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Home My WebLink About194-163 STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMIS! REPORT OF SUNDRY WELL OPERATIONS % 1. Operations Performed Abandon ❑ Plug Perforations Q Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Po5#5ffylft/ // 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 194-163 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20652-01-00 7. Property Designation(Lease Number): ADL 0028281 8. Well Name and Number: PBU F-17A 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: RECEIVED Total Depth: measured 12300 feet Plugs measured See Attachment feet CEN 2016 true vertical 9054 feet Junk measured 10431 feet J 0 8 Effective Depth: measured 10315 feet Packer measured 9781 feet AOGCC true vertical 8807 feet Packer true vertical 8300.71 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x30" 30-110 30-110 Surface 2695 13-3/8"72#L-80 29-2724 29-2712 4930 2670 Intermediate 8452 9-5/8"47#L-80 27-8479 27-7083 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10005-10015 feet 10015-10035 feet 11185-11460 feet 11482-11502 feet 11502-11522 feet 11522-11542 feet 11542-11562 feet 11738-11758 feet 11850-12200 feet True vertical depth: 8515-8525 feet feet 8525-8544 feet 9053-9051 feet 9050-9050 feet 9050-9049 feet 9049-9048 feet 9048-9048 feet 9045-9046 feet 9047-9052 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 25-9868 25-8384 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: -Lb' .. LI,IZ SCANNED 1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 365 28298 72 680 1023 Subsequent to operation: 253 2031 8 180 859 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q 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 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature rge44,17 (j Phone +1 907 564 4424 Date 9/8/16 Form 10-404 Revised 5/2015 V7-L 4/za/I c- . ,� �� RBDMS -V SEP 12 2016 Submit Original Only • Plugs Attachment 205-081-0 SW Name Date MD Description F-17A 08/12/2016 10314.7 Set Cement Plug F-17A 08/12/2016 10324 Set Posiset Plug • a oOOOOO CNO N- (O v— N O O U) O N r LO N - U N o O o 0 0 0 L M N - 0 CO CO M 03 CO C Ca Nr (0 CO CO CO O S CO N (0 LC) CO 0) O O CO N N- co O) W co I- Lo r- o O O) N CO M 0 CO N N LU 6) 6) N (.0 O 00 W O o) 0 0 CO � CO N 00 M 0 00 N CO CO O— A O v o 2 Q < ti Lf) 0 0 O) N- n LO M N N N- N c N N- CO W H acoO O O co 00 coU co 0o J co .N N X N- 4 *k �# (V (O - CO O)RS v N U O 0O CO N N _ LO a LO N LO N COO O7 LO `- co Nrct CO CO V In LO CO co J N co Lf) N O) w CF- 11NI 715 U w 0 O Ni ctNY NY NY z Z w w w w w m 0DH-- z_ _zzD UcnZJJJ �- • • Packers and SSV's Attachment PBU F-17A SW Name Type MD TVD Depscription F-17A PACKER 7714.51 6525.03 7" Baker ZXP Top Packer F-17A PACKER 8286.11 6937.52 7" TIW Liner Top PKR F-17A TBG PACKER 9781.42 8300.71 4-1/2" Baker S-3 Perm Packer F-17A PACKER 10465.83 8935.19 5-1/2" H Isolation Packer • • • W � 0 J - >- I� >., M Cl) m J m M O _ O 2 0 Z . a- C7 M a a O O F- 2 O O W J Y \ J LL J • cpo .a) D CC LU II � O 0 >>w o O a F- I 0 Q > H z a. 2 oa Li_0 Q Q >- 2 � � oI U) a. 0 0 a. ,e(n - ,_ ZO a_ a_ 0 U) LO _o a Fz11 (n < 0 F- U F- X II 0 CC o 0 0 U il aoo � � ~ 0 W QFF" a W0 a � � � U w ao � w c75owUw0 Cl) w W .� a i- • 0 O z o o a. 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F, ,_ U) CCa- I- i _ IO W o ° = 0 � bQULLj � zzZD � � J � � � � oau' z II a (nmMJOw pUzzN 2MZ0H C� 00002N2_ UIQ2 2 JUJU' 0OO _J 1- JN o YU) F>_ O — W OC9OWUU1- r II Uria_ i _ E < 89W � 0 W 7 J II C W Q -I Q > a' 0 (7 ~ O Z ~m m W N M N r (>J 0 -I z H J m W W II N .� * Eg * 0 °' c * ziw2a00 � U)W W WDCCpccNiDmD W W WazO I' 0 U) : F\- E =1 : - J 0 a' 0 LL a' F- Q : U a' J a' I1 a' W a' a' r a: H Q it .*k W F- pc0 >- O IS O F N N N ON 5_ � N H 0 co _ CB 0-5 Q N > C � _o Ct E a) eL a) (A o 0 Q LL 0 O m a a a, 0) .c y_ D O c c • E - a) U c o W ' O c0 N CO U' m TTS= • SON NOTES: WELL ANKLE>70" 10667' = WELLHEADFMC "'4-1/2 CHROME TUBIN(i"'SLICKL}t4E(WHILE ON ACTUATOR= BAKER C D-16)WAS ABLE TO DRIFT THRU RSH(5" BF.ELEV= 38.96 -1 7A WASHPIPE)DURING 2/2008 RWO"•CHROME KOP= 2300' NPPI FS*** Max Angie= 95°@ 10959' I Datum MD= 10380' I ' 2055' —{4-1/2- HES X NP,D=3.813" Datum ND= 8800'SS GAS LFT MANDRELS 13-3/8"CSG,72#,L-80 BTRS,D=12.347" --I 2720' ST MD ND DEV TYPE VLV LATCH PORT DATE 13 2 3553 3457 37 MNG DMY RK 0 11/03/09 1 6674 5767 44 MNG DMY RK 0 11/03/09 Minimum ID = 3.813" @ 2055' 4-1/2" H E S X NIPPLE — 7712' -19-5/8"X 7"BKR HR ZXP LIP,D-6.22" It' 7 7734' —I 9-5/8'X 7"BKR HMC LNR HGR D=6.300" TOP OF TMl 7"LAR -- 8277' 8277' —{9-518"X 7"LTPw/TEEBACK SLV,D=6.210" y PERFORATION SUMMARY • r REF LOG: ? 1 1 8290' H 9-5/8"X 7"TMl LNR HGR ID=6.168" I ANGLE AT TOP FERE:91°(©1185' • Note:Refer to Production DB for historical pert data • MLLOUT yya OW(F-17A)8478'-8528' SIZE SPF NTER1/AL Opn/Sqz DATE • 2-1/2' 6 10005-10035 ' 0 08/12/16 • • 2-3/4" 4 11185-11460 C 03/18/95 I7 9748' —14-1/2-HES X NP,D=3.813" 2-1/2' 4 11482-11562 C 03/18/95 • 2-1/2" 4 11738-11758 C 09/21/95 9779' Hr X 4-1/2"BKR S-3 2-3/4" 4 11850-12200 C 09/21/95 •1•' PKR D=3.875' •1.111 9853' H4-1/2"HES X NP,D=3.813' MS 14•C �i 9865' —14-1/2"WLEG,D=3.958"? 9-5/8"CSG,47#,L-80 BTRS,D=8.681" 10317' �i 10315'ELM H TOP OF CMT CAP(08/12/16) 10324'ELM H 7'FOSISET PLUG(08/12/16) ` 10374'-10408' --WASHRFE ASH,5.75"OD X 5.00" 4-1/2"TBG,12.6#,13CR VAM TOP, 9865' ^ D w/4.75'D SHOE(02/08/08) .0152 bpf,D=3.958" 410"-, PV',---.°111i�1♦ 10431' H TOP OF 3-1/2"TALFIFE ASH 10458' H BOTTOM OF 3-1/2"TALPPE FISH 3-112"WLEG(2/11/08) 3-1/2"X NP w/2.750"BORE 10435' A 10470' —I HAD TT LOGGED 02/02/95 3-1/2"x NPw/2.750"BORE —I 10447' A10458' —7"X 4-1/2"BKR C-2 SETTING SLV,ID=5.250" .44 110465' —T X 4-1/2'BKR'H'ISOLATION PKR,ID=4.313" 10470' —7'X 4-1/2"BKR FLEX LOCK HGR,C=4.469' 7"LTC,29#,L-80 NSOC,.0371 bpf,D=6.184" --I 10812' 1% FBTD —{ 12214' ..4•••• •••�••'' 4-1/2"LNR, 12.6#,L-80 NSCT,.0152 bpf,D=3.958" —{ 12300' DATE REV BY COMMENTS DATE REV BY COMvENTS F X)HOE BAY MT ?? ORIGINAL COMPLETION 11/06/09 DMS/SV GLV C/O WELL: F-17A 01/16/95 MDO SIDETRACK(F-17A) 08/12/16 DHS/TLH PERF,PLUG SET,CMT CAP pERMTNo:'1941630 02/02/95 DTR RWO API No: 50-029-20652-01 02/13/08 D16 MVO SEC 2,T11 N,R13E,2215 FSL&2197'FEL 03/10/08 DAV/PJC GLV CIO(02/27/08) 05/05/09 FR/JMD DRLG DRAFT CORRECTIONS BP Exploration(Alaska) UNDER EVALUATION: F-17A~TD #1941630) Sustained Casing Press~ due to TxI... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~/~, ~~ I~~~c~ ~> Sent: Thursday, October 29, 2009 7:41 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Isakson, Shawn Cc: Williams, Carrie; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: F-17A (PTD #1941630) Sustained Casing Pressure due to TxIA Comm Attachments: F-17A.pdf; F-17A TIO Plot.doc •~ AI I, / Well F-17A (PTD #1941630) has beerr found to have sustained casing pressure due to 7xIA communication. A TIFL failed on 10/27/09 when wellhead pressures were tubing/IA/OA equal to 2330/2340/0. The we has been reclassified as Under Evaluation and may remain on line with further diagnostics are being conducted. The plan forward is to: 1. DHD: TIFL - FAILED on overnight build-up rate 2. Slickline: Change out GLVs ~ 3. DHD: Re-TIFL or Fullbore: MITIA A welibore schematice and TIO plot have been included for reference. «F-17A.pdf» «F-17A TIO Plot.doc» ~ Please let us know if there are any questions. Thank you, Anna ~u6e, ~.~. ~alt Torin Roschinger) iNe1! Integrmty Coardinatar GPB Vldells Group i ;! ~, ~ ~~~~ Phott~: (907) 659-5102 z~iaw~~~' ~``'~ ' Pager: {907j 659-5100 x1'154 11 /9/2009 PBU F-17A PTD #1941630 10-29-09 TIO Pressures Plot ai~o~_ ~- I I j ~ I I 3.000 li 2,000 i ~ _ ' ____~,_ _ _~r, 1,000 r~eioiros oe!oei~ aa~isros oarzzros ~sizsros osrosio9 os~izios o~n~a9 iorovos iaioros iai~ios iazaos -~- T6g ~- IA -~ OA OOA - ~- OOOA ~ On ~ • 7REE _ C~ ~ ~~~ ~~ SAF~TES: W ELL ANGLE > 70° @ 10667' ***4-1 HROMETUBINC~"°*S~ICKLINE{WHI~EON D-16) WAS ABLE TO DRIFf THFtU F1SH (5" WASHPIPE) DURING2/2QQ8 F2W0***CHROME NIPPLES"** 2055' 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MRNDRElS WELLHEAQ = FMC ACTUATOR = BAKER C KB. ELEV = BF. ELEV = 65.6' 38.95' KOP = 2300' Max Angle - 95° @ 1U959' Datum MD = 10380' DatumND= 8840'SS ~ 13-318" CSG, 72#, L-80 BTRS, IR = 12.347" ~--~ 2720' nn~n~mum iD = ~.s1~~° @ ~a~s~ ~-1i2" HE5 X NIPPLE I TOP OF TlW 7" LNR I PERFORATION SUMMARY REF LOG: ? ANG~E AT TOP PERF: 91" @ 11185' Note : Refer ta Production DB far historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3l4" 4 11185 - 11460 O 03/18/95 2-1/2" 4 11482 - 11562 O 03/18/95 2-1/2" 4 1173& - 11758 O 09121/95 2-3/4'" 4 11850 - 12200 O 09121/95 -- _ _ ___ _ 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" 10317~ 4-1i2" TBG, 12.6#, 13CR VAM TQP.. ,0152 bpf, ID = 3.958" 9865' 3-~ /2" X NIP w/2.750" BORE ~ 10435' ~ 3-1/2" X NiPw/2.75Q" BORE 10447' 7" LNR, 29#, L-80 NSCC, .0371 bpf, ID = 6.184" +-) 1081 PF3TD I--I 12214' 4-1l2" INR, 12.6#, L-80 NSGT, .0152 bpf, ID = 3.958" I--j 12300~ ST MD ND DEV TYPE VLV LATCH FORT DATE 2 1 3553 6674 3456 5767 37 44 MMG MMG DOME SO RK RK 16 20 p2/27/08 02l27l08 7712' 9-5/8" X 7'° BKR HR ZXP LTP, ID - 6.22" 7734' -~9-5/8" X 7" BKR MMC LNR HGR, !D = 6.30Q" ' $277' 9-5/8" X 7" LTP w/i"IEBACK SLV, ID = 6.210" $~JQ' 9-518" X 7" TNV LNR HGR, ID = 6.168" MILL(7UT WINDOW (F-'17A) 8478` - $528' ~ 9748' 4-1/2" HES X NIP, ID = 3.813" ~,~- -- ~77~' 7" X 4-1/2"BKR S-3 PKR, ID = 3.875" gg~3' 4-1 t2" HES X NIP, fD = 3.813" J$~~' 4-1l2" WLEG, ID = 3.958"? 