, JWP. Title Engineering Supervisor Date /--/ SUBMIT IN DUPLICATE 9-04A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 12/12/94: RIH & tagged PBTD at 9955' MD. 1 2/23/94: MIRU & PT equipment. Added perforations: 9814 - 9818' MD (Z2) 9912 - 9916' MD (Z2) RIH w/perforating gun & shot 8' of add perforations as follows: Ref. Log: BHCS 2/25/93. Used a 3-3/8" carrier & shot 4 spf at 60/120 degree phasing, at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED JAN 2 4 1995 Ai~ska Oil & Gas Con~. Commission Anchor: PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page' 1 Date: 01/11/95 RUN DATE_RECVD 93-024 5564 c/Y 93-024 SURVEY 93-024 SURVEY 93-024 BHC/SL 93-024 CNL 93-024 DLL 93-024 PERF 93-024 PERF 93-024 PROD 8350-10120 BCS/DL/CNTH/GR 8642-8946 MWD E TELECO 8842-10082 SPERRY SUN L~9300-10065 1 9300--10047 1 9300-10088 1 A~-9300--10021 1 9390-9690 1 c~95OO-lOOOO 03/19/93 08/31/93 08/31/93 03/09/93 03/09/93 03/09/93 04/27/93 04/27/93 07/30/93 Are dry ditch samples required? yes ,~ And re.~ived? yes no Was the well cored? yes ~_~ Analysis & descriDtion~ received? Are well tests required?j/yes ~~Received~_~ ..... yes no Well is in compliance In~tiai yes no STATE OF ALASKA ALASKA~''''-''_ AND GAS CONSERVATION C('~''- AISSION REPORT SUNDRY WELL OPb ATIONS Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well ,, -- t. Operations performed: 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 405' NSL, 747' WEL, Sec. 2, T10N, R15E, UM At top of productive interval 1238' NSL, 3605' WEL, Sec. 2, T10N, R15E, UM At effective depth At total depth 1351' NSL, 3767' WEL, Sec. 2, T10N, R15E, UM Type of Well Development X Exploratory Stratigraphic Service Perforate X Other ~ 6. Datum of elevation(DF or KB) 54' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-04A 9. Permit number/approval number 93 -24 10. APl number 50 - 029-20212-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10106 feet Plugs(measured) 9208 feet Effective depth: measured 10066 feet true vertical 9170 teet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 76' 20" 300 sx AS 76' 76' Surface 2701' 13-3/8" 64.00 sx AS 2701' 2701' Production 8680' 9-5/8" 1000 sx CL 'G' & 300 sx AS 8680' 7878' Liner 1621' 7" 308 sx CL 'G' 8465'-10106' 7849'-9207' Perforation depth' measured 9528-9554';9604-9612';9622-9650';9866-9888' true vertical 8660-8685';8732-8740';8749-8776';8980-9000' Tubing (size, grade, and measured depth) 7",26#,13CR-80 (~ 2210' MD'7" 29# 13CR-80 ~ 3210' MD;7" x 5--1/2" xover @ 3208' MD;5 I/2",17#,13CR-80, (cb 8~1~-' ~;5-1/2" x 4-1/2" xover @ 8413' MD 4--1/2".12.6#,13CRSO,w/tail @ 9457' MD Packers and SSSV (type and measured depth) 7" x 4-1/2" Baker SABL-3 Hydroset pkr @ 9309' MD' 7" Camco BAL-O SSSV ~) 2153' MD 13. Stimulation or cement squeeze summary 14, Intervals treated(measured) S E P - 9 t993; Treatment description including volumes used and final pressure Alaska 0il & GaS C0llS. Representative Dail~aELe. Production or' Lnjection Data Anchorage Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl 0 0 0 7716 .~ 8823 0 Casing Pressure Tubing Pressure - 0 357 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Y~, Gas ~ Suspended .... Service 17. I hereby certify that the foregoing is true and correct 1o tt~e best of my knowledge. Signed~~~~ (%~ ~.¢~ Title FS-2 Senior Engineer Form 1~)-404',R/~V 06/15/8~ "' '( ---- Date SUBMIT IN DUPLICATE i,ILy REPORT OF WELL OPER. iONS DS 9-04A Perforating Operations: ARCO Alaska, Inc. perforated DS 9-04A at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 3/22/93 and 4/3/93. The intervals perforated were the following: 9528' - 9554', 9604' - 9612', 9622' - 9650' and 9866'- 9888' MD (Reference Log: SWS-BHCS dated 2/25/93). Completion fluid was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 3/22/93. RU perforating unit, pressure tested BOP's to 3500 psi and lubricator to 2500 psi, okay. RIH, opened well to flow and perforated 9868'-9888' MD at 4 SPF, SI well, POOH, and confirmed all shots fired. RIH, opened well to flow and perforated 9866'-9868' MD at 4 SPF, logged up and perforated 9630'-9650' MD, SI well, POOH, and confirmed all shots fired. RIH, opened well to flow and perforated 9622'-9630' MD at 4 SPF, logged up and perforated 9604'-9612' MD, SI well, POOH, hung up in tubing tail, pulled out of cablehead. (ref: SWS-BHCS of 2/25/93). Rigged down and secured well. Fished perf gun on 4/2/93. Began perforating operations on 4/3/93. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. RIH, opened well to flow and perforated 9548'-9554' MD at 4 SPF, RIH and perforated 9528'-9548' MD, SI well, POOH, and confirmed all shots fired. (ref: SWS-BHCS of 2/25/93). Rigged down and secured well. Alaska Oil a 6as Co,Is. Anchorage RDC: 9/7/93 ARCO/t~n_qk~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA 12-20-92 2-25-93 2-27-93 4-19-93 4-9-93 3-19-93 3-23-93 4-18-93 2-23-93 2-26-93 3-7-93 3-13-93 4-6-93 4-15-93 3-7-93 4-1-93 12/6-23/92 1/23-2/6/93 MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MW]) Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey 12/30-1/15/93 MWD Directional Survey 12-9-91 MWD Directional Survey 1-15-92 MWD Directional Survey 1/92 MWD Directional Survey 2-9-93 MWD Directional Survey 1-16-93 MWD Directional Survey 12-27-92 MWD Directional Survey 1-18-93 MWD Directional Survey 1-17-93 MWD Directional Survey 2-16-93 MWD Directional Survey 2-24-93 MWD Directional Survey 4-28-93 MWD Directional Survey 3-7-93 MWD Directional Survey 3-17-93 MWD Directional Survey 3-30-93 MWD Directional Survey Please sign and return the attached copy as RECEIVED BY_~~~ Have A Nice Day! Sonya Wallace ATO- 1529 CHEVRON # CLINT CHAPMAN # EXXON MOBIL An8 Job#AKEI30010 Sperry Job#1209 BHI Ana Ana Job#AKEI30016 Sperry Job#AKMW30020 Sperry Job# 1188 Teleco Job#AKEI30009 Sperry Job # 1192 Teleco Job#AKEI30012 Sperry Job#1202 BHI Ana Ana Ana Job # 1159 Teleco Job # 1175 Teleco Job# 1167 Teleco Job #AKMM911128 Sperry Job#AKMM911231 Spe try Sperry Aha Job#AKMW30003 Sperry Job#AKMM921231 Sperry Job# 1168 Teleco Job# 1172 Teleco Teleco Job# 1185-450 Teleco Job# 1185 Teleco Job# 1190 Teleco Job# 1195-450 Teleco Job#1205 BHI receipt of data. R£c£/v APPROVED ~/~.¢~,~¢o.' !$$J ~ PB ~LL F~ES ~ BPX ~ ST. OF ~. (2 COP~) t LUCILLE JO~STON f"~-"%R'¥'-SUN DRtl =lNG SERVICES' ANCHORAGE ALASKA '"" 2"/" PAGE i PRUDHOE BAY DRILLING DATE OF SURVEY: 02/26/93 PBU/9-4A ORIGI~,~IAL ELECTRONIC MULTI-SHOT SURVEY' 500292021201 ...... JOB NUMBER' AK-ET-30009 NORTH SLOPE KELLY BUSHING ELEV. = 54.00 CO,M,,='UTATZON DATE: 3/ 1/93 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA COURS COURSE DLS TOTAL NEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST SECT. 8642 7846.86 7792.86 35 35 N 70.00 W .00 663.60N 2571.52W 2852.39 8885 8057.99 8003.99 24 8 N 59.44 W 5.16 713.41N 2681.54W 2772.26 8979 8143.75 8089.75 22 29 N 56.78 W 2.09 732.90N 2712.93W 2808.03 9074 8232.18 8178.18 21 37 N 55.38 W 1.06 752.89N 2742.67W 2842.38 9169 8320.90 8266.90 20 26 N 55.66 W 1.26 772.21N 2770.79W 2874.99 9262 8408.60 8354.60 19 12 N 55.36 W t.32 790.11N 2796.85W 2905,21 9356 8497.06 8443.06 18 49 N 55.05 W .43 807.52N 2821.89W 2934.30 9450 8585.96 8531,96 18 18 N 54.57 W .5? 824.73N 2846.3tW 2962.74 9545 8676.35 8622.35 18 28 N 54,63 N .17 842.15N 2870.82W 2991.32 9638 8764.52 8710.52 19 3 N 54.65 W ,62 859.49N 2895,25W 3019,82 9730 8851.85 8797.85 19 8 N 54.98 W .t4 876,91N 2919.97W 3048.61 9824 8940.48 8886.48 19 1 N 54.77 W .t4 894,55N 2945.04W 3077.81 9917 9028,49 8974.49 19 1 N 55.37 W ,21 911.93N 2969.93W 3106,74 10010 9116.14 9062.14 18 38 N 55.68 W .43 928,85N 2994.57W 3135.31 10041 9145.99 9091.99 18 46 N 55.67 W .42 934.55N 3002.91W 3144.97 10082 9184.84 9130,84 18 30 N 55,17 W .76 941.98N 3013,70W 3157.49 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DiMENSION MINIMUM CURVATURE HETHOD. HORIZONTAL DISPLACEMENT = 3157,49 FEET AT NORTH 72 DEG. 38 MIN. WEST AT MD = 10082 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 287.36 DEG. 'RRY-SUN DRILLING SERVICE~ ANCHORAGE ALASKA PRUDHOE BAY PBU/9-4A 50029202120 NORTH SLOPE COMPUTATION DRILLING DATE: 3/ 1/93 DATE OF SURVEY: 02/26/93 JOB NUMBER: AK-Ei-30009 KELLY BUSHING ELEV. = 54.00 FT. OPERATOR: ARCO ALASKA iNC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINAT NORTH/SOUTH EAST/WE ES MD-TVD VERTICAL ST DIFFERENCE CORRECTION 8642 7846,86 7792.86 663,60 N 2571.52 W 795.14 9642 8767.77 8713.77 860.14 N 2896.17 W 874.23 79.09 10082 9184,84 9130,84 941.98 N 30t3,70 W 898.14 23.91 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. '-~RY-SUN DRTLLTNG SERVTCES ANCHORAGE ALASKA PAGE PRUDHOE BAY PBU/9-4A 500292021201 NORTH SLOPE COMPUTATZON DRZLLZNG DATE: 3/ 1/93 DATE OF SURVEY: 02/26/93 JOB NUHBER' AK-EZ-30009 KELLY BUSHZNG ELEV. = 54.00 FT. OPERATOR: ARCO ALASKA ZNC ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTZCAL VERTZCAL RECTANGULAR COORDZNATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTZCAL DZFFERENCE CORRECTZON 8642 7846.86 7792.86 663.60 N 2571.52 8650 7854.00 7800.00 665.36 N 2576.47 8769 7954.00 7900.00 689.31 N 2634.81 8881 8054.00 8000.00 712.49 N 2679.98 795,14 796.86 1.72 815.14 18.28 827.34 12.20 8990 8154.00 8100.00 735.23 N 2716.48 9098 8254.00 8200.00 757.81 N 2749.79 9204 8354.00 8300.00 779.16 N 2780,96 9310 8454.00 8400.00 799.09 N 2809.83 9416 8554.00 8500.00 818.60 N 2837.68 836.21 8.87 844.00 7.80 850.91 6,9O 856.89 5.98 862.51 5.62 9521 8654.00 8600.00 837.82 N 2864.72 9627 8754,00 8700,00 857.39 N 2892.29 9733 8854.00 8800.00 877.34 N 2920.58 9839 8954.00 8900.00 897.24 N 2948.85 9944 9054.00 9000.00 916.93 N 2977.17 867.87 5.36 873.43 5.56 879.25 5.82 885.06 5.81 890.84 5.78 10050 9154.00 9100.00 936.08 N 3005,16 W 896.44 10082 9183.91 9129.91 941.80 N 3013.45 W 898,09 5.60 1 .65 THE CALCULATZON PROCEDURES USE A LZNEAR ZNTERPOLATZON BETWEEN THE NEAREST 20 FOOT ND (FROM MZNZMUM CURVATURE) POZNTS ECO Baker Hughes company 6324/6116 Nielson Way · Anchorage, AK 99518 Phone: (907) 563-3269/Fax: (907) 563-5865 Phone: (907) 562-2646 / Fax: (907) 561-1358 ORIGINAL EASTMAN TELECO MWD SURVEY DS 9- WELL 4A PRUDHOLE BAY Eastman Teleco appreciates the opportunity to provide our services. Please find attached a copy of the directional surveys. EASTMAN TELECO MWD Direct,dnai Surveys Company' Prudhoe Bay Drilling Field: Prudhoe Bay Borough: Pad/Drill Site' North Slope Driltinc~ Co.' Nabors Alaska Drillin.cl. Ri~.:` II~E dob #' Minimum Curvature method used, for Sur~ey calculations. Surveys measured from RKB located 51.7ft above MSL. DS 9 Well #: 4A FSE: Craig Tomoyer State: Alaska Country: t,JSA 1188 Date: Feb2$, 1993 Declination: 3[). 