10374'-'~0~4$~ WASHPIPE FISH, 5.75" OD X 5.00" ~ Id w /4.75" ID SHOE (~2/08J08) 10431~ TOP OF 3-1i2" TAILPIPE FISH '~Q45$' BOTTOM OF 3-1/2" TAILPIPE FISH, 3-1l2" WLEG (2/11/08) 10470' ELMD Tf LOGGED 02/02/95 10458~ 7" X 4-1/2" BKR G2 SEl"TlNG SGV, ID = 5.250" '10465` 7" X 4-1i2" BKR "N" ISQLATION PKR, ID = 4.313" ~ 10470' 7" X 4-1/2" BKR FLDC LOCK HGR, ID = 4.469" DATE REV BY CC7MMENTS DATE ' ?? ORIGINAL COM PLETION ' 01(16195 MDO SIDE7F2ACK(F-17A) Q2/02/95 DTR RWO 02/13/OS D16 RWO 03?10/48 DAV/PJC GLV C/O (02/27108) 05/05/09 FR(JMD DRLG ~RAFT CdRRECTIONS PRUDMOE BAY UNfT WELI: F-17A PERMIT No: ~1941630 API No: 50-Q29-20652-a1 SEC 2, T11 N, R13E, 2215' FSL & 2197' FEL BP F~cpioration (Alaska) -- STATE OF ALASKA ~~~ ~ti.+-~I X G® A~ OIL AND GAS CONSERVATION COM~SSION REPORT OF SUNDRY WELL OPERATIONS MARX 3 2008 1. Operations Performed: ~ ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Su sp nde ell Alter Casing~7Y,,.~~ ~J?UII Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Dritl Number: BP Exploration (Alaska) Inc. ®Development• ^ Exploratory 194-163 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20652-01-00 ' 7. KB Elevation (ft): 65.58' ~ 9• Well Name and Number: P BU F-17A ' 8. Property Designation: 10. Field /Pool(s): ADL 028281 ' Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 12300- feet true vertical 9054 feet Plugs (measured) None Effective depth: measured 12214 feet Junk (measured) 10374' - 10458' true vertical 9052 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' Surface 110' 110' Surface 2720' 13-3/8" 2720' 2708' 4930 2670 Intermediate 8478' 9-5/8" 8478' 7082' 6870 4760 Production Liner 2535' 7" 8277' - 10812' 6931' - 9068' 8160 7020 Liner 1842' 4-1/2" 10458' - 12300' 8929' - 9054' 8430 7500 Scab Liner 551' 7" 7712' - 8263' 6523' - 6920' Perforation Depth MD (ft): 11185' - 12200' ~~a~~ell~~ A~~ ~' ~ ~~~~ Perforation Depth TVD (ft): 9053' - 9052' 4-1/2", 12.6# 13Cr80 9865' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packer 9779' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing from 10431'. Run 7" scab liner, cem ent w/ 31 Bbls Class'G' (174 cu ft / 150 sx). Left washpipe fish and 3-1/2" tail i e fish in the hole, unable to retrieve. Ran new com letion. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A if C.O. Exempt: Contact Frank Roach, 564-4373 308-008 Printed Name Terrie Hubble Title Drilling Technologist ~ Prepared By Name/Number: Signature Phone 564-4628 Date ~ ~ Terrie Hubble, 564-4628 _:~_. Form 10-404 Revised 04/2006 _ ~~ Submit Original Only TREE= 3-1(8" FMC (W-4" QU) WELLHEAD = FMC ACTUATOR= BAKER KB. ELEV = 65.6' BF. ELEV = 38.96' KOP = 2300' Max Angle = 95 @ 10959' Datum MD = 10381 Datum TV D = 8800' SS DRLG DRAFT 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-~ 2720' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3553 6674 3456 5767 37 44 MMG MMG DOME SO RK RK 16 20 02/27/08 02/27108 7" LNR, 26#; L-80„ .0382 bpf, ID = 6.276" ~ 7711' TCOP OF TIW 7" LNR $277' Minimum ID = 2.750" @ 2033' OTIS HXO SSSV NIPPLE PERFORATION SUMMARY REF LOG: ? ANGLE AT TOP PERF: 91 @ 11185' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 4 11185 - 11460 O 03!18/95 2-112" 4 11482 - 11562 O 03!18/95 2-1/2" 4 11738 - 11758 O 09/21/95 2-314" 4 11850 - 12200 O 09/21 /95 SAFETY NOTES: HORIZ. WELL, 70° @ 10667' AND 90° @ 10803' ***4-1 /2" CHROME TBG*** F 17A SLICKLINE (WHILE ON DOYON 16) WAS ABLETO ~ DRIFT THRU FlSH (5" WASHPIPE) DURING 2!2008 RW O 4-1/2" TBG, 12.6#, 13Cr-80 Vam Top, .0152 bpf; iD = 3.958" ~-1 9865' {~ 3-112" X-Nipple w ith 2.750" Bore 10435' 3-1/2" X-Nipple w ith 2.750" Bore 10447' TOP OF 4-112" liner 10465' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" PBTD (-{ 1 4-1/2" LNR, 12,6#, L-80, .0152 bpf, ID = 3.958" 2055' ~-(4-112" HES X NIP, ID = 3.813" 7711' ~-{ 9-5/8" X 7" BKR C-2 ZXP LTP w / FLEXLOCK LNR HGR, ID = 6.290" MILLOUT WINDOW (F-17A) 8475' - 8528' 9748' 4-1/2" HES X NIP, ID = 3.813" 9778' 7" X 4-1/2" BKR S-3 PKR ID = 3.875" 9853' 4-1 /2" HES X NIP, ID 3.813" 9865' 4-112" WLEG 10374'-10408' WASHPIPE FISH, 5.75" OD x 5.00" IC w / 4.75" ID SHOE (02108108) 10431' Top of 3-112" Tailpipe Fish 10458' Bottom of 3-1/2" Tailpipe Fish 3-1/2" WLEG 10470' ELMD TT LOGGED 02(02/95 10465' 4-1/2" BKR ISOLATION ~ PKR, ID = ? PRUDHOE BAY UNff WELL: F-17A PERMff No: 1941630 API No: 50-029-20652-01 SEC 2, T11 N, R13E, 2215' FSL & 2197' FEL BP Exploration (Alaska) DATE REV BY COMMENTS DATE REV BY COMMENTS ??? ORIGINAL COMPLETION 03/10/08 DAV7PJC GLV C/O (02!27/08) 01/18/95 MDO SIDETRACK(F-17A) 02/02/95 DTR RWO 04101!07 JMF/PJC 5ET PX PLUG @ 10395' (10!31/06) 02/13/08 D16 RWO 02/17108 /TLH UPDATES I~I.V~~I~~ile ~ ~ Page 1 of 1 .Well History Well Date Summary F-17A 12/30/2007 ***WELL S/I ON ARRIVAL*** (pre rwo) PU D "P" Fn-PR(1NC; FRC1M PX PI I1G BODY AT 10395' Mr1 RIH W/ 3-1/2" GR TO PULL PLUG BODY - IN PROGRESS. ****CONT JOB ON 12-31-07**** F-17A 12/31/2007 ****CONT JOB FROM 12-31-07**** ATTEMPTIN -. TO PL11 1 3.1/9" Px PI u[, RnDY (4 HOURS JARRING). RAN 2-1/4" PUMP BAILER IN ATTEMPT TO UNPLUG PORTS IN PLUG BODY. RECOVERED NO FILL IN BAILER & NO CHANGES IN TBG PSI, FL STILL AT SURFACE. ***CONT ON 01-01-2008 WSR*** F-17A 1/1/2008 ****CONT JOB FROM 12-31-07****( pre-rwo ) PULL 3 1/ " PX PI I11; R(~f)V FROM 10395' MD RIH W/3-1/2" BRUSH, 2.65" G.RING THROUGH X NIPPLE ~ 10434' MD SET -1 UG BODY ~ 10434' MD 4 x 3/16" E P T RUN CHECK SET TO 10434' MD. GO ET ****HIGH WINDS START WEATHER TICKET**** F-17A 1/3/2008 ***WELL SHUT IN ON ARRIVAL*** SET EO PRONG INTO PLUG BODY, TOP OF PRONG AT 10,417'SLM. MIRU LRS TO PRESSURE TEST 3-~~"~XTT~~L~Z; TAT 10,434' MD. ***CONT WSR ON 1/4/08*** F-17A 1/3/2008 T/I/O = 120/80/0 Temp = S/I - Assist slickline MIT T to 1500 psi (RWO prep) Pumped 18 bbls 100* crude down TBG. *** Job continued on 01/04/08 WSR *** F-17A 1/4/2008 ***CONT. WSR FROM 1/3/07*** LRS MIT-T TO 1500# (PASSED) ***RDMO, LEFT WELL SHUT IN AND TURNED OVER TO DSO*** F-17A 1/4/2008 *** Job continued from 01-03-08 WSR *** Assist slickline - MIT T PASSED to 1500 psi (RWO prep) -Pressured up TBG to 1500 psi w/7 bbls crude (25 total) -TBG lost 80 psi in 1st 15 min and 20 psi in 2nd 15 min for a total loss of 100 psi in 30 min test. Bled TBG to starting pressure. FWP's = 150/100/0 *** Casing valves open to guages, tags hung *** F-17A 1/6/2008 ***WELL SHUT-IN ON ARRIVAL*** INITIAL WHP 150/250/0 JET CUT 3 1/2" TUBING WITH 2.5" POWERCUTTER. CUT TUBING AT 10,398', IN TOP 2' OF PUP AB VE PACKER AT 10409'. LEFT WELL SHUT IN. FINAL WHP 100/260/0 ***JOB COMPLETE*** F-17A 1/16/2008 Circ out Tx IA, MIT OA to 2000 psi. (Pre RWO) ***Job Postponed due to unavailability of heater*** F-17A 1/16/2008 T/I/0=750/740/20 Circ Out, MITOA (continued on 01/17/08) F-17A 1/17/2008 ***continued from 1/16/08*** Circ Out, MST OA PASSED to 200~0 )si (Pre-RWO) Pump 5 bbl meoh spear ~ followed by 1013 bbls 9.8 NaCI brine down bg to ing rem IA to flowlijne. Freeze protected well w/ 45 bbls diesel to 500 ft. Freeze protected flowline w/ WOA recipe. MIT-OA to 2000 psi.. Pumped 2.1 bbls crude OA to achieve test pressure. 2nd test. OA lost 20 psi 1st 15 mins, OA lost 0 psi 2nd 15 mins for a total of 20 psi in 30 mins. Bled all pressures back to Opsi. FWHP= 0/0/0 Annulus casing valves open and tagged well. F-17A 1/19/2008 T=0 Set 3" CIW BPV H plug Pre rig for Doyon 16 D_id set 3" CIW BPV H plug #311 ~ 111" ... no problems Print Date: 3/12/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 3/12/2008 • A BP EXPLORATION Operations Summary Report Page 1 of 21 Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours .Task Code' NPT j Phase Description of Operations 1/19/2008 15:00 - 17:00 2.00 MOB P PRE PJSM. Move off of DS 14-29 and stage rig to UD Derrick. 17:00 - 19:00 2.00 RIGD P PRE Install BOPE on traveling stand. Remove CMT line from cellar for repairs. 19:00 - 20:30 1.50 RIGD P PRE PJSM. R/D rig floor. Lower derrick and secure for rig move. 20:30 - 00:00 3.50 MOB N WAIT PRE Wait on F-Pad operator to give OK to start rig move. Install derrick kickover rams and other maintenance jobs on rig. 1/20/2008 00:00 - 08:00 8.00 MOB N WAIT PRE Got OK from F-Pad operator to move. Wait on security to give OK. Lower cellar doors. Inspect crown sheaves and service same. Continue maintenance jobs on rig. 08:00 - 15:30 7.50 MOB P PRE Security arrived on location for escorting rig to F-Pad. Start rig move from DS-14. Rig at BOC at 12:00 hrs. Arrive on F-Pad at 15:30 hrs. 15:30 - 17:00 1.50 RIGU P PRE Position rig to raise derrick and spot rig. Remove rear booster wheels. 17:00 - 19:30 2.50 RIGU P PRE Install new CMT line in cellar. 19:30 - 21:00 1.50 RIGU P PRE PJSM. Raise derrick and pin in place. 