190° E Proposed Azimuth: 19.98° Survey Course Inc° Az1'° TVD VS N/S E/W DLS Depth Length ff ff ff fr °/1 CO' TIE-iN TO MAGNE TIC MULTI-S HOT 8642 35.6 290 7846.86 663,60 N 2571.52 W 8852 210 25.8 304,1 8027,44 -243,80 710,30 N 2667,15 W 5,76 8946 94 23.0 304.8 8113.04 -234.11 732.25 N 2699.18 W 2.99 ARCO ~]n__~n_, Inc. P.O.Bo~ 100:360 Anchorage, Alaska 99~10 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 3_ 18A ~0'~.18_93 5-13 77~ ~ 5-28-93 5-24 ~/-/~ 5-22-93 5-32 ~ l-? ~ 5-27-93 6-12A ~2-~ 5-29-93 6-14A ~/~75-19-93 7-147~1 5-25-93 9-3 ?s. ~- 5-18-93 9-3 5-24-93 * 9-4A ~-~ ? 5-26-93 9-5A ~-~ ~ 5-30-93 ** 9-28A ~-~ 5-28-93 9-31A ~35-19-93 9-32 ~/1~5-30-93 12-15 ~-~ z 5-27-93 12-23 ~ ~-~5-27-93 14-22 .a 5-23-93 x O~ ~ 18-29A ~5-18-93 AGI-1 ~ 5-20-93 AGI-I~'i 5-20-93 AGI-2 ~. ~¢~-23-93 AGI-2 ~-23-93 Pe~ Record AGI-3 ~ ~5s 5-20-93. ~/~ AGI-3 , ~5-21-93 ~ Peff Record AGI-4 ~A~ 5-22-93 ~t~ Peff Record Completion Record R~_m 1, 5" Sch TDTP (Borax) Run 1, 5" Sch GR/Collar Run 1, 5" Arias TDTP (Borax) Run 1, 5" Sch TDTP (Borax) Run 1, 5" Sch Production Log Run 1, 5" Sch Prod Profl/e Run 1, 5" Sch Perf Record Run 1, 5" Sch Prod Profile R~_m 1, 5" Sch Production Log Run 1, 5" Sch Completion Record R~m 1, 5" Sch Production Log Rim 1, 5" Sch CBT Run 1, 5" Sch Completion Record Run 1, 5" Sch Completion Record Run 1, 5" Sch ' Leak Detection Run 1, 2" Sch Perf Record Run 1, 5" Sch PITS Run 1, 5" Sch Perf Record R~m 1, 5" Sch Jewelry R~m 1, 5" Sch Perf Record Run 1, 5" Sch Jewelry R~m 1, 5" Sch R-n 1, 5" Sch R~m 1, 5" Sch Run 1, 5" Sch Please sign and return the RECEIVED Have A Nice Sonya Ws~!_~ce ATO-1529 Run 1, 5" Sch ~che~ as receipt of data~ /~C~/v~D # ~'rilAL # CHEVI~N #BPX # STATE OF ALASKA The correct well name for this log is 9-4A. The correct API# for 9-28A is 50-029-21292-01. ARCO -~l~_Sk~_, Inc. P.O.Box 100360 Anchorage, ,~l~_s~r~ 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 3.18A ~9~_18.03 5-13 77- ~ 5-28-93 5-24~/*/~ 5-22-93 5-32 5 J~? ~.5-27-93 6-12A ~7-~ 5-29-93 6-14A ~75-19-93 7-147P-~! 5-25-93 9-3 ?s~ ~.-- 5-18-93 9-3 5-24-93 * 9-4A ~-~ ¥ 5-26-93 9-5A ?~-~- ~ 5-30-93 ** 9-28A ~-~ 5-28-93 9-31A {~-~35-19-93 9-32 y3'~/1~5-30-93 12-15 e~ -~ z 5-27-93 12-23 ~-~5-27-93 14-22A~ .~z] 5-23-93 14-22AIi 5-23-93 (~ ~" 18-29A ~5-18-93 AGI- 1~../~ 5-20-93 AGI-1 5-20-93 AGI-2 qg- ~¢~5-23-93 AGI-2 /5-23-93 Perf Record AGI-3 ~, ~(}s 5-20-93, GR/(X~ AGI-3 , ~5-21-93 Primary Perf Record AGI-4 ~A~ 5-22-93 Initial Perf Record Completion Record Run 1, 5" Sch TDTP (Borax) Run 1, 5" Sch GR/Collar Run 1, 5" Atlas TDTP (Borax) Run 1, 5" Sch TDTP (Borax) Run 1, 5" Sch Production Log Run 1, 5" Sch Prod Profile Run 1, 5" Sch Perf Record Run 1, 5" Sch Frod Profile R-n 1, 5" Sch Production Log Run 1, 5" Sch Completion Record Run 1, 5" Sch Production Log R~n 1, 5" Sch CBT Run 1, 5" Sch Completion Record R-n 1, 5" Sch Completion Record Run 1, 5" Sch ' Leak Detection Run 1, 2" Sch Perf Record Run 1, 5" Sch PITS Rim 1, 5" Sch Perf Record R~_m 1, 5" Sch Jewelry Run 1, 5" Sch PerfRecord R~_!n 1, 5" Sch Jewelry R~_m 1, 5" Sch R~_m 1, 5" Sch Rim 1, 5" Sch Rim 1, 5" Sch Run 1, 5" Sch Sonya Wallace ATO-1529 The correct well name for this log is 9-4A. The correct AP1//for 9-28A is 50-029-21292-01. '~'~ STATE OF ALASKA -'~ ALASKA ,..,,L AND GAS CONSERVATION CC, .... VlISSION WELL COMPLETION OR RECOMP LETION REP ., :T AND LOG OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , ,. , / .... 2. Name of Operator 7. Permil NUmber ARCO Alaska, Inc. 93-24 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-20212-01 4, Location of well at surface 9. Unit 0~' Lease Name '405' NSL, 747' WEL, SEC. 2, TI ON, R15E .?':(~r;'ii;i':~'?i~;~'~7!~ -~'""~"' ~- "~'f3' ~ ~' 10.Prudh°ewell NumberBay Unit Al Top Producing Interval 1238'NSL, 3605' WEL, SEC. 2, TION, R15 ~ 11. Field and Pool At Total Depth Prudhoe Bay Field/Prudhoe Bay Pool 1351' NSL, 3767' WEL, SEC. 2, TION, R15~- 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 50.2' J ADL 28327 12. Date Spudded " 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completion~ I 2/22/93 2/24/93 4/3/93 N/A feet MSL J One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey ~20. Depth where SSSV set ~1. Thickness of Permafrost 10106' MD/9208' TVD 10066'MD/9170' TVD YES [] t,Z:) []! 2153'feet MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run DLL/S CC/C NL/GR/AMS 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ' WT. PER FT.' GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 76' 32" 300 sx AS cmt 13-3/8" 72# MN-80 Surface 2701' 17-1/2" 6400 sx AS cmt 9-5/8" 47# MN-80/S0095 Surface 8639' 12-I/4" 1000 sx "G"/300 sx AS 7" 29# L-80 8483' 10106' 8- I/2" 308 sx Class "G" 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) sIZE DEPTH SET(MD/ PACKER SET (MD~ Gun DiameterMD3-3/8" ¢~ 5-1/2" x 4-1/2" 9457' .r.. 9309' 9528"9554' 8660'-8685' 9604"9612' 8732'8740' 26. ACID, FRACTURE, CEMENT SQUEEZE., ETC. 9622"9650' 8749'--8776' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9866'-9888' 8980"9001' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 4/3/93 I Flowing Date of Test :Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure DALCULATED OIL-BBL GAS-MCF WATER-BBL DIL GRAVITY-APl (corr) Press. 24.-HOUR RATE 28. CORE DATA ' Brief description of lithology, porosity, fractures, apparent dips, and presence ofoil, gas orwater. Submit ~c~(____~p~, i V~ D MAY -- ;~ 1~993 Alaska Oil & Gas Co~;s. Commission Anch0ra~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS F~..~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River Absent Shublik Absent Top Sadlerochit 9496' 8630' GOC 9510' 8732' Zone 3 9659' 8784' Zone 2 9700' 8823' MAY - ~ ~99~ Alaska Oil & Gas Cons. C0rrlmissi0,~ · .~. Anchorage 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~-~.Y~ ~ /~/~v~~it~le'Dri//inc~EncfineerSuoervisor , _ _ Date / / _ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 · If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached sUpPlemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS9-04A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-20211 PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 18E WO/C RIG: NABORS 18E 02/14/93 ( 1) TD: 9300 PB: 9300 RIG MOVE MOVING RIG. MW: 0.0 NaCl/Br 02/15/93 ( 2) TD: 9300 PB: 9300 02/16/93 (3) TD: 9275 PB: 9275 02/17/93 ( 4) TD: 9275 PB: 9275 02/18/93 (5) TD: 8848 PB: 9275 02/19/93 (6) TD: 8841 PB: 9275 02/20/93 (7) TD: 8664 PB: 8836 02/21/93 (8) TD: 8790 PB: 8836 TEST BOPS MW: 8.5 Seawater MOVE RIG. RIG ACCPTD 2-14-93 @ 13:00 HRS. TAKE ON SW, ADAPT LINES. RU & PULL BPV. RU TO DISPL DIESEL, CIRC HOLE. ND TREE, NU BOPE & TEST. P/U DP. MW: 8.5 Seawater R/U LUB. PULL BPV. RIH W/ TSA SPEAR. PULL TBG. TBG PARTED. POOH. L/D TBG. TEST BOPE. RIH W/ TSA FISHING TOOLS. SPEAR TBG @ 3012'. PULL TBG FREE. POOH. L/D TBG. RIH W/ SPEAR. RIH W/ATLAS CHEM CUTTER MW: 8.5 Seawater RIH, SPEAR & PU DP. CHG DRAW WKS DRUM CLUTCH, RIH. PU DP. SPEAR FISH, POH. RIH, LATCH ONTO FISH & PULL LOOSE. RU WIRELINE & RIH W/CHEM CUTTER. RU WIRELINE TO CHEM CUT MW: 8.5 Seawater RIH W/CHEM CUTTER, POH, RIH W/OVERSHOT ASSY, CBU. WORK OVER FISH, POH W/FISH. RU TO TBG, RECVRD FULL JTS, REMOVE JT & LD. PU SPEAR & RIH. SPEAR FISH, POH. RU WIRELINE FOR CHEM CUT. LOGGING 9-5/8" CSG MW: 8.5 Seawater RU FOR CHEM CUT. RIH, POH, RD. LD TOOLS & CLEAR FLOOR. PU BIT & CSG SCRAPER, RIH. CUT DRLG LINE. RIH, BREAK CIRC, TAG FISH, POH. RU & RIH W/LOG TO CHECK 9-5/8 CSG INTEGRITY. MILLING SECTION MW: 9.8 KCl LOG TO SURF. PU BP & RUN E-LINE. SET @ 8828. POH. PU SECTION MILL & BHA, RIH & TAGGED BP @ 8836. PREP & CHG OVER TO MILL FLUID. SPOT BAL. PILL. CIRC & PULL UP TO 8639. MILLING 9-5/8 CSG." CIRCULATING MW: 9.8 KCl MILLED SECTION, PUMP HI VIS SWEEP. REPAIR MUD PUMP, MILL SECTION. CIRC & COND MUD & DRY JOB. POH, DL DC & MILL. PU SHOE SHOE & RIH. CIRC & COND MUD. WELL : DS9-04A OPERATION: RIG : NABORS 18E PAGE: 2 02/22/93 (9) TD: 8600 PB: 8890 02/23/93 (10) TD: 9011 PB: 8640 AT KOP FO 8640 MW: 9.8 KCl PUMP CMT & SPACER. CIP. POH, PULLED WET, BUT NOT FLOWING. CMT SQEEZE, POH & LD SHOE. FLUSH BOP STACK OF MILL CTTNG. CHG RAMS & TEST BOP. CHG OUT HYDRIL RUBBER & TEST. INSTL WEAR RING, PU BHA & TEST. RIH. DRILLING MW: 9.9 CONTROL DRLG TO KO OUT OF WINDOW. DRLG TO 9011. KC1 02/24/93 (11) TD: 8950 PB: 8640 DRLG 8.5 HOLE MW: 9.9 KC1 DRLG. CIRC & DROP SURV, POH. CHG BHA & RIH. DRLG 8.5 HOLE. 02/25/93 (12) TD: 9210 PB: 9785 POH F/WL LOGS MW: 9.8 KC1 DRLG TO 10106. CBU, WIPER TRIP. CBU, PUMP PILL. POH W/WL LOGS. 02/26/93 (13) TD: 10106 PB: 9785 02/27/93 (14) TD:10106 PB:10106 02/28/93 (15) TD:10106 PB:10106 RIH W/7" LINER MW: 9.8 KC1 RIH W/LOGS & LOG WELL, POH & RD. RIH TO 10106, CBU. WIPER TRIP TO SHOE, CBU. POH, CHG TOP RAMS, POH & LD BHA & MULTI-SHOT SURV. CHG OVER TO SW MW: 8.5 Seawater RIH W/7" LINER. PU CMT HEAD & CIRC TO BTTM. CIRC & COND MUD. PUMP SPACER. TEST CMT LINES, PUMP CMT. BUMP PLUG, CIP. REV CIRC OUT CMT. POH. INSTL RAMS, RIH W/BIT & SCRAPER. RIH, TAG CMT @ 9964. CHG OVER TO SEAWATER. RUN COMP ASSY MW: 8.5 Seawater CIRC CORR INHIB. LDDP, CHG RAMS. RU & RIH W/COMP ASSY. 03/01/93 (16) TD:10.106 PB:10106 03/02/93 (17) TD:10106 PB:10106 CLEANING MUD PITS MW: 8.5 Seawater RUN COMP ASSY, MU LNDG JT & RIH. CHG RAMS, TEST TREE & FLANGE. RU & PULL 2-WAY CHECK. DROP BALL & SET PRK, TEST ANNL. CLEAN MUD TANKS. RELEASE RIG MW: 8.5 Seawater CLEAN MUD TANKS & CELLAR. RELEASE RIG 3-01-93 @ 0700 HRS. SIGNATURE: (drilling superintendent) DATE: A~aska Oil & Gas Cons. Commissio~ " .Anchorage Baker Hughes company 6324/6116 Nielson Way · Anchorage, AK 99518 Phone: (907) 563-3269 / Fax: (907) 563-5865 Phone: (907) 562-2646/Fax: (907) 561-1358 EASTMAN TELECO MWD SURVEY DS 9 - WELL 4A PRUDHOLE BAY Eastman Teleco appreciates the opportunity to provide our services. Please find attached a copy of the directional surveys. REEEJVED k~ AY - 3 1993 Alaska Oil & Gas Cons, Anchorage EASTMAN TELECO MWD Directi ,nal Surveys'.. Company: Prudhoe Bay Drilling Pad/Drill Site: DS 9 Well #: 4A FSE: Craig Tomayer Field: Prudhoe Bay Borough: North Slope State: Alaska Country: USA Drillin~ Co,' Nabors Alaska Drillin..q Ri~l: ]8-E Job #: Minimum Curvature method used for survey calculations. Surveys measured from RKB located 51.7ft above MSL. 1188 Date: Feb 25, 1993 Declination: $0.190° E Proposed Azimuth: 19,98° i i Survey Course Inc° Azt© TVD VS N/S E/W D LS Depth Length ff ff It it °/100' TIE-IN TO MAGNE TIC MULTI-S HOT 8642 35,6 290 7846.86 663,60 N 2571.52 W 8852 210 25,8 304,1 8027.44 -243,80 710,30 N 2667.15 W 5.76 8946 94 23.0 304.8 8113.04 -234.11 732.25 N 2699.18 W 2,99 I I I S/-"~,RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/9-4A 500292021201 NORTH SLOPE COMPUTATION DATE: 3/ 1/93 DATE OF SURVEY: 02/26/93 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER' AK-Et-30009 KELLY BUSHING ELEV. = 54.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST SECT. 8642 7846.86 7792.86 35 35 N 70.00 W .00 663.60N 257t,52W 2652.39 8885 8057.99 8003.99 24 8 N 59.44 W 5.16 713.41N 2681.54W 2772.26 8979 8143.75 8089.75 22 29 N 56.78 W 2.09 732.90N 2712.93W 2808.03 9074 8232.18 8178.18 21 37 N 55.38 W 1.06 752.89N 2742.67W 2842,38 9169 8320.90 8266.90 20 26 N 55.66 W 1.26 772.21N 2770.79W 2874.99 9262 8408.60 8354.60 19 12 N 55.36 W 1.32 790.11N 2796.85W 2905.21 9356 8497.06 8443,06 18 49 N 55.05 W .43 807.52N 2821.89W 2934.30 9450 8585,96 8531,96 18 18 N 54.57 W .57 824.73N 2846.31W 2962.74 9545 8676.35 8622.35 18 28 N 54.63 W 17 842.15N 2870.82W 2991.32 9638 8764.52 8710.52 19 3 N 54.65 W .62 859,49N 2895.25W 3019.82 9730 8851.85 8797.85 19 8 N 54.98 W .14 876.91N 2919.97W 3048.61 9824 8940.48 8886.48 19 1 N 54.77 W .14 894.55N 2945.04W 3077.81 9917 9028.49 8974.49 19 1 N 55.37 W .21 911.93N 2969.93W 3106.74 10010 9116,14 9062,14 18 38 N 55.68 W .43 928.85N 2994,57W 3135.31 10041 9145.99 9091.99 18 46 N 55.67 W .42 934.55N 3002.91W 3144.97 10082 9184.84 9130.84 18 30 N 55.17 W .76 941.98N 3013.70W 3157.49 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3157.49 FEET AT NORTH 72 DEG. 38 MIN. WEST AT MD = 10082 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 287.36 DEG. RECEIVED MAY - 199,l ^)aska Oil .& Gas Oons. Commission ;Anchorage Sr"'"'~,RY-SUN DRILLING SERVICES ~"'"~" ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/9-4A 500292021201 NORTH SLOPE COMPUTATION DATE: 3/ 1/93 DATE OF SURVEY: 02/26/93 JOB NUMBER: AK-EI-30009 KELLY BUSHING ELEV. = 54.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8642 7846,86 7792.86 663.60 N 2571.52 W 795.14 9642 8767.77 8713.77 860.14 N 2896.17 W 874.23 79.09 10082 9184,84 9130.84 941.98 N 3013.70 W 898,14 23.91 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. 'RY-SUN DRTLLTNG SERVZCES ANCHORAGE ALASKA PAGE PRUDHOE BAY PBU/9-4A 500292021201 NORTH SLOPE CONPUTATZON DRZLLZNG DATE' 3/ 1/93 DATE OF SURVEY' 02/26/93 JOB NUMBER' AK-EZ-30009 KELLY BUSHZNG ELEV. = 54.00 OPERATOR' ARCO ALASKA ZNC FT, ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL NEASD VERTZCAL VERTZCAL RECTANGULAR COORDZNATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTZCAL DZFFERENCE CORRECTZON 8642 7846.86 7792.86 663.60 N 2571.52 W 795.14 8650 7854.00 7800.00 665.36 N 2576.47 W 796.86 1.72 8769 7954.00 7900.00 689.31 N 2634.81 W 815.14 18.28 8881 8054.00 8000.00 712.49 N 2679.98 W 827.34 12.20 8990 8154,00 8100,00 735,23 N 2716,48 W 836,21 8,87 9098 8254,00 8200,00 757,81 N 2749,79 W 844.00 7.80 9204 8354,00 8300,00 779,16 N 2780,96 W 850,91 6,90 9310 8454,00 8400,00 799,09 N 2809,83 W 856.89 5,98 9416 8554,00 8500,00 818.60 N 2837,68 W 862,51 5.62 9521 8654,00 8600,00 837,82 N 2864,72 W 867,87 5,36 9627 8754,00 870.0,00 857,39 N 2892,29 W 873,43 5,56 9733 885'4,00 8800,00 877,34 N 2920,58 W 879,25 5,82 9839 8954.00 8900,00 897,24 N 2948,85 W 885,06 5,81 9944 9054,00 9000,00 916,93 N 2977,17 W 890,84 5,78 10050 9154,00 9100,00 936,08 N 3005,16 W 896.44 5,60 10082 9183,91 9129,91 941.80 N 3013,45 W 898,09 1,65 THE CALCULATZON PROCEDURES USE A LZNEAR ZNTERPOLATZON BETWEEN THE NEAREST 20 FOOT ND (FROM MZNZNUN CURVATURE) POZNTS ARCO Alaska, Inc. P. O .Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINALS 4- 29 ~ ~-~ 1~-3-26-93 % (d"-'~ -~ 4-33 3-25-93 5-11 '77-~O 3-29-93 ~} ~-'~ 6-3 4-5-93 6-9 '~--7~ 4-5-93 ~ 6-18 3-30-93 6-22 ~~ 3-26-93 ~~ ~:ll 4-3 3-22-93 -93 '--9-351 4-1-93 ~ -~ ~-~3A 4-0-93 ~2-~ ~U~ 3-3~-03 ~~d3-~o 3-~-93 14-15 ~l~q 3-30-93 4-22A 4-2-93 4-22A 4-2-93 16-30 ~-9~ 3-21-93 ~7-20 4-3-93 ~3~0~8-26 3-23-93 ~8-26 3'24-93 18-27 ~}8-27 3-23-03 3-24-03 Leak Detect Run 1. 1".5"~25'* Sch Production Run 1. ~' Sch Production Run 1. ~' Sch Peri Record Run 1, ~' Sch Production Run 1. 5" Sch Peri Record Run 1. ~' Sch lnJ Profile Run I, ~' Sch Peri Record Run 1, 5" Sch Production Run 1, [~' Sch Tubing Puncher Run 1, ~' Sch CNL Run 1, ~' Sch Static Pressure Run 1. ~' Sch Press/Temp/Spin Run 1, 2'&5' Sch Static Pressure' Run 1, [~' Sch Production/Gas Entry Run 1, ~' Sch Peri Record Run 1, I~' Sch l~ak Detect Run 1, 1"&5" Sch Production Run 1, ~' Sch Peri Record Run 1. ~' Sch Peri Record Run 1, ~' Sch Static Pressure Run 1, [~' Sch Peri Record Run 1, [~' Sch Production Run 1, ~' Sch Peri Record Run 1, ~' Sch Production Run 1,/~' Sch PITS Run 1, ti~' . Sch Peri Record Run 1, ~' ~ch Peri Record Run 1, I~' Sch Peri Record Run 1, ~' Sch Peri Record Run 1, [~' Sch Static Pressure Run 1. ~' Sch GR/CCL Run 1, ~' 8ch Static Pressure Run 1, [~' Sch GR/CCL Run 1, ~' Sch Have i Nice Dayl ' -% ~ ~.. ~ ~' -~ APPROVED_~/~yl/ ATO-1529S°nyaWallace f% v~~ ~.~ # CHAPM '.% # EXX # STAT Or L SKA ARCO Alaska, Inc. P.O.Box 100360 · Anchorage, Alaska 99510 DATE: 3-17-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS 2-27-93 2-25-93 29-93 2-19-93 11 - 14-92 DLL/MLL/AC/GR . BCS/DLL/CNTH/GR DLL/SDN/Cm~H/GR ~L/~LL/AC/GR DPR/Den Poro/GR Run I Job~5903 Run1 Job~93090 Run I Job~93057 Run I Job~5898 Run 6 Job# 1149 PleaseRECEivEDsign andByreturn~~_~__~the~ attached copy ap receipt of data. Have A Nice Dayl Sonya Wallace ATO-1529 APPROVED__~ Trans# 9303.~~- .... Atlas 8ch 8ch Atlas Teleco CENTRAL FILES (CH) CHEVRON D&M # BO~ OCAN,~S (OH/~CT) # EXXON MARATHON MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO RECEIVED ~aska 011 & GaS Cons. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-2-93 REFERENCE: ARCO OPEN HOLE FINALS 2-25-93 DLL (Simultaneous) Run 1, 2"&5" Sch 2-25-93 BHC]Sc.-- Run 1, 2"&$" Sch 2-25-93 CNL Run l, 2"&5" Sch 2-9-93 DLL/MSFL/GR Color Run 1, 2"&5" Sch 2-9-93 LD/GR/CNL (Raw) Color Run 1, 2"&5" Sch 2-9-93 LD/GR/CNL (Poro) Color Run 1, 2"&5" Sch 1-18-93 DLL/MSFL/GR Color Run 1, 2"&5" Sch 1-18-93 LD/Neutron (Raw) Color Run 1, 2"&5" Sch 1-18-93 LD/Neutron (Poro) Color Run 1, 2"&5" Sch 2-19-93 DLL/MLL/GR Run 1, 2"&5" Atlas 2-19-93 BHCA/GR Run 1, 2"&5" Atlas 1/26-2/12/93 DGR/EWR/FXE 1/26-2/12/93 DGR/CNP/DSFD/CAL 1/26-2/12/93 DGR/Near-Far Ave ~' Runs 4-16, 2"&S"MD Sperry Runs 4-16, 2"&S"MD Sperry Runs 4-16, 2"&S"MD Sperry ~"- 18.26 1/26-2/12/93 DGR/EWR/FXE Runs 4-16, 2"&S"TVD Sperry 6---'-'~ '1/26-2/12/93 DGR/CNP/DSFD/CAL Runs 4-16, 2"&$"TVD Sperry ~"_~ 1/26-2/12/93 DGR/Near-Far Ave .~ Runs 4-16, 2"&S"TVD Sperry Please sign and return ~.e~ttac~e}/copy as receipt of ~ RECEIVED ~~ rove A Nice ~ '~ / ' --- .n~ W~ce ~ APPROVED ~ ~~ON ~%~ ~ ~ ~ PB ~LL ~S ~D&M ~~ R&D ~ C~T C~~ ~ ~ BPX ~ ~ON ~ ~ STA~ OF MARATHON # TEXACO ,. # MOBIL MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David Johnston Commission~ thru: Blair E Wondzell Sr Petr Engineer from: Bobby Foster Petr Inspector date: file: subject: March 3, 1993 BOBO2212. DOC BOP Test-Nabors 18E ARCO PBU D.S. 9-4A Prudhoe Bay Field PTD 93-24 Sunday, February 21, 1993: The BOPE Test began at 3:30 p.m. and was concluded at 9:00 p.m. There were two failures. A value leaked in the choke manifold and the annular preventer element leaked. The value was repaired and the element replaced. Both were retested and passed. SUMMARY: I witnessed the BOPE Test on Nabors Rig 18-E which had two failures, both were corrected before I left the rig. Test time 5 1/2 hours, 2 failures. Attachment STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: grig:, .~ /' Workover: _ :,._ _ DATE: ~---<--/- /,:./~ grig Contractor: ~"//-~~ _ Rig No.//~_>~- PTD ~--/~- ~ ~./Z'~ Rig~h.# /.,_:, ..%~ --- Z_Z/~- O,~-~ Operator: ' ;,'./.~_.~ - Pr~Z'0. ~ Re,. .27.~*~.,~,~ ' ,' . we, Name:. '~. 5' ~- q A'.-.~, Rep.-., ~/,;~/-J/~.~, / ~ ZJ~~ Casing Size: ~/,g~ Set@~q~///OLEeet Location: Sec. V~ T. JO/?/R. ~erd. IJFk'l Test: Initial Weekly ~ Other Test Location Gen · Housekeeping: :Reserve Pit (Gen) MISC. INSPECTIONS: BOP STACK: Qua. Ann. Preventer Pipe Rams Blind Rams Chk/Ln Valves HCR Valves -.. Kill Line Valves ~ Check Valve ~1/? MUD SYSTEM: Light Tdp Tank Pit Level Indicators Flow Indicator Gas Detectors Well Sign ~''~' Drl. Rig ~ Test Pressure P/F Alarm FLOOR SAFETY VALVES: Quan. Pressure P_/F Upper Kelly Lower Kelly / Ball Type / Inside BOP CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure ---, minutes System Pressure Attained ,.-~ minutes ~ :~. ,. Blind Switch Covers: Master: ~ Remote: ,----- Nitgn. Btl's: zg/ ~ :~e, ~ (~> ,~/Cr~ Psig. Equipment shall be mad'~'within ~a~s. Notify the Inspector on duty and follo~wit~ Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your Call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 Distribution: odg-Well File c - Oper./Rig c- Database ./,c.,- Trip Rpt File Inspector STATE WITNESS REQUIRED? YES NO ~/ 24 HOUR NOTICE GIVEN YES NO v// Waived By: Witnessed _ . , _ , ~ FI-021L.XLT Rev. 1/93 ALASKA OIL AND GAS CONSERVATION COMMISSION '::" WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGIE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 February 8, 1993 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re .' Prudhoe Bay Unit DS 9-4A ARCO Alaska, Inc. Permit No. 93-24 Sur. Loc. 405'NSL, 747'WEL, Sec. 2, TiON, R15E, UM Btmnhole Loc. 1473'NSL, 3623'WEL, Sec. 2, T10N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. ~ ) Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~) printed on recycled paper b y ~. ii'). f --'~, STATE OF ALASKA ALASKA,..