21:00 - 00:00 3.00 RIGU N WAIT PRE Wait on pad prep. R/U rig floor and mud manifold. Install BOPE in cellar. Bridle down. 1/21/2008 X00:00-12:00 12:00 - 18:00 18:00 - 00:00 12.00 MOB N WAIT PRE Continue waiting on pad prep. Continue small maintenance jobs around rig. Hang bridle lines. Replace bladder in pipe skate accumulator bottle. 6.00 MOB N WAIT PRE Continue waiting on F-17A pad preparation. Lay down Herculite 6.001 MOB I P 1/22/2008 00:00 - 00:30 0.50 MOB P 00:30 - 02:00 1.50 WHSUR P 02:00 - 03:00 1.00 WHSUR P 03:00 - 05:30 2.50 WHSUR P 05:30 - 06:30 1.00 WHSUR P 06:30 - 08:30 2.00 WHSUR P 08:30 - 09:30 I 1.001 WHSUR I P 09:30 - 14:00 4.50 BOPSU P 14:00 - 14:30 0.50 BOPSU P 14:30 - 19:00 4.50 BOPSU P 19:00 - 21:30 2.50 BOPSU N 21:30 - 22:00 22:00 - 22:30 22:30 - 00:00 0.50 BOPSU~P 0.50 PULL P 1.50 PULL P 1 /23/2008 ~ 00:00 - 00:30 0.501 PULL P around well cellar. UD double rig mats. PRE PJSM. Check tree and wellhead for pressure. No pressure on OA, IA, or Tubing. P/U and move rig onto well slot F-17A. him an se rig own. Spot slop tank and #2 pump in position. R/U Circulating lines. Accept rig at 24:00 hrs 1 /22/08. PRE Accept Rig 00:00 hrs. P/U DSM tools and equipment. DECOMP Pre Spud Meeting. P/U, install lubricator and test to 500-psi. Pull BPV. R/D lubricator. oad pits with 9.8 ppg NaCI brine. DECOMP R/U lines to circu ate ou iesel freeze protect fluid. Test surface circulating equipment to 3500 psi. Good test. DECOMP Reverse circulate 60-Bbls of hot 9.8-ppg NaCI brine at 6-BPH with 870-psi. Realign valves and circulate 675-Bbls of hot 9.8-ppg NaCI brine at 7-BPM with 1370-psi. DECOMP Monitor well for flow. No flow on IA or tubing. DECOMP Set TWC. Test from Above to 3500 si for 10 ' Below for 10 mins; Good Test. DECOMP PJSM; Nipple Down Tree and Adapter Flange, close Hydrualic Valve and Bleed Off Pressure. DECOMP N/U BOPE. DECOMP Rig Up to Test BOPE DECOMP Test BOPE E ui ment. Pressure Test all Components to 250 psi low and 3500 psi high for 5 mins. Test witness waived by John Crisp with AOGCC. Blind Rams Failed Pressure Test SFAL DECOMP C/O Blind Shear Rams for Blind Rams. Re-Test Rams to 250 psi low and 3500 psi high for 5 mins. Good Test. DECOMP Rig Down Testing Equipment. DECOMP Rig Up Tubing Handling Equipment. DECOMP P/U Lubricator Extension and Lubricator. Test 500 psi. Pull TWC. DECOMP UD DSM Lubricator and Lubricator Extension. Printed: 2/27/2008 2:57:42 PM • BP EXPLORATION Page 2 of 21 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: F-17A F-17A WORKOVER DOYON DRILLING INC DOYON 16 Spud Date: 12/29/1994 Start: 1 /19/2008 End: Rig Release: 2/13/2008 Rig Number: Phase Description of Operations DECOMP P/U and M/U 3-1/2" TDS XO to Jt of DP. Screw into Hanger with 10 right hand turns. M/U to Top Drive. BOLDS. Pull Hanger Free at 127,000 Ibs Up Wt. Continue to pull hanger to floor at 123,000 Ibs Up Wt. DECOMP C a pm an psi, no gas or oil seen in returns. DECOMP UD Tbg Hanger and secure well. DECOMP Weather Conditions -Very Low Visibility, Blowing Snow and Winds in excess of 55 mph. Secure well and Stand Down until weather improves. DECOMP Weather on i ions -Very Low Visibility with Phase 3 conditions, Blowing Snow and Winds in excess of 65 mph. Stand Down until weather improves. Weather starting to improve. Able to change out rig crews at 21:00 to 22:00 hrs while coordinating with IMT and with heavy equipment escort. DECOMP Weather starting to improve. Able to change out rig crews at 21:00 to 22:00 hrs while coordinating with IMT and with heavy equipment escort. DECOMP Weather Conditions improving. Phase 3 conditions lowered to Phase 2 on main roads and Level 3 on access roads and pads, emergency and critical travel only. All other travel to be coordinated with IMT. Rig still in stand down status. DECOMP Weather conditions improving. Phase 2 driving conditions on main roads, but Level 3 (critical and emergency travel only) still in effect on access roads and pads. Rig soil in stand down status due to necessary personnel getting to location. Make contact with Roads and Pads Supervisor to allow travel to F-Pad at 01:00 hrs. Permission denied. IMT not available to coordinate travel. DECOMP R/U and prepare to CBU. Permission given through IMT to continue work on F-Pad and use Access Road ~ 0445 hrs. DECOMP CBU at 11.2 bpm with 0 psi. DECOMP Monitor well. R/D Circ Equipment and PJSM on Pulling Tubing. DECOMP P OH and UD 3-1/2" 9.2# L-80 Com letion and 1/4" Dual Control Lines. UD First 63 Joints and SSSV. Recovered 66 of 67 SS Bands. Tubing showed minor interior corrosion and mild damage to nose ends of the pins. Outside of the tubing was in good shape very little scale and some light paraffin. Recovered all the control line. DECOMP Continue to POOH and UD Tbg. Found very small holes in the tbg in Jts #79, 83, 84, 85, 86, 87 & 89. Holes were due to internal corrosion and would have not been noticed except for ', fluid leaking out of them. Pin ends were chewed up slightly on the noses. Very little scale was seen a few spots down around the cut joint but very spotty at most, UD a total of 326 joint of tbg, 2 GLM's, 1 SSSV, and 1 SWS Nipple. The let cut was ~ very uniform ins ape, wit a sma e a e end. The bell measured 4" OD across its widest spot. The cut was made 1.53' below the SWS nipple leaving -8.15' of 3-i/2" tbg looking up above the 4-1/2" x 3-1/2" XO. DECOMP Rig down tbg handling equipment and R/U to pressure test casing. DECOMP Pressure test casing. Stage up pressure in 500 psi Date From - To ~ Hours I Task !Code ! NPT ~ 1/23/2008 00:30 - 01:00 0.50 PULL ~ P 01:00 - 02:30 1.50 PULL P 02:30 - 03:00 0.50 PULL P 03:00 - 06:00 3.00 PULL N WAIT 06:00 - 20:00 I 14.00 I PULL I N I WAIT 20:00 - 22:00 I 2.001 PULL I N I WAIT 22:00 - 00:00 2.00 PULL N WAIT 1/24/2008 100:00 - 04:30 I 4.501 PULL I N I WAIT 04:30 - 05:00 I 0.501 PULL I P 05:00 - 06:00 1.00 PULL P 06:00 - 06:30 0.50 PULL P 06:30 - 09:00 2.501 PULL P 09:00 - 17:00 8.00 PULL I P 17:00 - 18:00 I 1.00 I PULL I P 18:00 - 19:00 I 1.00 I EVAL I P Printed: 2/27/2008 2:57:42 PM • • BP EXPLORATION Page 3 of 21 ', Operations Summary Report Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task ,Code NPT ' Phase Description of Operations 1/24/2008 18:00 - 19:00 1.00 EVAL P DECOMP increments. Casing tested solid up through 2000 psi. Pressured u to 2500 si where ressure bled off 175 si in 12 minutes. Attempt to bring pressure up to 3000 asi. Obtain an in'ection rate at 0.8 BPM with 2650 psi. Shut in and monitored 19:00 - 20:00 1.00 FISH P DECOMP R/U floor and bring Baker 3-/12" TBG Dress Off Assembly to rig floor. 20:00 - 21:30 1.50 FISH P DECOMP P/U BHA #1 (3-1/2" TBG Dress Off Milling Assembly) consisting of dress off shoe, wash pipe with dress off mill inside, boot basket, x/o, 7" scraper, bit sub, bumper sub, jars, pump out sub, x/o, (9) 4-3/4" drill collars, 58 joints of 4" HT-38 drill pipe, x/o subs, 9-5/8" scraper, x/o to 4" HT-38 drill pipe. Total Length of BHA #1- 2168.4' 21:30 - 00:00 2.50 FISH P DECOMP P/U and RIH with BHA #1 on 4" HT-38 drill pipe from pipe shed. 1/25/2008 00:00 - 07:30 7.50 FISH P DECOMP Continue to P/U and RIH with BHA #1 on 4" HT-38 drill pipe from pipe shed. 07:30 - 09:30 2.00 FISH P DECOMP Take Initial Parameters Up Wt = 212,000 Ibs Dw Wt = 145,000 Ibs Rot Wt = 170,000 Ibs with 50 rpm's and 7500 ft-Ibs torque. Pump Pressure 10 bpm at 2570 psi. Tag up high at 10317' rotate down through to 10388' and make multiple asses to ensure clean. ontinue to wor own o Ve slow millin from 103 ' to 1 395', vary wt on it up to 10,000 Ibs unable to go past 10395', was able to see small pump pressure(-50) increase below 10390'. Looked like wash over shoe was spinning on something at 10395', unable to ma a any more ept . While circulating did see black flour sand across the shakers with bottoms up. 09:30 - 11:00 1.50 FISH P DECOMP Pump 20 bbl High Visc Sweep and circulate out of hole at 11 bpm and 2660 psi. Did not see anything over the shakers with sweep, clean. 11:00 - 11:30 0.50 FISH P DECOMP Monitor well. B/O and Blow Down Top Drive. 11:30 - 15:00 3.50 FISH P DECOMP POOH and Stand Back Drill Collars. 15:00 - 16:30 1.50 FISH P DECOMP B/O and L/D Wash Over BHA. Clean Out Boot Basket, 1/2gallon of sand & scale. Bottom Cut lip guide on washover shoe in good shape , no major scaring. Did find and recovered remaining 7.5' section of 3-1/2" pup joint with =11.04'. Top of Packer at - 10398'. 16:30 - 18:00 1.50 EVAL N SFAL DECOMP P/U HES 9-5/8" RTT3 wif irc a ve, 4-1/2" x 3-1/2" IF XO, and 3-1/2" IF x 4" HT-38 XO. Total Length of BHA- 19.6'. While using steam to warm up tool prior to RIH a piece of O-Ring Seal fell out of the inside of tool. Unknown where it came from it was elected to L/D the RTTS and P/U a different one. Wait on new tool from HES Shop. 18:00 - 18:30 0.50 EVAL P DECOMP P/U new HES 9-5/8" RTTS with Circ Valve, 4-1/2" x 3-1/2" IF XO, and 3-1/2" IF x 4" HT-38 XO. Total Length of BHA- 19.6'. 18:30 - 22:00 3.50 EVAL P DECOMP RIH with HES 9-5/8" RTTS on 4" HT-38 drill pipe from derrick to 8200'. 