- AND GAS CONSERVATION CO:- .SSION PERMIT TO DRILL 20 AAC 25.OO5 la. Type of work Drill I-! Redrill ElJlb. Type of we'll.' Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen Cfi Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO A/aska, /nc. KBE = 54'fe et Prudhoe Bay Fie/d/Prudhoe 3. Address ~6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. A/aska 99519-6612 ADL 28327 4.. Location of well at surfaCe 7. Unit or property Name 11. Type Bond(me 2o AAC 25.025) 405' NSL, 747' WEL, SEC. 2, TIOIV, R15E Prudhoe Bay Unit At top of produCtive interval 8, Well number Number 1300' NSL, 1700' EWL, SEC. 2, TION, R15E DS 9-4A U-630610 At t/~,~a~, depth 97Approximate spud date Amount 1473' E4W., 3623' WEL, SEC. 2, TION, R15E 2/15/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 28324-1473'feet No Close Approach feet 2560 10119' MD/9212' TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) iKickoff depth o68ofeet Maximum hole angle 3s. 58 o Maximum surface 3330Pstg At total depth (TVD) 880~)'/4390pslg 18. Casing program Setting Depth s~ze Specifications ..Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80/ TDS/Fox 1589' 8530' 7756' 10119' 9212' 317 sx Class "G" , 13CR80 ~,, 'i9. To be completed for Redrill, Re-entry, and Deepen Operations. ~i~ Present well condition summary Total depth: measured 10250 feet Plugs (measured) true vertical 9153feet Effective depth: measured 10147feet Junk (measured) Aiask~ 0i.i ~ ,?,~o - true vertical 9o71 feet Casing Length Size Cemented . . Measured depth True Vertical depth Structural Conductor 76' 20" 300 sx AS 76' 76' Surface 2701' 13-3/8" 6400 sx AS 2701' 2701' Intermediate Production 10233' 9-5/8" 1000 sx "G"/ 10233' 9139' Liner 300 sx AS Perforation' depth' measured 9786'-9811' true vertical 8780'-8800' 2~J. Attachments Filing fee 171 Property plat [] BOP'Sketch [] Diverter Sketch [] Drilling program [] iDrillin~ fluid program [] Time vs depth pict [] Refraction analysis l'-! Seabed reportl-I 20 AAC 25.050 requirementsr-I 21 I hereby certif,~][¢ t~i · fjy the foregoing is true and correct to the best of my knowledge Si~ned , Title Drilling Engineer Supervisor Date"Z · Commission Use Only P'ermit Number IAPI number IAppro~al date ISee. cover letter ~-.¢_y js0-o~e--::z.o;z./~-<:,/, ,_~ _ ~-~,.~ Ifor other requirements Conditions of approval Samples required [] Yes j~No Mud Icg required []Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] NO Required work' e M; 1"I3M; 1~5M; F-ll0M; i-115M; Othe~"~ ,~...~ ~ 1 ) -- by order of ~Appro . Commissioner me commission Datez.,//~./~,~ Form 10-401 Rev =1-2:1 "~"~- '"---- Submit WELL: AP! No.: LOCATION: PRELIMINARY WELL INFORMATION DS 9-4 A Redrill PBU EOA 50-029-20212 (on the original DS9-4 well) Surface: 405' FSL, 747' FEL, Sec. 2, T10N, R15E Target: 1300' FSL, 1700' FWL, Sec. 2, T10N, R15E @ 8595' ss BHL: 1473' FNL, 3623' FEL, Sec. 02, T10N, R15E @ 9158' ss Original KBE: 54' AMSL ESTIMATED START: 9 Feburary, 1993 OPR. DAYS TO COMPLETE: 13 CONTRACTOR: Nabors Rig #18E DIRECTIONAL: Kickoff at = 8680' MD with a 4°/100' constant curvature drop / turn from initial 35.58° to final 17.66© inclination and from initial N 70 W to final N 14.25° azimuth. Max angle: 35.58° (at KOP). No close approaches. WELLBORE: ~ TVD(BKB) MD(BKB) Mud Wt. KOP 7878' 8680' 9.4- 9.6 END OF CURVE 8533' 9406' 9.4- 9.6 TOP SADLEROCHIT (TARGET) 8649' 9528' 9.4- 9.6 HOT 9053' 9952' 9.4- 9.6 OOWC 9084' 9984' 9.4- 9.6 BASE S^DLEROCHIT 9117' 10019' 9.4 - 9.6 TOTAL DEPTH 9212' 10119' 9.4 - 9.6 LOGGING PROGRAM: 9 5/8" Casing: 8-1/2" Hole: Vertilog log for corrosion inspection Schlumberger GR/DIL/CNL/BHCS by electric line MUD ..... PROGRA.M...; The milling / drilling fluid program will consist of a 9.7 ppg Biozan polymer / KCI water based mud in the 8-1/2" hole. DEPTH DENSITY PV YP INT 10 MIN FL (TVD) .......... (PPG) (CP) (#/FT) GEL GEL cc/30min KOP' 9.4 10 10 5 7 8 to to to to to to to TD' 9.6 16 18 10 15 5 OIL SOLIDS MUD (%1 (%1 TYPE '0' 5 Water to to Base 0 7 Mud MUD,,,WEIGHT CALCULATIONS / WELL CONTROL: Est. Pore Press. Sadlerochit: Est. BHT (F°)· 3600 psi/8800' ss TVD. 191 °F / 8800' ss TVD. Mud Wt.' 8-1/2" Hole = 9.7 ppg. Overbalance Top Sadlerochit' 793 psi Well control equipment consisting of 5000 psi pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3400 psi based upon a gas column to surface from 8800' TVDss with no oil column. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: CASING DEPTH BURST COLLAPSE TENSILE 7" 26# L-80 TDS / 13Cr-80 Fox ,,,8530' - 10119' MD 7240 psi 5410 psi 604 klbs ,,.CEMENT CALCULATIONS: 7" LINER' Measured Depth: 8530'MD (Hanger)- 10119'MD (Shoe) Basis: 40% open hole excess, 40' shoe joint, 150' liner lap and 200' excess abOve liner with DP. Total Cement Vol: 367.7 cuft or 317 sxs of Class G blend @ 1.16 Cu ft/Sk TUBING DETAILS: 7"X 5-]/2"× 4-1/2" 12.6# 13CR-80 Fox (Surface - 9478' MD) 9-4 A AFE INFORMATION ~,EXPENSE) Ob!ective' The primary objective the 9-4 A redrill is to increase the life expectancy of the well due to extensive liner and tubing corrective and access intervals below the Victor currently covered with cement. A new hole will be drilled starting from deep within the existing wellbore to a location about 250' east of the current BHL. The 9-4 A redrill will be completed with 7" 13-Chrome production liner and 7" X 5-1/2" X 4-1/2" 13-Chrome tubing. Well 9-4 is currently producing at 2500 BOPD with 75% water cut and 5400 GOR. The well's liner and tubing are severely corroded. Scope: The scope of the 9-4 A redrill is as follows: Plug and abandon the original perforations with CTU and pull the existing 7" X 5-1/2" X 4-1/2" tubing completion. Run Vertilog Icg to inspect 9 5/8" casing corrosion. If 9-5/8" casing fails the inspection, drill out the cement plugs, mill the packer, and rerun another tubing string to return the well to production. If 9 5/8" casing passes the inspection, then continue the sidetrack operation, mill a 60' section in the 9-5/8" casing starting at 8,675'MD. Lay a cement plug across the section, kickoff and drill a new 8-1/2" hole to a target about 250' east of the original wellbore. Obtain E-line logs. Run and cement a 7" 29# L-80 / 13CR liner. Clean out to the landing collar. Recomplete with 7" X 5-1/2" X 4- 1/2" 13 Cr tubing and prepare well for post-rig perforation. Remedial work for annular communication is not within the scope of this AFE. Timina: This project is presently scheduled for Nabors Rig 18E upon drilling activity on DS 3 in mid February, 1993. The redrill should take approximately 13 days. A summary of time break down is listed below: Well to Well (around the pit) Rig Move 1 day Pull Tubing & Run USIT log 2 days Mill 60' Section & Set Cement Plug 2 days Kick Off from Section 1 day Drill 8 1/2" Hole & Run E-logs 3 days Run Completion 4 days Total Days 13 days DS 9-4 A REDRII,.I., R.EDR!LL_. SUMMARY. .PROCEDURE: 1.Pre-rig work: Kill well. . 3~ 4. 5. 6. 7. 8. , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Lay cement plug across perforations to at least 100' above top perforation. Cut 4-1/2" tubing just above the packer PBR. Freeze protect and set a BPV. Move in drilling rig. Test 9-5/8" intermediate casing pack-off if not done during pre-rig work. Pull 7" BPV. Circulate freeze protection cap from well. Set a two-way check valve and remove the production tree. Install BOP's and test to 5000 psi. Remove the two-way check valve. Pull and lay down the 7" X 5-1/2" X 4-1/2" tubing. Run 9-5/8" casing corrosion log (Schlumberger USIT). Set a drillable bridge plug in the 9-5/8" casing at 8880' MD or 200' MD below the top of the proposed section. Spot a 17 ppg pill on bottom and cut a 60' section in the 9-5/8" casing from about 8675' to 8735' MD. Spot a balanced cement kick-off plug (170 cubic feet minimum) from 100' below the base of the section to 200' above the top of the section. Replace the 9-5/8" casing pack-off as needed. Run in with an 8-1/2" steerable drilling assembly and dress the cement to 5' below the section top. Kickoff and directionally drill to align well with target. Follow with an 8-1/2" packed hole assembly and drill to the target at 150' MD below the base of lvishak at 9063' ss (see directional plan for more details). Run wireline conveyed open hole (GR/DIL/CNL/BHCS)logs. If a DLL is used in place of the DIL, a micro-resistivity log will be required. Run a 7" 29 # L-80 / 13Cr liner assembly to bottom in the 8-1/2" hole. Space the liner hanger and top isolation packer about 150' up inside the 9-5/8" casing. Cement the liner in place with the total cement volume based upon 40 % open- hole enlargement plus the shoe volume, lap volume and 200' excess on top of the liner with drillpipe in the hole. Re-test the 9-5/8" casing pack-off and replace as needed. Clean out the liner to the landing collar and test to 3500 psi. Displace well to filtered and inhibited seawater. Run a 7"X 5-1/2" X 4-1/2" 13CR completion string and 7" packer. Space out, land tubing hanger and set packer. The packer should be set at about xxxx' ss with the tubing tail above any future objective.. Test tubing to 4000 psi. Test tubing by casing annulus to 3500 psi. Set two-way check valve. Remove BOP's. Install and test the production tree to 5000 psi with diesel. Pull the two-way check valve. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release workover rig. Complete appropriate documentation and hand-over to Production for-' perforation. Anticipated BHP: 7.9 ppg equiv. Drilling Fluid: 9.5 ppg Workover Fluid: 8.5 ppg. NABORS RIG NO. 18E MUD SOLIDS CONTROL EQUIPMENT 2 - Continental Emsco Fl000 Mud Pumps 2 - Derrick FIoLine Cleaner Shale Shakers 1 - Derrick Mud Cleaner 1 - Swaco Centrifuge 1 - DRECOGas Buster 2 - Pioneer Sidewinder Mud Hopper 2 - 5 HP Flash Mixer Agitator 3 - Abcor 10 HP Agitators 1 - 50 bbl. Trip Tank 1 - Recording frilling fluid pit level indicator with both visual and audio warning devices at driller's console. 1 - Drilling fluid flow sensor with readout at driller's console IU GREAT LAND DIRECTIONAL DRILLING, INC. Corporate Office i111 East aO~h Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING well ......... : DS 9-04A (P3)~ Field ........ : PRUDHOE BAY DRILL SITE 9 ComDutation..: MINIMUM CURVATURE Units ........ = ~EET Prepared ..... ~ 01/18/93 Section at...: KB elevation.: 54'.00. ft LEGAL DESCRIPTION Surface ...... : 404 FSL 747 FEL S02 T10N R15E UM Tie-An ....... : 1080 FSL 3340 FEL s02 T10N R15E UM Target ....... : 1299 FSL 3B79 FEL S02 T10N 815~ UM BHL .......... : 1473 PSL 3623 FEL S02 T10N R15E UM X ASP ZONE 4 Y 717662.20 5941851.48 715050.75 5942453.22 714805.00 5942665.~0 714755.89 5942837.52 PROPOSED WELL PROFILE STATION IDENTIFICATION TIE-IN K-5 END OF CURVE TARGET TOP SADLEROCHIT HEAVY OIL TAR OOWC BASE SADLEROCHIT TD MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-$ DIST I! 680 35.58 700 34.90 800 31.56 8808 31.29 900 28.37 9000 9100 9200 9300 9400. 7878 7824 1294 7894 7840 1301 7978 7924 1333 7985 7931 1336 8064 8010 1366 25.38 8154 8100 1399 22.70 8245 8191 1432 20.42 8338 8284 1464 18.69 8432 8378 1495 17.70 8527 8473 1526 ~406 9528 9528 9952 9984 17.66 8~33 8479 1528 17.66 8649 8595 1565 17.66 8649 8595 1565 17.66 9053 8999 1694 17.66 9084 9030 1703 10019 10119 17.66 9117 9063 1714 17.66 9212 9158 1744 DIRECTION REL-COORDINATE$ DL/ AZIMUTH FROM-WELLHEAD 100 290,00 676 N 2593 W <TIE 290.72 681N 2604 W 4.0 294.74 702 N 2655 W 4.0 295.15 703 N 2659 W 4.1 299.58 724 N 2699 W 4.0 305.49 748 N 2737 W 4.0 312.77 774 N 2769 W 4.0 321.74 801 N 2794 W 4.0 332.55 829 N 2812 W 4.0 344.98 858 N 28~3 W 4.0 345.75 859 N 2524 W 4.0 34~.75 895 N 2833 W 0.0 345.75 895 N 2833 W 0.0 345.75 1020 N 28~4 W 0.0 345.75 1029 N ~67 W 0.0 345.75 1040 N 2869 W 0.0 345.7~ 1069 N 2~77 W 0.0 (GLDI) (c)92 osgO~.A 81.40 4:10 PM 2) ................ PI:::IODHO'E ...... 8'A'Y .... O'-Pi":Z'L-Ei'IqG ....................... i Il i i i i ii i ii ii. i i - - C) T~6ET 95~8 8649 2~5 17.66 D) TD 10119 9212 1744 17,66 Section Bt: 345.75 ~"~":~: TVD Scale · I inch = 1200 feet ....... Der Scale · ~ inch : 120~:~:~e,-~ <KB> o '1'1 'l' "~ 600 ~ ', ~ I ~ ~ , ~ ~, ~ ~ ' ' ~ ~ l , , i [ ;~ GPeat Land DJpectiona] Drilling ~2oo ~ ' , ' J ~ ~_L_~ ........ ~ ..... ~.~_,_ i , ,~ ~ ]...'J."~'~ t'-~ {, t/ ~ , , iI] t ~800 2400 .~-~,: I .:i ' i,, -T'i '7, ~ ~'; ...... , , l' [ , , ~' I,'' .... i' ;i ~'~ , t , .~'-~ "!.. ;] , ~ ~i' ltl' ~ j' LL.L .::~1 r'' .... _~ I ........ I I ..... lt'~[I i t I , , I I ] J .... t : 1 i ....... ............. ;'' ' , i t i I t" r'" ~ i : ~, . I : I :, i ,T i :: I i~_L~ .l.i. Jill I I j i ~ I ! J i liJ IfILL i il j l , , :: , Il, : ,i ; 4200 !': iii , ...... : ~: , :~ I 4~00 ~i :t , : , , , : ,i ...... , , I I , I : : . . ' i , ' I I I ! I I' I f' r-T- I j l ~ Il i ...... f-I-':[~ J i 'il ti [ ':l J t J ' "J"-[-I .... I'", :_L ~000- i i i i"~ ....... ~ ; I I I : ~ ~..] i i I 'f ! ] i i ' ' ' ..... I I I I., ~i l ..... ..[ ...i ' ll !Il I'~ ; tli !)l i [~ :I. '- !:1 ti : t t ! Ii ] r-F' .l ,I '- -I-- - : -4~..~..:.4~-i--- ~ii , ', ~ ' 7~oo17].::i__~ I ~ I !' ~ ~ ~ ',,~.L~ ~ ~ ., ~ rq k~ ;, , ,,~, i'---i , ,,,.4_ ill, 1! i,,: ,~ , ~ ~-,, ,.,, ,..:.,,,: , , ::, , , · i ~ : I : : ~ i "'~ r : ~' I :~ ~ I i t i ~ : i : , .... ill' 'l'" 8400 I . : [ I t ~ ~q~ ~i~ F .... ~ ........ ' ' . . t I--F~ .'i I~N ; ; k.: ! ',', i I I I l'l" I~ i . .!. 111 Ii f IiT'" : : ¢ iF' :'i-'* 'j """ ' tj: ii ':" ""' 9600 ;I', ' i i., ~iil I I ; i I..irl-' !I.i i~li.._~l!(' I~ ! iii I',,~, '~l! ~l!l 0 600 l~OO lBO0 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 Sect~0n Depantune , m mm f~om r,e~,~ m4 .~/~ ~. ,, ~, ~t . I mm mm mmmmmm JAN-18-1993 16:16 TO ~BD bNUIN~bN~ ~.~4 FROM GREAT LAND DIR DRILLING . ~'OHOL BAY OR iLL i~'kiG .........."- ~ (i:3) TIE- TvD Scale' i ~nch = 200 feet Oep Scale.' ] inch = 200 feet .-~:' . Great Land OlPectJona] OcjJJjng ~000 ! lO0 1200 1300 1400 i500 i600 i700 l/lO0 1900 2000 2t00 2200 2300 2400 Section Oeparture 16L~D to, J92 05904A B'~.4O 4: S~ FN 2) PRUDHOE BAy 425D 400,1) 3750 (Gl. BI) [,~:;Itllt D';904A [lJ .40 4_ ',2 PN 2J Marker Id~mti f 1cation Nb N/S E/l~ A) TIE-IN B6~ 676 N ~93 B) Ef~ OF CURVE 9406 859 N 2824 O) lD tOllg ~08g ~ 2B77 3500 3~0 30~0 DRiLLinGII 2750 2500 2250 200,0 1500 1259 lO~B 750 500 mill lin __ ~reat Land Directional DriYling BS 9-04A (P3) PLAN VIE~ CLoSUHE' ....: 306§ feet at Azimuth 290.38 DECLINATION.' 30.1g E SCALE. · ! ~nch = 500 feet DRAWN. ' 01/18/93 250 0 25D <- WES! ' EAST -> · ,, ___ i iiiJl PRUDHOE BAY DRILLING .==.--~.,~ CLOSURE ' 3069 feet at DECLINATION.' 30.19 E SCALE ' ~ }nch= ~00 fe~t DRA~ ' 01/18/93 Jill .., .., (E~=~_OE) (¢J9~ J)S~4A B~.4~ .t: '.4 ¢f4 2J TOTFaL P. 06 SUF..::',~C:F__ )LED I V F__RTF_,,'~,.SY STEM ...... Two lines venting go deg. apart in directions that ensure safe down wind venting, and ex- tending to a point at least 100' Item any potenti;i""" source o! Ignition. ~.,/.10' Full Opening Valves J ~ .... 35' or as required L , . Dresser Sleeve o .; ., 10' Diverter Line I All pipe connections 150,f. ANSI Flanges or welded c=nnections and secured to prevent movemenL. 2. Manual 10' full opening valves mechanically connected to ensure that one valve is fail-sate open at all limes. All tums are g0 deg. and t~rgeted. 10' Full opening ball valve w/Hydraulic Actuator 20' Diverter Spool wi 1 O' Side MEM 1/3/90 .o . NABORS 18 E 13 5/8" 5,000 psi Stack 1.50 4.75 4.73 3.98 3.66 I 1.49 2.37 .,~ 2.21 0.55 GROUND LEVEL RKB 1 , KR T(') RF RI(~ FI ('-)(")R HYDRIL PIPE RAM BLIND RAM 11.41 15.66 17.93 MUD CROSS PIPE RAM I CROSS I ~ TBG I I ~x~ASE FLy 22.96 26.45 28.25 3O.25 MI~A,'G ~1/.. L TAM/C. ., ~~ [,, , ~ pIT ~VATF_,R 2~0 ~ c V~I..UHe. rAAIK lDO ~6L. I,~LUHE TAbU g ,,'MUD D~STRI~LITION D~TT leo BBL. TYF~. / /' [' , ,/ - Choke Manifold - Poor Boy Degasser · - Brandt VacuumvType Degasser - Brandt Dual Tandem Shale Shaker - Pioneer Mud Cleaners - Pioneer MKI Centrifuge 1 - RecOrding drilling fluid, pit'level indicator with both visual and audio warning de~ices at driller's console 1 - Trip Tank (75 BBL.) 1 - Drilling fluid flow sensor with readout at driller's console 11 - 5 Hp AgitatOrs 9-4ACMT.XLS State: Well: Fie~d: State Permit Ptudhoe Ba..~, $3-24 E ncneef: Work Sheet Date: M. Mk'~def Cement Volume Calculations- 2/5/93 Casing Type Casing Size -Inche~ Casing Length - Feet Hoie Diameter -Inches Cement- Sacks Cement-Yield Cement- Cubic t't Cement-Cubic ft Cement- Sack~ ~2 Cement- Yield ~2 C~enI - Cubic ~ Cement - Cubic ti ~2 Cement - Sacks ~3 Cemenl - Yietd ~3 Cement - Cubic it ~3 CemenI - Cubic II ~3 Cemenl - Cubic ~ / Vol Cement- Fill Facto~ Conductor 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 O. OOO 0.000 0.000 ~DIVIO~ Surface 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ~DIV/O! Liner 7.000 1,589.000 8.500 317. 000 1.180 367.720 367.720 0.000 0.000 0.000 0.000 387.720 1.825 Casing Type Casing Size -Inches Casing Depth - Feet Hole Diamete~-Inches Cement- Sacks 1:11 Cement- Yield ~I1 Cement- Cubic ItI:I1 Cement- Cubic it~I1 Cement- Sacks ~t2 Cement- 'Yield 1:I2 Cement- Cubic ft1~2 Cement- Cubic tt Cement- Sacks Cement- Yield Cement- Cubic ~t~3 Cement-Cubic fi Cement- Cubic tt /Vol Cement-Interval ft Top ol~ Cement- Feet Intermediate ~I1 0.000 O. O00 0.000 0.00 0.00 O. O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O. O0 0.00 t:IDIV/O! ~DIV/O! Intermediate ~I2 0.000 0.000 0.000 0.00 0.00 O. O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~IDIV/O! ~DIV/O! Production 0.000 0.000 0.000 O. OO 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 I~DIV?O! State: Alaska Borough: Well: Dsg-4A Field: Prudhoe Bay St. Perm ;9~24 Date 2/5/93 Engr: M. Minder DSg-4A.XLS IA 2A SA 4A 5A 6A 7A 8A 9A 10A Casing Interval Interval Size Etoffom Top Length 7 9212 7756 1589 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Lbs Grade Thread Lbs 26 13CR-80 TDSIFOX 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ,0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 IB 2B 3B 4B 5B 6B 7B 8B 9B 10B Mud Hydraulic Collapse Wieght Gradient Gradient ppg psi/ft psi/ft 9.7 0.504 0.404 0.0 0.000 -0.100 0.0 0.000 -0.100 0,0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure psi 3:930 0 0 0 0 0 0 0 0 0 Yield psi BDF 7240 2.2 0 #DIV/0! 0 #DIVI0! 0 #DIVI0! 0 #DR/10! 0 #DIV/O! 0 #DR//0! 0 #DIVI0! 0 #DIV/0! 0 #DIV/0! 1C 2C 3C 4C 5C 6C 7C 8C 9C 10C Tension Strength K/Lbs 41 .~14 0 0 0 0 0 0 0 0 0 K/Lbs TDF 604 1 0 #DIV/0! 0 #DIViOI. 0 #DIV~! 0 CDIVi0i 0 ~D~ 0 ~DIVI0i 0 ~D~I 0 ~D~ 0 ~DIV~ Collapse Collapse Pr-Bot--Psi 3725 0 0 0 0 0 0 0 0 0 Resist. CDF 5410 1.452 0 #DR/10! 0 #DNtO! 0 #DIVI0! 0 #DIV/0! 0 #DR/10! 0 #DR//0! 0 #DIV/O! 0 #DIVi0! 0 #D!V!0! ITEM (1) Fee (2) Loc *:: CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE {~ thru 8] -' '- [10 g 13] [14 thru 22] [23 thru 28] Company Lease g Well YES NO 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... ~ .. 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ -~ '' e 10. 11. 12. 13. 14. 15. Does operator have a bond in force ................................... ~ Is a conservation order needed ....................................... ~ Is administrative approval needed .................................... . /~ Is lease nLrnber appropriate .......................................... ~ Does well have a unique name $ n~rnber ................................ ~_ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ ,,, Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... ~ Will all casing give adequate safety in collapse, tension, and burst. ~ Is well to be kicked off from an existing wellbore ................... ~ Is old wellbore abandonment procedure included on 10-403 ............. ~ .. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ ~ Is drilling fluid program schematic g list of equipment adequate ..... ~ ... Are necessary diagrams & descriptions of ~'~--.