22:00 - 22:30 0.50 EVAL P DECOMP Establish parameters of Up Wt- 152,000 Ibs; Down Wt- Printed: 2/27/2008 2:57:42 PM • ~ BP EXPLORATION Operations Summary Report !Legal Well Name: F-17A Common Well Name: F-17A Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date ~~ From - To Hours ~ Task ~~ Code ~I NPT 1/25/2008 122:00 - 22:30 I 0.501 EVAL I P 22:30 - 23:00 0.50 EVAL P 23:00 - 00:00 1.00 EVAL P 1/26/2008 100:00 - 00:30 I 0.501 EVAL I P 00:30 - 01:00 0.50 EVAL P 01:00 - 04:00 3.00 EVAL P 04:00 - 04:30 0.50 EVAL P 04:30 - 07:00 2.50 EVAL P 07:00 - 08:00 1.00 EVAL P 08:00 - 08:30 I 0.501 EVAL I P 08:30 - 09:00 I 0.501 EVAL I P 09:00 - 10:30 I 1.501 EVAL I P 10:30 - 11:00 0.50 EVAL P 11:00 - 12:30 1.50 EVAL P 12:30 - 15:30 3.00 EVAL P 15:30 - 16:30 1.00 DHB P 16:30 - 19:30 3.00 DHB P 19:30 - 20:00 0.50 DHB P 20:00 - 21:30 I 1.501 DHB I P 21:30 - 23:30 I 2.001 DHB I P 23:30 - 00:00 I 0.501 DHB I P 1 /27/2008 100:00 - 00:30 I 0.50 I DHB I P 00:30 - 03:00 I 2.501 DHB I P 03:00 - 03:30 I 0.501 CLEAN I P 03:30 - 05:30 f 2.001 CLEAN I P Start: 1 /19/2008 Rig Release: 2/13/2008 Rig Number: Page 4 of 21 Spud Date: 12/29/1994 End: Phase Description of Operations DECOMP 125,000 lbs. Attempt to set RTTS at 8257'. RTTS took weight (15,000 Ibs) before set. Reason for RTTS taking weight believed to be from junk around packer. Circulate 50 bbls at 6.2 bpm with 780 psi to wash junk from around RTTS. Set RTTS at 8250'and confirm set. DECOMP RJU to pressure test from above the RTTS. DECOMP Pressure #est 9-5/8" casin above RTTS to 3500 psi. Hold test for 30 charted minutes, good test. Pressure test liner top an 7" casing below RTTS to 3500 psi. Hold test for 30 charted minutes, did not get a test. Pressure bled off and leveled off at 2000 psi. DECOMP Bleed off pressure from below 9-5/8" RTTS. Find injection rate of .75 b m with 2750 si. DECOMP R/D casing testing equipment and blow down lines. DECOMP POOH standing back 4" HT-38 drill pipe in derrick. DECOMP UD 9-5/8" RTTS and P/U 7" RTTS. DECOMP RIH with 7" RTTS on 4" HT-38 drill pipe from derrick to 8163'. DECOMP Establish parameters of Up Wt- 155,000 Ibs and Down Wt- 125,000Ibs. R/U and slip and cut 95' of drill line. DECOMP Continue RIH. Tag 7" liner top at 8270'. Continue RIH to 8450' with 7" RTTS on 4" HT-38 drill pipe from derrick. DECOMP POOH and UD one joint. Set 7" HES RTTS at 8422' to the center of the acker elements. DECOMP R/U and pressure test from below RTTS to 3500 psi for 30 charted minutes, goo test. ressure test rom a ove to 3500 psi for 30 charted minutes, test failed. DECOMP Release 7" RTTS. POOH to 8295' and reset RTTS. DECOMP R/U and ressure test from a ow R S to 3500 si for 30 charted minutes ood test. Pressure test from above RTTS to 3500 psi for 30 charted minutes, test failed. R/D testing equipment and blow down lines. DECOMP Release 7" RTTS. POOH from 8295'. UD 7" HES RTTS. DECOMP P/U 7" HES RBP. DECOMP RIH with 7" HES RBP on 4" HT-38 drill i e from derrick. DECOMP Set 7" HES RBP center of elements at 8416' and top of RBP. at DECOMP POOH to 8355' and dump 1200 Ibs of 20/40 mesh sand down the drill string. DECOMP R/U and pump sand down to clear drill string at .8 bpm with 60 psi. DECOMP R/U pressure testing equipment. Pressure test from above 7" _HES RBP to 1000 si. DECOMP Continue pressure test from above 7" HES RBP to 1000 psi for 30 charted minutes, good test. R/D pressure testing equipment. DECOMP RIH and to to of sand at 8357' 55' of sand . POOH with RBP running tool standing back 4" HT-38 drill pipe in derrick. UD running tool. DECOMP P/U BHA #2 (Polish Mill Assembly) consisting of TIW fluted mill, spacer sub, TIW liner dress-off mill x/o sub, bumper sub, jars, pump out sub, x/o sub, 3 stands of 4-3/4" drill collars from derrick. Total length of BHA #2- 308.26' DECOMP RIH with BHA #2 on 4" HT-38 drill pipe from derrick to just Printed: 2/27/2008 2:57:42 PM • • BP EXPLORATION Operations Summary Report Page 5 of 21 Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: i Date From - To Hours Task ~ Code' NPT ' Phase Description of Operations 1/27/2008 03:30 - 05:30 2.00 CLEAN P DECOMP above liner top. Establish Parameters at Up Wt = 157,000 Ibs Dw Wt = 127,000 Ibs Rot Wt = 145,000 Ibs with 5,000 ft-Ibs free torque C~ 50 rpms. Pump rate = 3 bpm at 270 psi. 05:30 - 06:30 1.00 CLEAN P DECOMP No-Go on liner top at 8257. Polish Tie Back with 5,000 Ibs 60 06:30 - 08:00 1.50 CLEAN P DECOMP Pump 20 bbl High Visc Sweep and Pump around at 11 bpm and 2200 psi. Seen only a little sand with returns from sweep. B/O and Blow Down Top Drive. 08:00 - 10:00 2.00 CLEAN P DECOMP POOH and Stand Back Drill Pipe. 10:00 - 10:30 0.50 CLEAN P DECOMP Stand Back Drill Collars in derrick and L/D Polish Mill BHA. Polish Mill showed very minor wear on outside of top dress off cutters. 10:30 - 12:00 1.50 CASE P TIEB1 Clear and Clean Rig Floor. R/U to run 7" Liner with TIW Seal Stem and Baker ZXP Liner Top Packer and HMC Hanger. 12:00 - 13:00 1.00 CASE P TIE61 Load and Strap TIW Seal Stem, Joint with Insert Landing Collar, and Hanger /Liner Top Packer Assembly. 13:00 - 13:30 0.50 CASE P TIEB1 PJSM with rig crew and Baker on making up liner and equipment, discuss loading hanger /setting tool oh to pipe skate with its oversized length. 13:30 - 15:00 1.50 CASE P TIEB1 M/U and Run 7" 26# L-80 BTC-M Scab Liner w/TIW Seal Stem Pup Jt, Float Collar, Pup Jt, 12 Full Joints of 7" 26# sin Baker HMC Liner Han er Baker ZXP Liner To Packer 10.95' Tie Back Sleeve), and Hydraulic Setting Tool. Total Length minus setting tool = 551.4 ft. FIII every 5 joints. 15:00 - 16:30 1.50 CASE P TIEB1 Mix and Fill Hanger Sleeve with PAL Mix and RIH with 1 Stand of DP from Derrick. R/U Clrc Head and pump Liner Volume at 4 bpm and 210 bpm. R/D Clrc Head. 16:30 - 20:00 3.50 CASE P TIEB1 Run liner in hole on 4" HT-38 drill pipe from Derrick 8249' on 81 stands filling pipe every 5 stands. 20:00 - 21:00 1.00 CASE P TIEB1 M/U cement head and R/U to circulate. Break circulation at 4 bpm with 450 psi. Establish parameters of Up Wt- 165,000 Ibs; Down Wt- 132,000 lbs. Cut pump rate back to 1 bpm with 60 psi. Ease seal stem down into PBR. Observe pump pressure increase to 200 psi. Shut down pump and bleed off pressure. Continue to slack off and no 0 out on to f liner. S/O 10,000 Ibs on no go. P/U and find neutral point. Pressure up on drill pipe to 250 psi and POOH. Observe pressure release as circulating ports pulled free of PBR. P/U one more foot and ensure circulation. Secure into place. 21:00 - 22:30 1.50 CASE P TIE61 Circulate at 2 bpm with 90 psi. Hold PJSM with rig team, Schlumberger cementers, and CH2MHill vac truck operators. Discuss in detail upcoming cement job, setting of liner and packer, and cleaning out of cement. Focus on safe and procedures. Assign jobs and responsibilities to personnel. R/U Schlumberger cementer tools and equipment. 22:30 - 23:00 0.50 CASE P TIEB1 Start cement job by Schlumberger pumping 5 bbls fresh water and pressure testing lines to 4700 psi, good test, bleed pressure. Mix and pump 31 bbls of 15.8 ppg "Neat" Class G cement with .08% BWOC 6155 Uniset LT retarder, .2% BWOC D046 antifoam, .35% BWOC D065 TIC dispersant, .1% BWOC D153 antisettling agent, and .35% BWOC D167 UNIFLAC-S. Pump cement at 3.2 bpm with 255 to 384 psi. Shut down pumps and dropped drill pipe dart. Schlumberger chased dart Printed: 2/27/2008 2:57:42 PM • • BP EXPLORATION Page 6 of 21 Operations Summary Report Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date i From - To 'Hours ~~ Task Code NPT Phase ' Description of Operations 1/27/2008 22:30 - 23:00 0.50 CASE P TIEB1 with 5 bbls of fresh water. Switch to rig pump and displaced cement with 9.8 ppg brine at 6 bpm with 360 psi. Caught cement after pumping 25 bbls at 6 bpm pump pressure increased to 570 psi. Continue pumping at 6 bpm for 70 bbls, pump pressure continue to increase to 800 psi. Pump rate was slowed down to 4 bpm from 70 to 85 bbls with 470 to 590 psi. art latched up with wiper plug. Pump rate was slowed down to 2 bpm and 350 psi. Bumped plug at 94 bbls displacement at 2 b m and 800 psi. CIP at 23:00 hrs. 23:00 - 00:00 1.00 CASE P TIEB1 Bleed pressure off to 180 psi. Slack o on seal stem into PBR and no go out. S/O 22,000 Ibs on liner. Pressure up on drill pipe to set Baker HMC liner hanger with 1400 psi and S/O 40 000 Ibs on finer an er. ontinue to pressure up on drill i e and set Baker HR ZXP liner top packer with 2300 psi. Continue increasing pressure and release Baker hydraulic rooa psi and monitor. Bleed off pressure to 0 psi. S/O 50,000 Ibs on liner. Pressure up to 1000 Ibs and pull running tool out of PBR. Pressure bled to 0 psi. New liner top at 7711'. 1/28/2008 00:00 - 01:00 1.00 CASE P TIEB1 Pump Biozan sweep at 10 bpm with 2310 psi to c can out excess cement. Estimated 15 bbls of cement returns at surface. 01:00 - 01:30 0.50 CASE P TIEB1 Break out and L/D cement head. Flush BOP stack with 30 bbls of citric acid rinse. 01:30 - 02:30 1.00 CASE P TIEB1 Circulate 2 bottoms up to insure hole cleaning at 11 bpm with 2700 psi. 02:30 - 03:00 0.50 CASE P TIEB1 Flush ROPE stack, choke line, and kill line with citric acid rinse. 03:00 - 05:30 2.50 CASE P TIE61 POOH with Baker running tool. Stand back 4" HT-38 drill pipe in derrick. 05:30 - 06:30 1.00 CASE P TIEB1 P/U BOP stack washing tool and rinse out stack with citric acid rinse. Inspect flow riser. 