~-7_]_~BOPE attached .... ~¢= ...... Does BOPE have sufficient pressure rating -- test to ~'OOopsig ..... ~ Does choke manifold comply w/AP! RP-53 (May 8~) ...................... _ Is presence of H2S gas probable ...................................... .. ~ REMARKS 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (6) Other ~/~_~ ~ '[~9 thru 3~L] ' ' .[323 (8) Add l ~..~.~/ ~ geology' engin.eering: DWJ MTM~. RAD~ ~2--~ BEW dDH,~4 ~/~ RPC~'~_ LG rev 12/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ngrnber of contact to supply weekly progress data ...... Additional requirements ............................................. ~NI'TIAL ........ GEOL 'IUNIT"' ON/OFF POOL CLASS STATUS AREA ~ SHORE _ i, , Additional MERIDIAN: remarks' UM ,TYPE' Exp/Dev Inj Red ri 11 Rev O 'l-Z ~0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIx. No special effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 9-4A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA AP1 NUMBER : 50-029-20212-01 REFERENCE NO : 953e2 Anchorage ., LES Tape Ver|fication Lis%ing Schlumberger Alaska Comput|ng Center 5-SEP-19'95 10:41 **** REEL HEADER ***~ SERVICE NAME : EDIT DATE : 95/09/ 5 ORIGIN : FLIC REEL NAME : 953~2 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 9-4A, API# 5e-029-20212-0[ ***~ TAPE HEADER SERVICE NAME : EDIT DATE : 95/09/ ORIGIN : FLIC TAPE NAME : 953~2 CONTINUATION # : ~ PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 9-4A, API# 50-029-202~2-0[ TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S, 9-4A AP1 NUMBER: 5002920212~! OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 5-SEP-95 JOB NUMBER: 95302 LOGGING ENGINEER: SIMMONS OPERATOR WITNESS: D.REEM SURFACE LOCATION SECTION: 2 TOWNSHIP: ~ON RANGE: 15E FNL: FSL: 405 FEL: 747 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: s4.ee DERRICK FLOOR: 53.00 GROUND LEVEL: 28.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) [ST STRING 9.625 8680.0 2ND STRING 7.000 [0106.0 3RD STRING $.500 8413.0 PRODUCTION STRING 4.500 9457.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) 47.00 29.00 [7.00 [2.60 PAGE: L~S Tap~ Verification Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 25-FEB-93 5-SEP-1995 10:4~ LOGGING COMPANY: BASELINE DEPTH GRCH SCHLUMBERGER WELL SERVICES EQUIVALENT UNSHIFTED DEPTH NPHI 88888.0 88888,e 88888.~ 9872,5 9872.5 9872.5 9865,5 9865.0 982~,5 9820.5 9820.5 9816,5 9816,0 9812,0 98e7.5 9807.5 98e7.5 9793.5 9794.e 9794.0 9755.5 9755.5 97[0.5 97[0.5 97[0.5 9656.0 9656.0 9655.5 9656.5 9643.5 9644.5 9628.5 9628.5 9622.5 9622.5 9569.5 9570.0 9520.0 952[.0 9521.0 9478.5 9479.0 9479.e 9468.5 9469.0 9469.0 946e.0 946e.e 946e.e $ REMARKS: The depth adjustments shown above reflect cased hole GR to open hole GR and cased hole NPHI to open hole GR. All other CNTG curves were carried with the NPHI shifts. PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. LIS Tape~ Verificaf, ion Listing Schlumberger Alaska Computing Center 5-SEP-1995 10:41 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9ge2.0 9447.0 CNTG 9912.0 9447.e $ # CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH GRCH ,EQUIVALENT UNSHIFTED DEPTH CNTG REMARKS: This file contains CNTG Pass #1. shifts were applied to this data. $ LIS FORMAT DATA. No pass to pass PAGE: ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LiS Tape Verificat|on List;ing Schlumberger Alaska Comput~ing Ceni~er SET TYPE - CHAN ** 5-SEP-1995 10:4[ PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 5e6134 oe Dee ee e ! ! I 4 68 oeeeeeeeee NPHI CNTG PU-S 5e6134 9e eD9 9e e 1 1 1 4 68 eeeee999ee ENPH CNTG PU-S 596134 99 eee ee e 1 1 1 4 68 eegegegege CPHI CNTG PU-S 5e6134 ee 99e 9e e I I I 4 68 eeee99egee NRAT CNTG se6134 99 e99 99 e I 1 1 4 68 999ee999ee CRAT CNTG 596134 99 9ee e9 e I 1 1 4 68 eeeege99ee ENRA CNTG 596134 ee 99e 99 e 1 1 1 4 68 9eeeegeege NCNT CNTG CPS 596134 9e 99e 9e e I I 1 4 68 eeeeeegeee FCNT CNTG CPS 596134 99 ege e9 e 1 1 I 4 68 999egeeege CNTC CNTG CPS 506134 9e Dee e9 e 1 1 1 4 68 eee9999ege CNEC CNTG CPS 596134 99 Dee ee e I I I 4 eS eeeegeeeee CFEC CNTG CPS 596134 9e 9eD ee e 1 1 1 4 68 9egegee999 GRCH CNTG GAPI 5e6134 ee 99e 9e e 1 1 I 4 68 egeeoeeee9 TENS CNTG LB 596134 99 999 ee e 1 1 I 4 68 egeegegege CCL CNTG V 5e6134 ee 99e e9 e 1 1 1 4 68 egeegeeeee DATA DEPT. 995e.ee9 NPHI.CNTG -999.25e ENPH.CNTG -999.25e CPHI.CNTG NRAT.CNTG -999.259 CRAT.CNTG -999.25e ENRA.CNTG -999.25e NCNT.CNTG FCNT.CNTG -999.259 CNTC.CNTG -999.25e CFTC.CNTG -999.25e CNEC.CNTG CFEC.CNTG -999.259 GRCH.CNTG -999.25e TENS.CNTG -999.25e CCL.CNTG GR.BCS 41.75e DEPT. 94De. Dee NPHI.CNTO -999.25e ENPH.CNTG -999.25e CPHI.CNTG NRAT.CNTG -999.259 CRAT.CNTG -999.25e ENRA.CNTQ -999.25e NCNT.CNTG FCNT.CNTG -999.259 CNTC.CNTG -999.25e CFTC.CNTG -999.25e CNEC.CNTG CFEC.CNTG -999.25e GRCH.CNTG -999.25e TENS.CNTG -999.259 CCL.CNTG GR.BCS 274.Dee -999.25e -999.25e -999.25e -999.25e -999.25e -999.25e -999.25e -999.25e END OF DATA **=, FILE TRAILER FILE NAME : EDIT .eel SERVICE : FLIC VERSION : e91Cel DATE : 95/99/ MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : LIS Tap~ Verification Listing Schlumberger Alaska Computing Center ===* FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 991C~1 DATE : 95/99/ 5 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : 5-SEP-1995 19:41 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shi~%ed and clipped curves ~or each pass in separate ~iles. PASS NUMBER: 2 DEPTH INCREMENT: g.5999 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9992.9 9448.0 CNTG 9912.9 9448.9 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: I ,EQUIVALENT UNSHIFTED DEPTH, BASELINE DEPTH GRCH CNTG 88888.9 88887.5 88887.5 9993.5 9993.9 9895.5 9895.9 9891.5 9899.5 9888.5 9888.9 9887.5 9886.5 9883.5 9883.9 9889.5 9889.9 9876.5 9875.5 9875.5 9875.9 9872.5 9871.5 9871.5 9879.5 9868.5 9868.9 9867.5 9866.5 9864.5 9864.9 9863.5 9862.9 9869.5 9859.5 9859.5 9858.5 9855.5 9854.9 9847.5 9846.9 9843.5 9842.5 LIS Tape Verification Listing Schlumberger Alaska Comput|ng Center 9831.5 9830.5 9828.5 9827.5 9827.5 9827.0 9824.5 9824.0 9823.5 9822.5 9820.5 9819.5 9819.5 9819.~ 9815.5 9813.5 9811.5 981e.e 9808.5 9807.5 98~7.5 98e6.e 9804.5 9804.0 98~3.5 9802.5 9799.5 9799.e 9787.5 9787.0 9783.5 9784.e 9780.5 978e.0 9779.5 9779.5 9775.5 9775.e 9772.5 9771.5 9767.S 9767.0 9764.S 9763.5 9763.5 9763.5 9760.5 9760.0 9759.5 9758.5 9748.5 9748.0 9744.5 9743.S 9743.5 9742.5 9740.5 9738.5 9739.5 9739.0 9736.5 9734.e 9735.5 9734.5 9732.5 9731.0 9728.5 9727.0 9724.5 9723.5 9716.5 9715.5 9715.5 9714.5 9712.5 9712.0 9711.5 9711.0 9708.5 97~7.5 9699.5 9699.0 9696.5 9695.5 9695.5 9694.5 9692.5 9692.5 9679.5 9678.5 9676.5 9676.5 9675.5 9673.5 9672.5 9673.0 9671.5 9670.0 9668.5 9668.5 9667.5 9666.5 9655.5 9654.5 96S1.5 9651.0 9647.S 9648.0 9644.S 9644.5 5-SEP-1995 10:41 PAGE: L¥S Tap~ Verificat|on L|sting Schlumberger Alaska Computing Center 5-SEP-1995 10:41 9643.5 9644.~ 9640.5 964~.0 9639.5 9639.5 9631.5 9631,5 9627.5 9627.0 9616.5 9616.0 9612.5 9612.5 9611.5 9611.0 9608.5 9608.0 96~7.5 9606.5 96~4,5 96g4,5 9603.5 9602.0 9599.5 9599.0 9595.5 9595.~ 9591.5 9591.5 9583.5 9583.5 9579.5 9580.0 9575.5 9575.5 9571.5 9571.0 9567.5 9567.~ 9563.5 9562.0 9559.5 9559.5 9555.5 9556.0 9551.5 9551.5 9548.5 9548.5 9544.5 9545.0 9543.5 9544.~ 9540.S 9540.5 9539.5 9539.5 9536.5 9S37.0 9531.5 9531.5 9527.5 9526.5 9523.5 9S24.0 9516.5 9517.0 9512.5 9512.5 9508.5 95~8.5 9507.5 9508.0 9504.5 9S05.0 9503.5 9503.5 9500.5 95~1.0 9499.5 9500.0 9496.5 9496.5 9495.5 9495.5 9492.5 9492.5 9488.5 9488.0 9484.5 9484.5 100.0 100.0 1~0.0 $ REMARKS: This file contains CNTG Pass #2. The depth shifts shown above relect GRCH pass #2 to GRCH pass #1 and NPHI pass #2 to NPHI pass #1. $ LIS FORMAT DATA PAGE: L~S Tap~ Verif|cation Listing Schlumberger Alaska Comput|ng Center ~-SEP-199~ PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE [ 66 0 2 66 0 3 73 64 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 ~3 66 0 Z4 65 FT Z5 66 68 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOQ TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 506134 90 900 MO NPHI CNTG PU-S 5M6134 MM MMM MM ENPH CNTG PU-S 5M6134 MM MMM MM CPHI CNTG PU-S 5M6134 MM MMM MM NRAT CNTG 5M6134 MM MMM MM CRAT CNTG 5M6134 MM MMM MM ENRA CNTG 5M6134 MM MMM MM NCNT CNTG CPS 5M6134 MM MMM MM FCNT CNTG CPS 5M6134 MM MMM MM CNTC CNTG CPS 5M6134 MM MMM MM CFTC CNTG CPS 5M6134 MM MMM MM CNEC CNTG CPS 5M6134 MM MMM MM M 2 1 1 4 68 MMMMMOMMMM M 2 1 1 4 68 MMMMMMMMMM M 2 1 1 4 68 MMMMMMOMMM M 2 1 1 4 68 MMMMMMMMMM M 2 1 1 4 68 MMMMMMMMMM M 2 1 1 4 68 MMMMMMMMMM M 2 ! 1 4 68 MMMMMMMMMM M 2 1 1 4 68 MMMMMgMMgM M 2 1 1 4 68 MMMMMgMMMM M 2 1 1 4 68 MMMMMOMMMM 0 2 ! 1 4 68 MOOMMOMOOM M 2 1 1 4 68 MOMMOOOMMM ! 1 4 68 00MMOOMOMM ! 1 4 68 MMMOMOMMOM 1 1 4 68 MgMgMMM90M 1 1 4 68 OMMgMOMMMM CFEC CNTG CPS 5M6134 MM OMM MM M 2 GRCH CNTG GAPI 506134 MM MMM MM M 2 TENS CNTG LB 5M6154 OM OMM MM M 2 CCL CNTG V 5M6134 OM MMM MM M 2 DATA L~S Tap~ Verification Listing Schlumberger Alaska Compu%ing Center 5-SEP-1995 10:41 DEPT. ggll.50e NPHI.CNTO 31.468 ENPH.CNTG 25.053 NRAT.CNTG 3.e43 CRAT.CNTQ 3.129 ENRA.CNTG 4.132 FCNT.CNTG 709.183 CNTC.CNTG 2043.023 CFTC.CNTG 732.628 CFEC.CNTG 711.767 GRCH.CNTQ -999.250 TENS.CNTG 3315.000 DEPT. 9448.000 NPHI.CNTG 30.939 ENPH.CNTG NRAT.CNTG 3.303 CRAT.CNTG 3.100 ENRA.CNTO FCNT.CNTG 662.907 CNTC.CNTG ~914.013 CFTC.CNT¢ CFEC.CNTG [188.810 GRCH.CNTG 117.563 TENS.CNTO 21.108 3.680 631.[55 3233.000 CPHI.CNTG NCNT.CNTQ CNEC.CNTG CCL.CNTG CPHI.CNTG NCNT.CNTG CNEC.CNTG CCL.CNTG PAGE: 23.062 2218.090 2940.743 -0.006 26.663 2100.662 4375.029 0.015 ** END OF DATA **** FILE TRAILER FILE NAME : EDIT .e02 SERVICE : FLIC VERSION : 001C01 DATE : 95/e9/ MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001Ce[ DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifSed and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: ~.5o00 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9902.0 9446.0 CNTG 9912.0 9446.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: LIS Tap& Verificat|on Listing Schlumberger Alaska Computing Center 5-SEP-1995 10:41 PAGE: 10 BASELINE DEPTH GRCH 88888.0 88888.5 9903.5 9899.5 9895.5 9891.5 9884.5 9885.0 9883.5 9880.5 9880.5 9879.5 9876.5 9876.5 9875.5 9872.5 9873.e 9871.5 9868.5 9869.0 9864.5 9864.5 9863.5 9859.5 9855.5 9847.5 9843.5 9839.5 9835.5 9823.5 9819.5 98~4.5 9804.5 98e3.5 9800.5 9801.0 9799.5 9791.5 9787.5 9767.5 9755.5 9751.5 9748.5 9749.0 9744.5 9744.5 9743.5 9740.5 9739.5 9739.5 9735.5 9732.5 9731.5 9731.5 9728.5 9728.5 97~4.5 9704.5 9703.5 9700.5 9700.0 9699.5 9696.5 9696.5 9695.5 9692.5 9693.0 9691.5 9688.5 9689.5 EQUIVALENT UNSHIFTED DEPTH CNTG 88889.0 9904.5 9900.0 9896.0 9891.5 9883.5 9880.0 9876.0 9871.0 9863.0 9859.5 9855.0 9847.0 9843.5 9839.0 9835.5 9823.5 9819.0 9803.0 9799.5 9791.5 9788.0 9768.0 9754.5 9751.0 9744.0 9740.e 9736.5 9731.5 9703.5 9700.5 9696.0 9691.5 L~S Tap~ Verification Listing Schlumberger Alaska Compu%ing Center 5-SEP-1995 I0:41 PAGE: 9687.5 9687.5 9684.5 9685.0 9683.5 9684.0 9680.5 9681.5 9679.5 968e.0 9676.5 9677.0 9675.5 9675.5 9668.5 9669.0 9664.5 9665.5 9651.5 9651.5 9647.5 9648.5 9640.5 9641.5 9639.5 964~.5 9636.5 9637.0 9635.5 9636.0 9631.5 9632.0 9627.5 9628.5 9623.5 9624.~ 96~7.5 9608.0 96~3.5 9602.5 9599.5 9599.5 9596.5 9597.0 9595.5 9596.0 9592.5 9593.5 9583.5 9584.0 9580.5 9581.5 9579.5 9580.5 9576.5 9577.0 9572.5 9573.5 9551.5 9552.5 9547.5 9547.5 9544.5 9545.5 9543.5 9544.5 9540.5 9542.0 9531.5 9532.5 9527.5 9529.0 9512.5 9514.0 95e8.5 9509.5 9499.5 9501.0 9495.5 9496.5 9491.5 9492.0 9479.5 948~.0 9475.5 9476.5 1~0.~ 1~1.0 101.~ REMARKS: This file contains CNTG Pass #3. The depth shifts shown above relect GRCH pass #3 to GRCH pass #1 and NPHI pass #3 to NPHI pass #1. LIS FORMAT DATA L~S Tap~ Verifica%ion Lis%ing Schlumberger Alaska Compu%ing Cen~er 5-SEP-1995 10:41 PAGE: 12 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 $ 73 64 4 66 5 66 6 75 7 65 8 68 0.5 9 65 FT [[ 66 16 [2 68 13 66 0 [4 6~ FT [5 66 68 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 506134 00 000 00 0 3 I [ 4 68 0000000000 NPHI CNTG PU-S 506134 00 000 00 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 506134 00 000 00 0 3 1 [ 4 68 0000000000 CPHI CNTG PU-S 506134 00 000 00 0 3 1 1 4 68 0000000000 NRAT CNTG 506134 00 000 00 0 3 ! [ 4 68 0000000000 CRAT CNTG 506134 00 000 00 0 3 [ [ 4 68 0000000000 ENRA CNTG 506134 00 000 00 0 3 [ [ 4 68 0000000000 NCNT CNTG CPS 506134 00 000 00 0 3 I I 4 68 0000000000 FCNT CNTG CPS 506134 00 000 00 0 3 I 1 4 68 0000000000 CNTC CNTG CPS 506134 00 000 00 0 3 I 1 4 68 0000000000 CFTC CNT~ CPS 506134 00 000 00 0 3 [ 1 4 68 0000000000 CNEC CNTG CPS 506134 00 0~0 00 0 3 [ [ 4 68 0000000000 CFEC CNTG CPS 506134 00 000 00 0 $ I I 4 68 00~0000000 GRCH CNTG GAPI 506154 00 000 00 0 3 ! 1 4 68 00000~0000 TENS CNTG LB 506134 00 000 00 0 3 [ 1 4 68 0000000000 CCL CNTG V 506[34 00 000 00 0 $ ! [ 4 68 0900000000 DATA L~S Tap~ Verification Listing Schlumberger Alaska Comput|ng Center 5-SEP-lgg5 10:41 DEPT. 9913.900 NPHI.CNTG 29.~69 ENPH.CNTG 26.998 NRAT.CNTG 2.927 CRAT.CNTG 3.093 ENRA.CNTG 4.344 FCNT.CNTG 7~8.549 CNTC.CNTG 2127.020 CFTC.CNTG 739.350 CFEC.CNTG 661.781 GRCH.CNTG -999.250 TENS.CNTG 3290.090 DEPT. 9447.900 NPHI.CNTG 39.199 ENPH.CNTG NRAT.CNTG 3.228 CRAT.CNTG 3.959 ENRA.CNTG FCNT.CNTG 6~9.646 CNTC.CNTG 1893.455 CFTC.CNTG CFEC.CNTG 1154.379 GRCH.CNTG 132.500 TENS.CNTG 20.893 3.655 617.718 3210.09~ CPHI.CNTG NCNT.CNTG CNEC.CNTG CCL.CNTG CPHI.CNTG NCNT.CNTG CNEC.CNTG CCL.CNTG PAGE: 13 24.350 2309.256 2875.097 -0.004 27.155 294~.610 4219.999 -0.013 END OF DATA **** FILE TRAILER FILE NAME : EDIT .993 SERVICE : FLIC VERSION : 091c01 DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .994 SERVICE : FLIC VERSION : 001C0[ DATE : 95/09/ 5 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5990 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS CNTG 1, 2, 3~ $ REMARKS: The arithmetic average of passes 1~2 & 3 was computed after all depth shi~s and clipping was applied. $ LIS FORMAT DATA L~S Tape Verifica%ion Li$%ing Schlumberger Alaska Compu%ing Cen~er 5-SEP-lgg5 10:41 PAGE: 14 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 56 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ,, NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 506134 00 000 00 0 4 I I 4 68 0000000000 NPHI CNAV PU-S 506134 00 000 00 0 4 1 I 4 68 0000000000 NRAT CNAV 506134 00 000 ~0 0 4 1 ! 4 68 0~000~0000 CPHI CNAV PU-S 506134 ~0 00~ 00 0 4 1 1 4 68 0000000000 CRAT CNAV 5~6134 00 000 00 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 5~6134 ~0 00~ ~0 0 4 1 1 4 68 00000000~0 ENRA CNAV 5~6134 00 00~ ~0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 506134 00 00~ ge 0 4 1 1 4 68 00~0000000 FCNT CNAV CPS 506134 00 00~ 00 0 4 1 1 4 68 000~00~000 CNTC CNAV CPS 506134 00 000 00 0 4 I 1 4 68 000~0000~0 CFTC CNAV CPS 506134 00 00~ ~ 0 4 1 I 4 68 0000000000 CNEC CNAV CPS 506134 00 000 00 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 506134 00 000 ~0 0 4 1 1 4 68 000~0000~0 GRCH CNTG GAPI 506134 00 000 00 0 4 I 1 4 68 eeeeeeeeee DATA DEPT. 9911.500 NPHI.CNAV 28.683 NRAT.CNAV 3.056 CPHI.CNAV CRAT.CNAV 2.976 ENPH.CNAV 24.554 ENRA.CNAV 4.076 NCNT.CNAV FCNT.CNAV 733.176 CNTC.CNAV 2030.915 CFTC.CNAV 734.683 CNEC.CNAV CFEC.CNAV 730.431 GRCH.CNTG -999.250 22.709 2143.624 2976.398 L~S Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 ;~0:4'~ PAGE: 15 END OF DATA ** *~** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : eelcel DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG $ LOG HEADER DATA 9912.0 9447.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE lg-AUG-95 CP42.2 901 9912.0 9918.0 9448.0 9912.0 NO 19-AUG-95 TOOL NUMBER L±S Tap~ Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 PAGE: ~6 CNTG CNTG TCC CNTG CNTG GR CNTG $ COLLAR LOCATOR LOGGING SOURCE TELEMETRY CARTRIDGE HOUSING COMP. NEUTRON CART. GAMMA RAY COMP. NEUTRON CAL-YA 1592 NSR-FA 2290 TCC-B 320 CNB-AB 3255 CNC-GA 63 SGC-SA 1004 CTSM-A 324 BOREHOLE AND CASINg DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8689.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 9 FAR COUNT RATE HIGH SCALE (CPS): 1599 NEAR COUNT RATE LOW SCALE (CPS): 9 NEAR COUNT RATE HIGH SCALE (CPS): 7999 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHC LOG OF 25-FEB-1993. LOGGED ON SANDSTONE MATRIX THREE PASSES LOGGED AT 1899 FT/HR FROM PBTD - 9948' $ LIS FORMAT DATA L~S Tap~ Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 10:41 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 13 66 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** PAGE: 17 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOQ TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 5~6134 00 000 00 0 5 1 1 4 68 0000000000 NPHI PS1 PU 506134 ~ 000 ~0 0 5 1 1 4 68 0~0~0000~0 ENPH PS1 PU 506134 ~ 0~ 00 0 5 1 1 4 68 000~000000 TNPH PS1 PU 506134 00 00~ 00 0 5 1 1 4 68 000000~0~0 TNRA PS1 506134 00 0~0 00 0 5 1 1 4 68 000~0000~ RTNR PS1 506134 00 00~ 00 0 5 1 1 4 68 0000000000 ENRA PS1 5e6134 ~ 000 00 e 5 1 1 4 68 000e0000~ CFEC PS1 CPS 506134 0~ 000 00 ~ 5 1 I 4 68 000~0000~0 CNEC PS1 CPS 506134 00 000 00 0 5 1 I 4 68 000000000~ RCEF PS1 CPS 5~6134 00 0e0 Oe ~ 5 1 1 4 68 00~0~00000 RCEN PS1 CPS 5~6134 00 000 00 ~ 5 1 1 4 68 0000000000 RCNT PS1 CPS 506134 00 000 eO 0 5 1 1 4 68 000000000e RCFT PS1 CPS 506134 00 000 ~0 ~ 5 1 I 4 68 00~0~000~0 CNTC PS1 CPS 506134 00 000 00 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 506134 00 000 00 0 5 1 1 4 68 0000000~00 NPOR PS1 PU 506134 00 000 00 0 5 1 1 4 68 0000000~00 GR PS1 GAPI 506134 00 000 00 0 5 1 I 4 68 0~00000000 TENS PS1 LB 5~6134 00 000 00 0 5 1 1 4 68 0000000000 CCL PS1 V 5~6134 ~0 ~00 00 0 S 1 1 4 68 0000000000 ** DATA L±S Tap~ Ver|fication Listing Schlumberger Alaska Computing Center DEPT. 9935.500 NPHI.PS1 TNRA.PSI 2.722 RTNR.PS1 CNEC.PS1 25~6.498 RCEF.PS1 RCFT.PS1 739.609 CNTC.PS1 GR.PS1 96.625 TENS.PS1 DEPT. 9446.500 NPHI.PS1 TNRA.PSZ 3.246 RTNR.PS1 CNEC.PS1 4301.623 RCEF.PS1 RCFT.PSl 610.339 CNTC.PS1 GR.PSl 126.688 TENS.PS1 5-SEP-1995 10:4t 24.053 ENPH.PS1 2.784 ENRA.PS1 538.338 RCEN.PS1 ~951,435 CFTC.PS1 226~.000 CCL.PS1 33.611 ENPH.PS1 3.244 ENRA.PS1 1149.263 RCEN.PS1 1881.988 CFTC.PS1 3385.e00 CCL.PS1 29.939 4.655 2298.308 733.543 -0.0e2 21.950 3.779 3957.674 610.893 -~.005 TNPH.PS1 CFEC.PS1 RCNT.PS1 NPOR.PS1 TNPH.PS1 CFEC.PS1 RCNT.PS1 NPOR.PS1 PAGE: 18 21.22e 538.490 2089.902 21.22o 27.389 1138.353 1906.488 29.416 ** END OF DATA **** FILE TRAILER FILE NAME : EDIT .0e5 SERVICE : FLIC VERSION : eelCel DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE .: **** FILE HEADER **** FILE NAME : EDIT .ee6 SERVICE : fLIC VERSION : 001C01 DATE : 95/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in las% file PASS NUMBER: 2 DEPTH INCREMENT: 0.5~00 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTg $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: 9912.0 9448.0 19-AUG-95 CP42.2 L~S Tap~ Veri~icat|on L|sting Schlumberger Alaska Computing Center 5-SEP-1995 10:41 TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) ~ENDOR TOOL CODE TOOL TYPE 9912.0 9918.0 9448.0 9912.0 1800.