06:30 - 07:00 0.50 WHSUR P DECOMP Pull wear ring. 07:00 - 09:30 2.50 WHSUR P DECOMP P/U FMC packoff running tool and RIH. Engage 9-5/8" packoff and BOLDS. All but one LDS backed out. Attempt to RILDS without success. LDS would not run complete y in. Packoff bein ushed u . 09:30 - 10:00 0.50 WHSUR P DECOMP Disengage packoff running tool and POOH. P/U and break out Baker cement head. Wait on orders. 10:00 - 11:00 1.00 WHSUR P DECOMP RIH with packoff running tool and egage packoff. Stack weight of top drive on packoff. Attempt to RILDS without success. POOH with packoff running tool. 11:00 - 12:30 1.50 WHSUR P DECOMP R/U and ressure test wellbore to 1500 psi. Hold test for 30 charted minutes, goo test. D pressure testing equipment. Blow down lines and pump out BOP stack. 12:30 - 15:00 2.50 WHSUR P DECOMP N/D between tubing spool and casing spool. Stand back BOPE. Visual inspection showed the 9-5/8" casing hanger to be moved u approximate) 1-1/2". P/U packoff running tool and engage packoff. Stack weight of top drive on packoff and attempt to BOLDS without success. 15:00 - 16:30 1.50 WHSUR P DECOMP N/U BOPE and set wear ring. Pressure test breaks to 1000 psi. 16:30 - 17:00 0.50 CLEAN P DECOMP M/U BHA #3 (Drill Out Assembly) consisting of a 6" rock bit, Printed: 2/27/2008 2:57:42 PM • i BP EXPLORATION Operations Summary Report Page 7 of 21 Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date ~ From - To Hours Task Code ~ NPT j Phase Description of Operations 1/28/2008 116:30 - 17:00 0.50 ~ CLEAN P 17:00 - 18:00 1.00 CLEAN P 18:00 - 20:00 2.00 CLEAN P 20:00 - 20:30 0.50 CLEAN P 20:30 - 22:00 1.50 CLEAN P 22:00 - 22:30 0.50 CLEAN P 22:30 - 23:00 I 0.50 I CLEAN I P DECOMP boot baskets, bit sub, bumper sub, jars, pump out sub, x/o sub, 3 stands of 4-3/4" drill collars from derrick. Total length of BHA #3- 311.10' DECOMP RIH with BHA #3 on 4" HT-38 drill pipe from derrick to 2680'. DECOMP R/U to reverse circulate. Reverse circulate 290 bbls of 42 deg F seawater at 3 bpm with 140 psi. DECOMP Attempt to function LDS without success. R/D circulating equipment and blow down same. DECOMP Continue RIH with BHA #3 on 4" HT-38 drill pipe from derrick to 7524'. DECOMP P/U HES 9-5/8" RTTS and RIH to 7619'. Establish arameters of Up Wt- 155,000 Ibs and Down Wt- 125,000 lbs. Set RTTS at 102' to the top of RTTS and 108' to COE. ~_ DECOMP R/U and test RTTS to 1000 Ibs from above for 10 charted, minutes, ood test. Pun wear r 23:00 - 00:00 1.00 CLEAN P DECOMP Attempt to function LDS without success. P/U FMC packoff running tool and engage packoff. Attempt to pull packoff free with one LDS still engaged. Pull on packoff to 80,000 Ibs (38,000 Ibs overpull) and work several times. Consult with FMC wellhead technician. Pull 100,000 Ibs on packoff (58,000 Ibs overpull) and work several times setting 15,000 Ibs on packoff with top drive. Notice some movement with packoff through tattle tale port. S/O 15,000 Ibs on packoff and attempt to function LDS. Slight movement in LDS. EventuaNy worked LDS out from packoff. POOH with packoff wi 1000 Ibs 1/29/2008 100:00 - 00:30 I 0.501 CLEAN I P 00:30 - 01:30 1.00 CLEAN P 01:30 - 02:00 0.501 CLEAN ( P 02:00 - 02:30 I 0.501 CLEAN I P 02:30 - 03:00 I 0.501 CLEAN I P 03:00 - 04:00 I 1.001 CLEAN I P DECOMP L/D old 9-5/8" packoff. Examination of packoff show the packoff to be in good/ used condition without any noticeable stress from LDS being engaged improperly other than the damage from attempting to run in LDS earlier and pulling the packoff OOH with one LDS engaged. DECOMP Discuss options with FMC technicians. P/U and RIH with new 9-5/8" packoff, carefully setting into position. Three noticeable indications were noticed that packoff was set properly; could visually see the packoff to a in a proper pose ion rough the tattle tale port, LDS engaged to proper setting depth, and marked packoff and visually could located mark on packoff through the annulus valve. RILDS. POOH with packoff running tool. DECOMP R/U and pressure test packoff to 5000 lbs. Hold pressure test for 30 minutes, good test. Test witnessed by FMC wellhead tech and BPX W SL. DECOMP R/U and pressure test BOP/wellhead breaks to 250 si low ressure test and 35 psi ig pressure test. Hold each test for 5 charted minutes. Test witnessed by Doyon Toolpusher and BPX WSL. DECOMP P/U HES RTTS running tool and RIH. Engage RTTS and unseat. POOH and L/D RTfS. DECOMP R!U and pressure test casing to 250 psi low pressure tesLaud_ Ihold test for 5 charted minutes. Pressure test casing to 3500 04:00 - 04:30 I 0.501 CLEAN 1 P si hi h ressure test and Hold for 30 charted minutes, good test. R/D pressure testing equipment and blow down lines. DECOMP Continue RIH with 4" HT-38 drill pipe from derrick. Tag TOL at Printed: 2/27/2008 2:57:42 PM • • BP EXPLORATION Operations Summary Report Page 8 of 21 Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task I Code i NPT i Phase Description of Operations i 1/29/2008 04:00 - 04:30 0.50 CLEAN P DECOMP 7714' and continue RIH to 8092'. Establish drilling parameters of Up Wt- 157,000 Ibs; Down Wt- 125,000 Ibs; Rot Wt- 145,000 Ibs at 60 rpm and 5,000 ft-Ibs free torque; Pump Rate- 5 bpm with 510 psi. 04:30 - 09:30 5.00 CLEAN P DECOMP Tag soft cement at 8094' and wash and ream to 8120'. Tag hard cement at 8120'. Continue to drill out cement with 5,000 to 10,000 Ibs WOB at 60 rpm and 6000 ft-Ibs torque, 700 psi at 5 bpm. Drill Down to Insert Landing Collar and Plug at 8191ft. Drill Cement below Landing Collar and thru Float Collar down to just below Seal Stem. 09:30 - 10:30 1.00 CLEAN P DECOMP Pump 20 bbl High Visc Sweep and Circ at 10 bpm and 1050 psi. A good about of Cement, Rubber, and Small Metal Pieces Seen in Returns. 10:30 - 11:30 1.00 CLEAN P DECOMP Clean Out Wellbore Below Seal Stem. Rotate and Wash Down to 8345'. Did take between 3-7,000 Ibs to work from 8260' down to 8330'. From 8345' to 8360' Rotate down w/o pumps to grind up remaining piece of plug and float collar that remain. P/U and repeat again. 11:30 - 12:30 1.00 CLEAN P DECOMP Pump 20 bbl High Visc Sweep and Circ at 12.0 bpm and 2550 psi while working pipe from 8270'-8360'. A larger amount of cmt fines in returns. Cleaned up quickly after Sweep passed. 12:30 - 14:00 1.50 CLEAN P DECOMP Shut Down Pumps and Monitor Well. Pump Dry Job. Pull Out of Hole and Stand Back One Stand. Found Well Out of Balance. M/U Top Drive again and Circulate while making 40 bbl dry job. Wt of fluid going in 9.6ppg, Wt of fluid out 9.6+ppg. Pump Dry Job and B/O Top Drive. Tubing on vac after pumping Dry Job. Blow Down Top Drive. 14:00 - 16:00 2.00 CLEAN P DECOMP POOH and Stand Back 4" Drill Pipe in Derrick. 16:00 - 17:00 1.00 CLEAN P DECOMP Stand Back Drill Collars and L/D 6" Bit and Drill Out BHA. 17:00 - 18:00 1.00 CLEAN P DECOMP P/U Pulling Tool and Pull Wear Ring. P/U Test Plug and Set. R/U to Test BOP's 18:00 - 21:00 3.00 CLEAN P DECOMP Test BOP's to 250psi low and 3500 psi high as per requirements with 4" and 4-1/2" test joints. Test Witness Waived by John Crisp with AOGCC. 21:00 - 22:00 1.00 CLEAN P DECOMP R/D BOP test equipment, B/D surface lines, pull test plug and install wear ring. 22:00 - 23:00 1.00 CLEAN P DECOMP M/U Reverse circulating junk basket BHA. 23:00 - 23:30 0.50 CLEAN N DECOMP Rig Crew responded to diesel spill at the #4 generator, 5700 notified and ACS Responded to Generator #4 and Approved Clean up of area. 23:30 - 00:00 0.50 CLEAN P DECOMP RIH to with 4" drill pipe to 1,463'. 1/30/2008 00:00 - 02:00 2.00 CLEAN P DECOMP Continue to RIH from 1,463' to 8,300' obtain parameters: up weight=175,000#, down weight=125,000#. Worked Casing Scraper from 8160' - 8300', covering Landing Collar, Float Collar, and Seal Stem Areas. 02:00 - 04:30 2.50 CLEAN P DECOMP Continue to RIH tag sand at 8,360'. P/U and attempt to wash down, start pumping at 3.5 bpm and 2500 psi, found that pipe was slowly packing off. Lined up and reverse circulated drill pipe, pumped pipe volume of 90 bbls. Rev Clrc at 8.5 bpm, pressured up to 3000 psi initially and broke down to 1700 psi. Bled Off Pressure and Open Bag and started rotation at 10 rpm's C~ 5,000 ft-Ibs free Torque. Circulate down drill pipe at Printed: 2/27/2008 2:57:42 PM BP EXPLORATION Page 9 of 21 Operations Summary Report Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To ~ Hours Task Code NPT Phase Description of Operations 1/30/2008 02:00 - 04:30 2.50 CLEAN P DECOMP 3.5 bpm and 2250 psi. Once returns were seen at the pits began to wash down and tag, attempting to make hole. Drill pipe packed off again. Try to Shake Free. Close Bag again and Reverse Circ another 70 bbls. Open Bag and Start Circulating at 5 bpm and 450 psi down drill pipe, ball seated and pressure increased to 800 psi at 5 bpm. Continue Pumping, pressure leveling off at 5.0 bpm and 1500 psi. After 50 bbls drill pipe started packing off again. Attempt to unplug 3 times unable to use the Reverse Circulating Junk Basket. Reverse Circ 1 last time and Drop the Opening Dart for Pump Out Sub, Monitor Wellbore, pumped 15 bbl dry job. 04:30 - 07:00 2.50 CLEAN P DECOMP POOH from 8,360' with Reverse Circ Junk Basket. Stand Back 4" DP in Derrick. 07:00 - 08:00 1.00 CLEAN P DECOMP Stand Back DC's and B/O RCJB BHA. Found 1 large piece of Aluminum from what looks like the landing collar. Several small piece of aluminum. Two pieces of carbide ball seat and one 7/8" Steel Ball. In Boot Baskets found - 1 qt of Aluminum pieces and cement chunks. 08:00 - 08:30 0.50 CLEAN P DECOMP Wait on new reverse basket. Clean and Clear Rig Floor. 08:30 - 09:00 0.50 CLEAN P DECOMP M/U New 5-3/4" RCJB and Barrel w/ 2 Boot Baskets Bumper Sub, Jars, Pump Out Sub, and (9) 4-3/4" DC. Total Length = 318.61' Ball was inserted to make sure it cleanly goes on seat and then remove. Casing Scraper was left out on this run. 09:00 - 12:00 3.00 CLEAN P DECOMP RIH w/ RCJB BHA on 4" DP from Derrick to Top 7" of Liner. Break Circulation every 30 stands and Pump a Drill Pipe Volume. 12:00 - 13:30 1.50 CLEAN P DECOMP Slip and Cut Drilling Line. Adjust Brakes. Inspect Saver Sub. 13:30 - 14:00 0.50 CLEAN P DECOMP Continue to Trip in Hole to just above top of sand at 8295'. 14:00 - 15:00 1.00 CLEAN P DECOMP Establish Parameters Up Wt = 175,000 Ibs / Dw Wt = 124,000 Lbs /Rot Wt = 150,000 Ibs at 40 rpm's and 7500 ft-Ibs free torque. Circulate at 5 bpm and 700 psi. Break Off one single from stand and drop ball. Bring Pumps back on at 1.2 bpm and 60 psi. S/O and Tag Sand Top at 8367'. P/U -20ft and increase Pump Rate to 5.0 bpm and 700 psi and wait on ball to seat, work pipe to help ball move down hole. 15:00 - 16:00 1.00 CLEAN P DECOMP With Ball on seat, 5 bpm and 840 psi. Increase Pump Rate to 6 bpm and 1100 psi. Rotate and Wash down from 8367' to 8400'. Work RCJB with 3-5,000 Wt on Bit an o 00 ft-Ibs torque. Work Pipe Down 5-10 ft at a time then P/U and wash over again to pick up any bigger pieces. Pump 20 bbl High Visc Sweep at 8385' and again at 8400'. 16:00 - 18:30 2.50 CLEAN P DECOMP Clrculate Out Sweeps at 8.5 bpm and 1900 psi. Sand and cement cuttings in returns before sweep coming over. Cleaned up after sweeps were back. Pump 15 bbl dry job after sweeps back. 18:30 - 20:30 2.00 CLEAN P DECOMP B/O and Blow Down Top Drive and POOH. Stand Back DP. 20:30 - 21:00 0.50 CLEAN P DECOMP B/O and UD BHA #5, Clean Junk Baskets, Recovered .5 Gallon of Cement and Small pieces of Aluminum. Clean RCJB and Recovered 11 large pieces of Aluminum 21:00 - 21:30 0.50 CLEAN P DECOMP M/U BHA #6 RCJB. BHA Consists of 5 3/4" RCJB, Double Pin Sub, 2-Junk Baskets, 7" Scraper, Bit Sub, LBS, Oil Jar, Pump Out sub, XO, 9-4 3/4" Drill Collars. 21:30 - 22:00 0.50 CLEAN P DECOMP Battery Terminals came loose on the 3516 Generator Printed: 2/27/2008 2:57:42 PM r BP EXPLORATION Page 10 of 21 Operations Summary Report Legal Welf Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT ' Phase Description of Qperations 1/30/2008 21:30 - 22:00 0.50 CLEAN P DECOMP Operating Control Panel. This caused the breaker to trip thus loose power all through out rig. 22:00 - 00:00 2.00 CLEAN P DECOMP RIH from 321' to 3,641' 1/31/2008 00:00 - 00:30 0.50 CLEAN P DECOMP Continue to RIH from 3,641' to 5,067', Fill pipe 1.5 Times Drill Pipe Volume at 9 bpm with 2,000 psi. 00:30 - 01:30 1.00 CLEAN P DECOMP Continue to RIH from 5,067' to 8,300'. Obtain Parameters: up weight=182,000#, down weight=120,000#, rotating weight=140,000#, 10 rpm with 6,000 ft-Ibs torque. 01:30 - 02:30 1.00 CLEAN P DECOMP Break circulation at 5 bpm with 730 psi, drop reversing ball and allow to fall on seat. Wash and rotate down to 8,410' with 6 bpm and 970 psi. 02:30 - 03:30 1.00 CLEAN P DECOMP Pump 20 bbl Hi-Vis sweep at 8 bpm with 1990 psi. 03:30 - 04:00 0.50 CLEAN P DECOMP Drop opening dart for circ sub, pump 15 bbl dry job, B/D Top Drive. 04:00 - 06:30 2.50 CLEAN P DECOMP POOH from 8,412' and Stand Back Drill Pipe 06:30 - 07:00 0.50 CLEAN P DECOMP Stand Back Drill Collars. B!O and L!D RCJB and Boot Baskets. Found two small pieces of aluminum in the RCJB. Boot Baskets had minimal amount of sand, cement and pieces of aluminum. 07:00 - 08:00 1.00 CLEAN P DECOMP Pressure Test Well. Close Blind Rams and Pressure Test Well to ~FM nci fnr sn minc nn chart Toot chnwinn ~ nsi as off in 30mins. Consult with town on results. 08:00 - 10:30 2.50 CLEAN P DECOMP M/U HES Retrieval Tool of 7" RBP. RIH on DP from Derrick to 8257'. 10:30 - 13:30 3.00 CLEAN P DECOMP Rig Up Test Equipment and Pressure Test Well again at 8257'. ressure est to psi on c art. on uct two separate tests. One for45 mins and another for 50mins. Both showing Bleed off the same at -75 psi in 30 mins. ee o apers down the longer t e test was a ook§ to be thermal. 13:30 - 14:00 0.50 CLEAN P DECOMP PJSM with Truck Drivers and With Rig Crew of Displacing to SW. R/D Test Equipment. 14:00 - 15:30 1.50 CLEAN P DECOMP S/O and Tag Up on RBP and P/U to 5,000 Ibs over. Up Wt = 175,000 Ibs and Dw Wt = 125,000 Ibs. Pump 20 bbl high visc sweep and chase out of the hole at 8 bpm and 1260 psi. Pump 595 bbls to displace well. Final Circ Pressure = 8 bpm at 1060 psi. 15:30 - 17:00 1.50 CLEAN P DECOMP Work Pipe to Pull RBP. S/O and Put 1/4 turn Rt Hand Torque. P/U and Work Pipe at 5,000 Ibs increments up to 30,000 Ibs over in attempt to release RBP. Repeat S/O with 1/4 Turn and Work Up to 30,000 over three times to get RBP to release. Circ Btms Up. 17:00 - 20:00 3.00 CLEAN P DECOMP POOH and Stand Back DP. 20:00 - 21:00 1.00 CLEAN P DECOMP M/U BHA #7 Consisting of: 6" Packer Mill, 3-Junk Baskets, Bit Sub, LBS, Jar, Pump,Out Sub, XO, 12-4.75" Drill Collars. BHA Lenght=408.60' 21:00 - 00:00 3.00 CLEAN P DECOMP RIH iron 408'to 9,142'. 2!1/2008 00:00 - 00:30 0.50 GLEAN P DECOMP Continue to RIH from 9,142' to 10,354' tagged up on junk. 00:30 - 07:30 7.00 CLEAN P DECOMP Obtain parameters: Up weight= own weight=140,000#, rotating weight=180,000#, 60 rpm, 11,000 ft-Ibs free torque. Continue to Rotate and push junk to top of acker at 10,400'. Milling packer with 5-15,000# W B Printed: 2/27/2008 2:57:42 PM ~ ~ BP EXPLORATION Page 11 of 21 Operations Summary Report Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/1/2008 00:30 - 07:30 7.00 CLEAN P DECOMP 11-13,000 ft-Ibs torque. Mill Packer from 10400' - 10402'. Packer Fell to 10406' (oft ). Did see a smal amount o gas in returns. eare up quit y. 07:30 - 09:30 2.00 CLEAN P DECOMP Pump 20 bbl High Visc Sweep and Chase Out of the Hole at 11 bpm and 2750 psi. Rubber, Metal Shavings, and Sand in returns prior to sweep coming over the shakers. Once sweep cleared, shut down pumps and monitor well for flow. Pump Dry Job and Prep to POOH. 09:30 - 12:30 3.00 CLEAN P DECOMP POOH with Pkr Mill BHA. Stand Back Drill Pipe. 12:30 - 13:00 0.50 CLEAN P DECOMP Stand Back DC's. UD Packer Mill and Boot Baskets. Recovered ~1.5 gallons of metal) shaves and pieces w/ some rubber in Boot Baskets. Mill worn about 1/3 the way down but still in good shape. Pieces of rubber and slip dies stuck in water passes. 13:00 - 14:00 1.00 CLEAN P DECOMP M/U 3-1/4" Spear BHA with 5-3/4" Stop Ring, Bumper SUb, Jars, Pump Out SUb, XO and 12 DC's. Total Length = 394.54' 14:00 - 17:00 3.00 CLEAN P DECOMP RIH with Spear BHA to 10350' on DP from Derrick. 17:00 - 18:00 1.00 CLEAN P DECOMP Slip and Cut Drilling Line and Adjust Brakes. 18:00 - 21:30 3.50 CLEAN P DECOMP Make Up Stand 106. Up Wt = 235,000 Ibs , Dw Wt = 140,000 lbs. Pump Rate = 2 bpm at 150 psi. Tag Top of Packer at .10406' and S/O Spear all the way down ~ ump ressure im apidly. Shut-In Pump. P/U with 30,000 Ibs Overpull. continue to jar and pull on pipe max up weight jarring 325,000# Max pulling up weight 375,000#. 21:30 - 22:00 0.50 CLEAN P DECOMP Service Rig, Inspect Top Drive and Derrick after Jarring Operation. 22:00 - 00:00 2.00 CLEAN P DECOMP POOH from 10,400' to 7,041' with Spear Assembly. 2/2/2008 00:00 - 01:30 1.50 CLEAN P DECOMP Continue to POOH with Spear Assembly from 7,041' to 396'. 01:30 - 02:00 0.50 CLEAN P DECOMP Stand back Drill Collars, B/O and UD Spear assembly and rebuild Pump out sub. 02:00 - 03:00 1.00 CLEAN P DECOMP M/U and Packer Millin Assembl BHA consists of: Packer Mill, 2-Junk Baskets, Bit Sub, LBS, Jar, Pump Out Sub, XO, 12-4.75" Drill Collars. 03:00 - 06:00 3.00 CLEAN P DECOMP RIH to 10300' with Packer Milling Assembly on 4" DP. Parameters Up Wt = 237,000 Ibs Dw Wt = 123,000 Ibs, Rot Wt = 175,000 Ibs ~ 60 rpm's and 12,000 ft Ibs free torque. Pump rate 5 bpm at 580 psi. 06:00 - 10:30 4.50 CLEAN P DECOMP Wash and Rotate Down. Tag ToP of Packer at 10406'. Mill on Packer from 10406' - 10410' with 5-15K and 2-15K ft-Ibs torque. First 2ft milled quickly < 1 hr. Second 2 ft required -2 hrs to mill. .Unable to mill past 10410', rotate with only free torque, tried varying WOB from 5-15k, rpm's 40-80, and pump rate from 3-7 bpm. Small metal shaving seen over the shakers and small amount of sand seen over shakers on first bottoms up. Pump two 20 bbl high visc sweeps while milling a little more fine metal shaving and small bits of rubber seen over the shakers just before the sweeps came back. Consult with Town on progress made. 10:30 - 11:30 1.00 CLEAN P DECOMP Pump 20 bbl High Visc Sweep and Chase Out of Hole at 10.5 bpm and 2650 psi. Saw fine metal shavings and a few pieces of black rubber over the shakers while circulating and prior to sweep coming back. 11:30 - 12:00 0.50 CLEAN P DECOMP Monitor Well and Prep for POOH. Pump Dry Job. B/O and Printed: 2/27/2008 2:57:42 PM r • BP EXPLORATION Page 12 of 21 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 2/2/2008 11:30 - 12:00 12:00 - 14:30 14:30 - 15:30 15:30 - 16:00 F-17A F-17A Spud Date: 12/29/1994 WORKOVER Start: 1/19/2008 End: DOYON DRILLING INC. Rig Release: 2/13/2008 DOYON 16 Rig Number: Hours Task Code' NPT Phase' Description of Operations 0.50 CLEAN P DECOMP Slow Down Top Drive. 