~ NO 19-AUG-95 TOOL NUMBER CNTG CNTG TCC CNTG CNTG OR CNTG $ COLLAR LOCATOR LOGGING SOURCE TELEMETRY CARTRIDGE HOUSING COMP. NEUTRON CART. GAMMA RAY COMP. NEUTRON CAL-YA 1592 NSR-FA 2290 TCC-B 320 CNB-AB 3255 CNC-GA 63 SGC-SA 1004 CTSM-A 324 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE coNDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): 8680.0 PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): EPITHERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL zoNE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 1500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 7000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHC LOG OF 25-FEB-1993. PAGE: 19 LiS Tap~ Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 10:41 LOGGED ON SANDSTONE MATRIX THREE PASSES LOGGED AT 1800 FT/HR FROM PBTD - 9948~ $ LIS FORMAT DATA PAGE: 20 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 0 3 73 76 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 ~ 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 API AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 506134 00 000 00 0 6 1 1 4 68 0000000000 NPHI PS2 PU 506134 00 000 00 0 6 1 1 4 68 0000000000 ENPH PS2 PU 506134 00 000 00 0 6 I 1 4 68 0000000000 TNPH PS2 PU S06134 ~0 000 TNRA PS2 506134 00 000 00 0 6 1 1 4 68 0000000000 RTNR PS2 506134 00 000 00 0 6 1 1 4 68 0000000000 ENRA PS2 506134 00 000 00 0 6 I 1 4 68 0000000000 CFEC PS2 CPS 506134 00 000 00 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 506134 00 000 00 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 506134 00 000 00 0 6 1 1 4 68 0000000000 RCEN PS2 CPS 506134 00 000 00 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 506134 00 000 00 0 6 I 1 4 68 0000000000 RCFT PS2 CPS 506134 00 000 00 0 6 1 I 4 68 0000000000 CNTC PS2 CPS 506134 00 000 00 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 506134 00 000 00 0 6 1 1 4 68 0000000000 NPOR PS2 PU 506134 00 000 0~ 0 6 I 1 4 68 0000000~00 GR PS2 GAPI 506134 00 000 00 0 6 1 1 4 68 00000000~0 L~S Tap~ Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 10:41 PAGE: 21]. NAME SERV UNIT SERVICE AP1 AP1 API AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS PS2 LB 506134 00 00~ 00 e 6 1 1 4 68 eoooOOOe00 CCL PS2 V 506134 Oe 0e0 00 0 6 1 1 4 68 oeoooooe00 DATA DEPT. 9931.500 NPHI.PS2 28.940 ENPH.PS2 32.378 TNPH.PS2 TNRA.PS2 2.990 RTNR,PS2 3,~58 ENRA,PS2 4,902 CFEC.PS2 CNEC,PS2 256~,219 RCEF,PS2 522,170 RCEN,PS2 2347.567 RCNT.PS2 RCFT.PS2 694.397 CNTC.PS2 2015,341 CFTC,PS2 688,701 NPOR.PS2 GR.PS2 99.625 TENS.PS2 2265.~0~ CCL.PS2 -0.006 DEPT. 9447.000 NPHI.PS2 31.158 ENPH.PS2 21.440 TNPH.PS2 TNRA.PS2 3.112 RTNR.PS2 3.253 ENRA.PS2 3.719 CFEC.PS2 CNEC.PS2 4317.445 RCEF.PS2 1182.91~ RCEN.PS2 3930.988 RCNT.PS2 RCFT.PS2 610.339 CNTC.PS2 1920.168 CFTC.PS2 608.421 NPOR.PS2 GR.PS2 130.500 TENS.PS2 31ge.~e~ CCL.PS2 0.004 25.078 522.315 2158.342 25.078 28.534 1160.863 2042.066 28.791 ,~* END OF DATA ** **** FILE TRAILER FILE NAME : EDIT .006 SERVICE : FLIC VERSION : eeicei DATE : 95/09/ MAX REC SIZE : le24 FILE TYPE : LO LAST FILE : **** FILE HEADER .*** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 0~1C01 DATE : 95/09/ S MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 L~[S Tap~ Verification List;lng Sch I umberger A I aska Compu~oi ng Cen~er 5-SEP-1995 10:4~ DEPTH INCREMENT: ~.5~O FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG $ LOG HEADER DATA 9912.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 9446.0 19-AUG-95 CP42.2 1029 9912.0 9918.0 9448.~ 9912.0 18~0.0 NO 19-AUG-95 TOOL NUMBER CNTG CNTG TCC CNTG CNTG GR CNTG $ COLLAR LOCATOR LOGGING SOURCE TELEMETRY CARTRIDGE HOUSING COMP. NEUTRON CART. GAMMA RAY COMP. NEUTRON CAL-YA 1592 NSR-FA 2290 TCC-B 32~ CNB-AB 3255 CNC-GA 63 SGC-SA 10~4 CTSM-A 324 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/0IL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 8680.0 PRODUCED FLUIDS EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN 0IL ZONE PAGE: 22 L~S Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1995 10:41 TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 1590 NEAR COUNT RATE LOW SCALE (CPS): 9 NEAR COUNT RATE HIGH SCALE (CPS): 7999 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHC LOG OF 25-FEB-1993, LOGGED ON SANDSTONE MATRIX THREE PASSES LOGGED AT 1899 FT/HR FROM PBTD - 9945'. $ LIS FORMAT DATA PAGE: 23 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 9 2 66 9 3 73 76 4 66 1 5 66 6 73 7 65 8 68 9.5 9 65 FT 11 66 13 12 68 13 66 9 14 65 FT 15 66 68 9 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 596134 99 999 99 9 7 1 1 4 68 9999999999 NPHI PS3 PU 596134 99 999 99 9 7 1 1 4 68 9999999999 ENPH PS3 PU 596134 99 999 99 9 7 1 1 4 68 9999999999 TNPH PS3 PU 596134 99 999 99 9 7 1 1 4 68 9999999999 TNRA PS3 596134 99 999 99 9 7 1 1 4 68 9999999999 RTNR PS3 596134 99 999 99 9 7 1 1 4 68 9999999999 : 39I~ ~S¥9 09 : 3aA~ ~OS : 3ZIS ~3~ X¥~ S /60/S6 : I~D~00 : NOISa3A OIq~ : 3DIAB3S LO~' 1I~3 : 3~¥N **** a39IVai 39I~ **** ** VIVO ~0 ON3 ** I86'B~ ~S8'L~ 96a'~9aa 6Bz'6ts SS0'0- SSd'qDD 000'SI~ SSS'SN3i S~9'SS[ ssa'aOaN I9~'609 SSa'Dla3 L8I'968[ gSa'D£N3 ZVS'~S9 SSa'HaN± eee's~ SSa'HaN3 9Se'SS SSa'IHaN ~S'S~6 '±a30 P00'0- SSa'gDO 000'SS~C SSS'SN3i S9~'I6 SSS'aO SSd'~OdN ~£'SIL SSd'Di~3 LO~'~ SSd'3£N3 8S~'~L SSd'l~D~ ~Sd'lN3a ~S'e6S~ SSd'N33a I9fi'6~S gSd'a33a ~6L'S~9~ ~Sd'33N3 ~$a'HdN± ~SZ'~S SSa'HdN3 S6S'6~ SSd'IHaN ~0S'6~66 '±d30 ** ViVO ** 0000~00000 89 ~ T. T L 0 00 0~0 00 ~ST90S A SSd 00000~000~ 89 ~ T I L 0 ~0 ~00 00 ~ST9~S Gq SSa SN31 OgOOOOOggO 89 ~ T T L 0 00 Og~ Og ~£lggs IdVO SSd 00000900gg 89 ~ T T L 0 00 00g Og ~STggS nd SSd ~OdN 00090ggOOg 89 ~ I I L 0 Og 00g Og ~sIggs SdD SSd Died 00ggOggOOg 89 ~ I I L 0 Og g00 Og ~sIggs SdD SSd 3iND OgOOgOOg00 89 ~ I I L 0 00 000 00 ~£Iggs Sd3 ssa OggOggg000 89 ~ I I L 0 00 000 00 ~slggs SdD SSd IN3~ 00090ggOgO 89 ~ I I L 0 Og 00g Og ~slggs SdD ssa N~D~ 00gggOOOgO 89 ~ I ~ L 0 Og gOg 00 ~£I90S SdD ssa OgOg000000 89 ~ I I L 0 Og 000 00 ~$Iggs sad ssa D3N3 (X3H) 3Q03 ~393 dRVS B~N OO~ SS¥9D 3dXi 009 # ~3QBO SS3DOB~ B~3B 3ZIS B~N B~N 39I~ I8¥ I~¥ I~¥ I~¥ 3DIAB3S IIN~ AB3S 3~¥N :3OVd I~:0I S66[-d3S-S Je~ue3 6u!4ndmo3 eMsel¥ ~eSaeqmnlqoS Su!~s!9 u°!~e3!$!aeA ~del L~S Tap~ Verification Listing Schlumberger Alaska Compu%ing Center S-SEP-1995 10:41 PAGE: 25 **** TAPE TRAILER SERVICE NAME : EDIT DATE : 9S/09/ 5 ORIGIN : FLIC TAPE NAME : 95502 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 9-4A, API# 50-029-20212-01 **** REEL TRAILER SERVICE NAME : EDIT DATE : 95/09/ 5 ORIGIN : FLIC REEL NAME : 95502 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 9-4A, API# 5~-~29-20212-01 ****************************** COMPANY NA~E w~L[~ NA~E STATE AP! ~IJ~BER A~CO ALASKA, INC, 9-4A 50-0~9-2021.2-01 93090 RECEIVED ~AR 1 9 199~ Alaska Oil & Gas Cons. 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O0 8ZO'EE9 910'99 000'~619 O00'~L~ 060'6gE'[ 968'~g qND'~OdN ggE'E q.O'l.d. 000'68tt LO:80 £66 l'a¥'V~-f I ,, V ii,,'V a M 0 O ~ iii ,, 0'8E98 0'0~99 ~i6 a T9Z ¥S DDS 0:8800[ 0 00£6 O'SOiO[ 0'9010~ 00~ ~'8[ dD ~ONOS DIN09 2qOH380~ '£d~D DiNO~ qqo mmmmmmmmm 3d/~ qO0~ ~GOD qo0£ (~OiiO~ O~ dOi) DNi~tg qooi 0'~6£6 0'66~6 :(&~) q~A83&NI DOq dO& O'L~L6 0'§9L6 O'LSL6 qqQ 0'8[L6 SD ~3(1~3h ~qiA :3DYd LO:80 E66['SV~-['[ m~m~mmmmmmm~mmmmmmmmmmmmmmmmmm 99 0 t 99 0 99 ~ 99 g'O ~9 ~9 £ 99 ~ 99 8~I EL i ~ 9~ 0 99 :39¥d 0086 0'09 0'09 0'09 60g'O iLI~O 80~°0 LO:80 [66[-8¥a-El ;chlumber~er Alaska Compt, lt!nq Cent:er 13-MAR-1993 08:07 PAGE: SET TYPE - CHA:".,! * ~RDER ~ LOG DEPT FT 6! 9034 O0 DT BMR US/F 619034 O0 TT1 BNR [)S 619034 O0 TT] RF!R !JS 619034 00 TT4 BHR US 619034 GR BHR GAPI 619034 OO TEN~ BHR LB ~19034 O0 ~iTE~ RHR DEGF 619034 ~RES BHR OH~M 61.9034 00 LLS DL~ O~b.~ p 6190~4 O0 LLD DLR OH~ 619034 O0 (;~ DLR GA, PT 619034 O0 TEN,S DLR LB 619034 O0 ~TE~ DLR DEGF 619034 O0 ~%PE~ DLR OHt~' 619034 O0 }{ T E:~ ~ DI,,R [~ 6190.34 OO ~ PH 1' CNR PI! 619034 00 RTh;R CN~ 619034 O0 TNPN CNR PU 610034 O0 TNR~[ CN~ 619034 00 t~PO~ CN'~ PU 6190'~4 O0 RC~T CNR CPS 619034 O0 ~CFT CNR CPS 619034 O0 CNTC CNR CPS 619034 O0 CFTC C~,{~ CPS 6190~4 OD G~ CNP GAP! 619034 TE~g CN~ LB 619034 O0 ~RES CN~ O'H~4~ 61~034 00 ~4*E~' CNP DEGF 619034 O0 HTE~ CNR LB 61o034 O0 oo0 oo 0oo OO 000 oo o00 oo ooo oo 000 oo o00 oo o00 00 oo0 oo 000 O0 000 oo 000 O0 000 0o 000 00 0o0 O0 000 oo 0o0 oo oo0 oo 000 oo 0oo OO ooo oo oo0 O0 0o0 o0 o0o 00 oo0 oo o00 Oo oo0 oo 0oo oo 00o 0o oo0 oo ooo 00 0oo no o 3 1 1 4 68 0000000000 o 3 I I 4 68 0o00000000 0 3 1 1 4 68 0000000000 o 3 I t 4 68 0000000000 o 3 1 t 4 68 o0000o0000 0 3 1 1 4 68 0000000000 o 3 I ! 4 68 0000000000 o 3 1 1 4 68 00000000o0 o 3 1 ! 4 6~ o000000000 0 3 I I 4 68 0000000000 o 3 1 i 4 68 oo00000000 0 3 ! 1 4 68 0000000000 o 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 6~ 0000000000 o ~ 1 1 4 68 oo0o000ooo 0 3 i I 4 68 oOo0o00000 0 3 1 ! 4 6~ 0000000000 o 3 I ! 4 68 0000000000 0 ~ ! 1 4 68 00o0000000 0 3 ! ! 4 68 0000000000 0 3 I I 4 6~ 0000000000 0 3 1 1 4 68 0000000000 0 3 1 ~ 4 68 0000000000 o 3 1 I 4 68 0000000000 a 3 1 1 4 68 0000000000 o 3 I 1 4 68 o00oo0000o o 3 1 1 4 68 0000000000 o 3 1 I 4 68 0000000000 o 3 1 1 4 68 0000000000 0 3 1 1 4 68 O000000000 o 3 1 1 4 68 o000000000 DEPT. 9790,000 DT, TT3. BH~ 631. gO0 TT4. ~TEV,EHR !.70.375 L!,D. PLR ! 2to6.56o GR. ?'~JP~. Cb:R 29.665 T~JRA. RCFT.C~ 945.533 CaTC, YFr.~S. C~ ~ 5430.000 ~S. DEPT. 9700.000 BT. TTB.BHP 607.500 TT4. LLD.DLP 6.2g4 BNR 5HR DLR DI,R CNR C~R C~R DL 99.000 TT1.BHR 632.000 TT2.BH~ 431.500 GR. ,~SH~ 49.781 0.074 HTE~, 5H~ 832,500 LLS.DLR 49,781 TENS, [)LR 5430 000 .gTE~. DLR 032,500 ~!~H! .CNR 29:459 RTN'R.CNR 2,703 NPOR. C~,{R 29.665 RC~T.CNR 2605,297 CFTC.CNR 976.655 GR.C~iR 0,074 ~4 TE"~, C~q R !70.375 HTEt,!. C~ ~ 9~..000 TTlo}'~ 608.~00 TT2.BNR 412,250 GR.BHR 29,734 TENS.BHR 0.074 HTE~!.SNR 1!81.000 LLS.DbR 29.734 TENS.DLR 5940.000 ~TE~.DLR 435.500 5430 000 9 16oo 170.375 2.871 2753.889 49.781 832.500 415,000 5940.000 5,500 170,500 ooo'8~Ei gLS'LOE L6~'006[ LIL'£ ~9'OL'[ 000'0809 000'§[~ O0~6g ~E6 ~0 sgg,§L[ O00'OEi9 00§'~9~ O0O'tOg'[ 896'E86E 00~'~ 000'00~9 O~L'~O~ 000'0~6S O~L'~E 000';8it t69" ~qO'~qq S~9'OL[ ~0'~8~ 000'0809 O0OiSggI SL8 LOE 000 L6§ 99't'5~ 000'0[I9 000'~89 Sag'IL'[ SSL'iLaI' OuO'O019 O00'IO~i ~60'1~ OOS'SL~ §Eg'iLt 08E'6i IOL'O[ O00'Of6S O00'~ii S~9'98 000'68~ L~9 aN3'DZA~ 869°£99I ~ND'8OdN L~L°E aH~*~Z~ EgS 80t ~ND'aOda 8T~'~ LO~ t 0(: : ,, 00§'8 0°008I 0"8800'J O'OOEO O'SOIO[ 0'9010[ iii ~'BE dj 3(iNO~ DiNOS 3qOt4~O~ · sot';~ ~a~a~¢as ut unz pue 'buIa~s IOO~ 'ssed q~eo ao~ e~ep ~opeaq ~,ol puc sa^~t'tj 9I ~39~d · 0'09 60g'O 0'09 tLI'O 0'09 80g'O 0 ' O~ 9 0~'6 00'9§ 08'6 qD~ 0'8f98 LO:80 E66I-aV~-[I ,IS Tame verification [,ist~i. no chll.!mberqer A.,!,,as~a Com[~uti.n.d center !3-~AR-1993 0~:07 PAGE: ** SET TYPE - CgAN ** ............ 0CE$8 ID O~DE~ # LOC TYPE CLASS ~OD ~II~8 SA~P ELE~ CODE (HEX) ~:~'~' ~T 61e0~4 OD o00 OD o 4 i l, 4 ~8 0oo0oo0000 ~ csc a~p~ ~l~o~4 oD ooo OD o 4 1 ~ 4 6~ oooooooooo T~s CSt ~ athos4 ~o ooo oD o ~ I 1 ~ 6~ oooooooooo ~s cs~ oH~ ~i9o~4 oo oho oo o 4 ~ 1 4 6~ oooooooooo ~TE~ CSG OEGF 61903,4 On 000 on 0 4 ~ I 4 SS 0000000000 ~T~:~ CSt ~ ..... 6190~4 OD o0~ 00 o 4 1 I 4 ~8 000o~00000 g)EPT. 94o0.00(~ G~ CSG 292.500 TENS.CSG 6130 000 ~ES.CSC D~P,, ~300,000 GR cSC . ~ 21.7 625 TE~S.CSG 5970 O00 ~T~;~.CSG 169.~75 ~IT~N. 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