2.50 CLEAN P DECOMP POOH and Stand Back DP. 1.00 CLEAN P DECOMP Stand Back DC's. B/O Boot Baskets, Packer Mill, and Jars. Boot Baskets contained -1/2 gallon of metal shavings, mostly fine stuff with a some larger shavings, nothing identifiable. Mill faceshowed obvious wear. Inner face of mill from nose out to 4.75" on the OD worn down more than the outer edge indicating milling on something smaller than 6" OD. P/U new set of 4.75" Jars. Consult Town on finds with mill face and boot basket recovery. 0.50 CLEAN P DECOMP M/U Bowen C Spear BHA~with 2.875" Nominal Grapple 16:00 - 20:00 4.00 CLEAN P 20:00 - 20:30 0.50 CLEAN P 20:30 - 21:30 I 1.001 CLEAN I P 21:30 - 22:00 0.50 CLEAN P 22:00 - 00:00 2.00 CLEAN P 2/3/2008 00:00 - 01:30 1.50 CLEAN P 01:30 - 02:00 0.50 CLEAN P 02:00 - 02:30 0.50 CLEAN P 02:30 - 04:30 2.00 CLEAN P 04:30 - 05:00 0.50 CLEAN P 05:00 - 08:30 3.50 CLEAN P 08:30 - 10:00 I 1.50 I CLEAN I P (L. /b~~-3.U") esumper suo, oars, rump vut quo, ana vas. Total Length = 398.07' DECOMP RIH with Spear on 4" DP. Break Circ Every 30 stands in hole, very small ID on spear 0.38". M/U T/D and obtain parameters: up weight=230,000#, down weight=140,000#. DECOMP Continue to RIH and_Tag Fish at 10,410', slack off to No-Go at 10,413', P/U 30' and engage pumps to verify latch of fish, pump rate at 20 spm, 1.7 bpm=1,640 psi, slow pump rate was 680 psi. DECOMP Drop ball and rod to open Pump Out Sub, engage pumps and shear open. CBU at 10 bpm with 1620 psi. DECOMP Monitor wellbore, pump dry job. DECOMP POOH from 10,413' to 6,092'. DECOMP Continue to POOH from 6,049' to 398'. DECOMP Stand back Drill Collars and B/O Spear Assembly, NO Fish, Spear was completly full of fine metal cuttings. Grapple run was 2.875". DECOMP Clear and Clean Rig Floor, Clean out Spear and XO of Cutting. DECOMP Waiting on Baker Tools. DECOMP M/U Spear Assembly, P/U 4 stands of 4 3/4" Drill Collars. DECOMP RIH with Spear assembly and 2.938" Grapple to Top of Fish at 10410' DECOMP Est Parameters; Up Wt = 230,000 Ibs Down Wt = 142,000 lbs. Attempt to Spear Fish. Bring pumps up to speed at 2.7 bpm and 2350 psi. S/O and ease down with stand 106. Tag up at 10410', pump pressure increasing rapidly. P/U and let pump pressure decrease back to 2350 psi. Slowly wash down to attempt to jet away any fill. Begin taking Wt at 10410' and slowly work down to 10412'. Pump pressure hold steady at 2385psi. At 10412' wt fell off quicly and pump pressure rapidly increased to over 2450 psi and continued climbing, back down on pumps. Continue to S/O and Stack 15,000 Ibs WOB at 10415'. Pump running at just under 1 bpm and 1600 psi. P/U off Bottom and immediately see over pull. Pull up to 45,000 Ibs over pull and let the jars go off then straight pull to 70,000 Ibs over. S/O down to 145,000 Ibs to recock the jars. P/U again and see no over pull. Pump pressure falling off. Bring Pumps Up to 2.7 bpm again. Printed: 2/27/2008 2:57:42 PM • • BP EXPLORATION Page 13 of 21 Operations Summary Report Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task j Code NPT ~ Phase Description of Operations 2/3/2008 08:30 - 10:00 1.50 CLEAN P DECOMP S/O and P/U again to attempt to latch fish. Back down on pump rate to -1.5 bpm and 1500 psi. Make Two attempts to latch fish. Getting back down to what looks like the same depth with 15,000 WOB. Unable to latch fish. Consult town . 10:00 - 11:30 1.50 CLEAN P DECOMP Drop Dart and Pump Down at 2.7 bpm and 2300 psi. Circ Sub Open after about 15 mins pumping at 2.7 bpm and 2300 psi. Circ Bottoms Up at 10.5 bpm and 1850 psi. Nothing seen with bottoms up over shakers. Monitor Well. Pump Dry Job. 11:30 - 12:30 1.00 CLEAN P DECOMP POOH from 10,417', 12:30 - 15:00 2.50 CLEAN P DECOMP L/D 4" 250 ton elevators. Derrick Hand saying that handle too close to body of elevatore and having difficult time getting hand in and out to open them. No other 4" elevators on location. Call out new set from API, tool service to pick up ASAP. Old set send back to API for repair and inspection. 15:00 - 17:00 2.00 CLEAN P DECOMP Continue to POOH with spear assembly from 8,849' to 402'. 17:00 - 18:00 1.00 CLEAN P DECOMP Stand Back Drill Collars, No Fish Recovered. 18:00 - 19:00 1.00 CLEAN P DECOMP Clear and Clean Rig Floor, Discuss Options with Anchorage Engineering and Baker Fishing. 19:00 - 19:30 0.50 CLEAN P DECOMP Continue to Wait on next BHA components, PJSM on Slip and Cutting Drilling Line. 19:30 - 20:30 1.00 CLEAN P DECOMP Slip and Cut Drilling Line 94'. 20:30 - 21:00 0.50 CLEAN P DECOMP Continue to Wait on 2 3/8" Mule Shoe. 21:00 - 22:00 1.00 CLEAN P DECOMP M/U BHA #12, 2 3/8" Mule Shoe, XO,Double Pin Sub, 2-Boot Baskets, Bit Sub, LBS, Jar, Pump Out Sub, XO, 12 - 4.75" Drill Collars. BHA Lenght=441.81'. 22:00 - 00:00 2.00 CLEAN P DECOMP RIH from 414' to 6,109' with 4" Drill Pipe. test 2/4/2008 00:00 - 01:30 1.50 CLEAN DECOMP Continue to RIH from 6109' to 10300'. Take Initial Parameters, 230,000 Ibs Up Wt; 140,000 Ibs Dw Wt; 170,000 Ibs Rot Wt C~ 5 rpm's with 4,500 ft-Ibs free torque. 01:30 - 08:00 6.50 CLEAN DECOMP PJSM w/ Crew. RIH to 10405' and Pump 20 bbl high visc sweep at 8 bpm and 1250 psi. Pump sweep - 50 bbls up annulus. Line Up and Reverse Circ at 5.3 bpm and 650 psi. while washing down to 10413'. Tagged top of Fish at 10410'. Recovered 15 Ibs of fine metal shaving rom sweep. Line up to pump long way. Rotate and Wash down at 13 bpm and 2900 psi, No Go at 10418'. Pump 10 bbl sweep at 13 bpm and 2900 psi while rotating and washing. Collected 12 Ibs of fine metal shavings with sweep. Close Bag with drill string at 10417' and reverse circ 20 bbl high visc sweep at at 2990 psi. Collect 12 {bs of metal off magnets. S/O to Reconfirm Depths. Wash Down and Tag at 10413'. P/U and Rotate, continue to S/O down to 10418'. Pump Press Increasing at this depth. again and Wash Down and tagged at 10413' w/ 5k down. Rotate String and Wt Fell Off. Stop Rotation and Wash Down to 10418' and Took Weight. Rotate Pipe Again and Wt Fell Off. Rotate down to 10421'. Printed: 2f27f2008 2:57:42 PM • BP EXPLORATION Operations Summary Report Legal Well Name: F-17A Common Well Name: F-17A Event Name: WORKOVER Start: 1/19/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date' From - Toro ~ H~ou~rs~'~Tas~Codie NPT~se 2/4/2008 101:30 - 08:00 I 6.501 CLEAN DECOMP 08:00 - 1 i :30 I 3.501 CLEAN I I I DECOMP 11:30 - 12:30 1.001 CLEAN I I DECOMP 12:30 - 13:00 0.501 CLEAN I I I DECOMP 13:00 - 15:30 2.50 CLEAN DECOMP 15:30 - 22:00 6.50 CLEAN DECOMP 22:00 - 00:00 I 2.001 CLEAN I I I DECOMP 2/5/2008 00:00 - 03:00 3.00 CLEAN P DECOMP 03:00 - 03:30 0.50 CLEAN P DECOMP 03:30 - 04:30 1.00 CLEAN P DECOMP 04:30 - 07:30 3.00 BOPSU P DECOMP 07:30 - 08:00 0.50 BOPSU P DECOMP 08:00 - 10:00 2.00 CLEAN P DECOMP 10:00 - 12:30 2.50 CLEAN P DECOMP 12:30 - 13:00 0.50 CLEAN P DECOMP 13:00 - 16:00 f 3.001 CLEAN 1 P I I DECOMP 16:00 - 17:30 1.50 CLEAN P DECOMP Page 14 of 21 Spud Date: i 2/29/1994 End: Description of Operations Pump Pressure Increase at 10421'. P/U till Pump Pressure Dropped Off. Pump 20 bbl High Visc Sweep and Chase Out of Hole at 12 bpm and 2500 psi. Recovered 4 Ibs of Metal. Pump Dry Job. B/O and .Blow Down Top Drive. POOH and Stand Back DP. Stand Back Drill Collars and B/O Mule Shoe BHA. Boot Baskets contain -1 qt of metal shavings. Mule shoe was round over a little on the tip and had a a few scrapes and gouges on it as if scraped by something. M/U Spear Assembly BHA Consists of: Itco Spear w/2.933 grapple, LBS, Jar, Pump Out Sub, XO, 6 - 4 3/4" Drill Collars, XO, 4 3/4" Intensifier, XO. BHA Lenght=234.83'. Continue to RIH from 234' to 10,387' M/U T/D at 10,387' and obtain parameters: up weight=220,000#, down weight=137,000#, pump rate at 2 bpm=540 psi. Continue RIH and tag top of pkr at 10,413' Continue to wash down to No-Go at 10,421' Noticed increase of pump pressure to 2,361 psi when stacking out on No-Go w/15,000# WOB, Shut down pumps and P/U 50,000# over string weight for a total of 270,000# Let jar fire and pull up to 300,000#, slacked off to neutral weight and B/D T/D, M/U T/D and begin Jarring Operations, Pulling a Max of 325,000# to jar and pull to 375,000#. Release from Fish made 4 rounds to the right, Torque at 5,500 ft-Ibs while coming up out of tubing around 6' up it pulled 20,000# overpull, lost the overpull and pulled out of tubing. Stand back 1 stand, drop ball and rod, open Circ Sub, pump dry job, monitor well. Inspect Derrick and Top Drive after jarring operations. POOH from 10,421' to 234'. UD Spear assembly, Spear came out of hole without grapple Pull Wear Ring, R/U to est Test BOPE, 250-psi low, 3,500-psi high. AOGCC witness waived by Lou Grimaldi. Pull test plug and install Wear Ring. M/U washover BHA: RIH washover BHA on DP from Derrick. M!U drill string to Top Drive at 10,356' R1H. Up wt 225K-Ibs, Dn wt 145K-Ibs. Rot wt 165K at 80-RPM, with 8K-Ib-ft free torque. Pump rate 6-BPM at 490-psi. RIH and tag fish at 10,413'. P/U off bottom and start Top Drive at 80-RPM and RIH to washover fish from 10,413' to 10,434'. Tag up with 5K-Ibs WOB and 13 to 14K-Ib-ft of torque, burn down with pump rate of 6-BPM at 600-psi. Pumped a 20-Bbl Hi-Vis sweep. Lost returns at 10,438'. P/U off fish, S/D pump and establish a loss rate of -250-BPH. B/O Top Drive and blowdown lines. RIH to verify max washover depth of 10,438'. Wait on additional seawater to continue burnover/milling operations. Discuss plan forward with ADW Engineer. Establish continuous hole fill rate of 95-BPH with charge pump. Got returns to surface with 198-Bbls pumped. Slowed pump rate to 50-BPH and maintained fluid level at the wellhead. Take on seawater to Pits. Printed: 2/27/2008 2:57:42 PM • 1.001 CLEAN I P I I DECOMP BP EXPLORATION Operations Summary Report Legal Well Name: F-17A Common Well Name: F-17A Event Name: WORKOVER Start: 1/19/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date 2!5/2008 2/6/2008 From - To ~ Hours Task Code NPT Phase 17:30 - 00:00 6.50 CLEAN P I I DECOMP 00:00 - 01:00 4 1.001 CLEAN I P I I DECOMP 01:00 - 01:30 0.50 CLEAN P DECOMP 01:30 - 05:00 3.50 CLEAN P DECOMP 05:00 - 05:30 0.50 CLEAN P DECOMP 05:30 - 06:00 0.50 CLEAN P DECOMP 06:00 - 07:00 1.00 CLEAN P DECOMP 07:00 - 08:30 1.50 CLEAN P DECOMP 08:30 - 09:00 0.50 CLEAN P DECOMP 09:00.- 12:00 3.00 CLEAN P DECOMP 12:00 - 13:00 1.00 CLEAN P DECOMP 13:00 - 14:30 1.50 CLEAN P DECOMP 14:30 - 15:30 15:30 - 19:30 19:30 - 20:00 20:00 - 20:30 4.001 CLEAN I P I I DECOMP .7 Page 15 of 21 Spud Date: 12/29/1994 End: Description of Operations Establish parameters: 80-RPM, 11 K-Ib-ft free torque, 4.5-BPM at 300-psi. Wash down and tag 2' higher at 10,436' and continue easily in to 10,438'. Start burning over with 3-5K-Ibs WOB and torque from 11 K to 18K-Ib-ft. Continue to burn down to 10,443'. Loss rate reduced to 20 bph. Fluid Loss 411 bbls. Pump 20 bbl Hi-Vis Sweep at 11 bpm with 2800 psi. Sweep yielded 5 Ibs of fine metal shavings. Monitor wellbore, pump 20 bbl dry job, B/D T/D. POOH from 10,443 to 486'. L/D Burn Over Assembly. Clear and Clean the rig floor. Lubricate and service rig. Discuss plan forward with ADW engineering. ~/1/U Spear BHA: Itco Spear with 2.933" grapple, Bumper sub, Oil Jar, Pump-out sub, 6 -ea 4-3/4" DCs, 4-3/4" Bowen Intensifier. RIH Spear BHA on DP from Derrick to 9,300'. Cut and slip drilling Line. Continue RIH from 9,300' to 10,386'. P/U stand #108 and get parameters: P/U wt 220K-Ibs, S/O wt 144K-Ibs, 2-BPM at 600-psi. Ta~q top of fish at 10,411', continue RIH and put 10K-Ibs on spear. P/U but see no extra weight on spear. RIH and set down 10K-Ibs, P/U and do not see extra weight. Make one half right-hand rotation. RIH and stack out with 10K-Ibs, P/U and do not see extra weight. Start rotating at 10-RPM, Rot wt 165K-Ibs 5K-Ib-ft free torque, 3.5-BPM at 1,390-psi; RIH and see pump pressure go to 1,600-psi and see weight indicator flutter several times. Stop rotating and continue to set down to 15K-Ibs on spear. P/U and weight indicator goes to 225K-Ibs and suddenly drops back to 220K-Ibs. RIH and make another 2' in to 10,413' after stacking out to 15K-Ibs on spear. P/U to 250K-Ibs and pops free. RIH with pump on 3.5-BPM at 1600-psi and pressure increases to 2,000-psi. P/U to neatral and put two full left-hand turns to re-seat grapple. Set down to 20K-Ibs on spear. P/U to make sure grapple is set. S/O to 20K-Ibs weight on spear. P/U to 245K-Ibs and weight drops off to 225K-Ibs or 5K-Ibs extra weight. Continue out one full joint and RBIH to verify, but stack out 2' higher at 10,411'. P/U one full joint of DP seeing the same 5K-Ibs extra weight, then RBIH to verify and stack out another 2' higher at 10,409'. P/U one joint of DP and see the same 5K-Ibs extra weight. Drop ball to open pump-out sub and call ADW engineer. Circulate 10-BPM at 1,490-psi, 20-Bbls Hi-Vis sweep all the way around, get loss rate of 6-BPH. Don't see any gas during the circulation. The ditch magnets collected a small amount of metal flakes, less than a pint. POH and S/B DP in Derrick. The drag for the first 5-stands is as high as 20K-Ibs over string weight. 20-stands POH at 1640-hours. Using constant hole fill while POH. Losing 12-14-BPH while 0.50 CLEAN P DECOMP L/D Int Jar, tan ac Drill Collars, No Fish Recovery, Grapple in the Release Position. 0.50 CLEAN P DECOMP Clear and Clean The Rig Floor. Printed: 2/27/2008 2:57:42 PM ~ • BP EXPLORATION Page 16 of 21 Operations Summary Report (Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours. Task Code NPT Phase Description of Operations 2/6/2008 20:30 - 21:00 0.50 CLEAN P DECOMP Clean Grapple, Rebuild Pump Out Sub, Wait on Orders. Loss rate 6 bph. 21:00 - 00:00 3.00 CLEAN P DECOMP Run same assembly RIH to 7724'. 2/7/2008 00:00 - 00:30 0.50 CLEAN P DECOMP Continue to RIH and tagged up at 7,724' which is 13' deeper than the liner top. M/U Top drive and circulated at 3.5 bpm P/U and Rotated pipe several times and worked into liner top. 00:30 - 04:00 3.50 CLEAN P DECOMP B/D Top Drive, Continue to RIH to 10,387' obtain parameters: up weight=213,000#, down weight=148,000#, 40 spm, 1460 psi. Washed down to 10,406' tagged up on wash pipe, had to P/U and rotate drill pipe several times to work in the spear. Tagged up on tubing at 10,410' had to pick up and orientate spear several time to get into the tubing as well. 2' into tubing pump pressure increased to 3,500 psi, picked up and washed back down and continued into tubing No-Go at 10,419' pump pressure increased to 1,930 psi. Latched grapple and pulled up to 275,000# and let the jar fire, pulled to 325,000# twice. Cocked jar on the third attempt jar fired and weight dropped to 150,000# Stacked 15,000 # on tubing, Pulled up 213,000# and pulled up to 10,387', Attempt to go back down with it and began taking weight at 10,397' Repeated to confirm 2X, engaged pumps at 3.5 bpm and had same pump pressure as we had on bottom 1,930 psi. Showing no-go pressure with fish off bottom. 04:00 - 05:00 1.00 CLEAN P DECOMP Dropped circ sub dart and opened circ sub. CBU ~ 12 bpm with 2180 psi, monitor well ,pump 15 bbl dry job and B/D T/D. 05:00 - 07:00 2.00 CLEAN P DECOMP POOH from 10,419'. Increase in string weight coming out of the 7" liner, additional 8-10,000# of drag while POOH. 07:00 - 07:30 0.50 CLEAN P DECOMP S/D operations to hold Dog House safety meeting to discuss a STOP Card that concerned transfer of rig cleaning chemicals in non-approved containers. All crew members understand the potential dangers associated with transferring any chemical. 07:30 - 09:00 1.50 CLEAN P DECOMP Resume POOH and S/B DP in Derrick. 75-stands POH at 0745-hrs. 85-stands at 0800-hrs. S/B 2-stands of DCs at 0900-hrs with fish-on. 09:00 - 10:30 1.50 CLEAN P DECOMP PJSM to punch tubing fish and B/O and UD fish. The fish consisted of the milled XO below the packer and the two 10' pup joints below the XO. Fish recovered:.45' of 4-1/2" x 3-1/2" XO, 9.40' pup joint, and 9.70' pup joint for 19.55' total recovery. -23' of tail i e remain in the well. The pin end of the bottom pup joint appears to have been damaged by setting it down on top of the washover pipe. Discuss with the ADW engineer and decide to RIH to retrieve the washpipe. , 10:30 - 11:00 0.50 CLEAN P DECOMP Clear an c can ig oor an ga er up the BHA for fishing the washpipe. 11:00 - 12:00 1.00 CLEAN P DECOMP PJSM. M/U washpipe fishing BHA: Itco Spear with 4.961" grapple and bullnose mill, Stop sub with 5-7/8" stop, Bumper Sub, Oil Jar, Pump-out Sub, 2-stands 4-3/4" DCs and Bowen Intensifier. 12:00 - 14:30 2.50 CLEAN P DECOMP RIH washpipe BHA on DP from Derrick. 55-stands at 1325-hours. 14:30 - 21:00 6.50 CLEAN P DECOMP P/U and M/U stand #108, get parameters: Up wt 212,000-Ibs, Dn wt 145,000-Ibs; pump rate 4-BPM at 340-psi. Continue to RIH and tag at 10411', slowly RIH and see pressure increase Printed: 2/27/2008 2:57:42 PM • • BP EXPLORATION Page 17 of 21 Operations Summary Report Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To ~ Hours Task Code NPT Phase Description of Operations 2/7/2008 14:30 - 21:00 6.50 CLEAN P DECOMP to 560-psi, set down 15,000-Ibs to get 32' in on stand #108. P/U to 38,000-Ibs over string weight and let jars go off. Set back down and no-go at 10,406'. Begin jarring operations and make -30' of progress uphole within 4-whacks, but stop to set back stand #108 and P/U a single joint of DP to continue jarring operations by pulling to 325,000-Ibs, letting jars fire then dead pull up to 375,000-Ibs, set back down to 140,000-Ibs to re-cock the jars, then repeat the process a multiplicity of times. Fluid loss rate increased to 12-13-BPH. Final Tag Depth of 1b~$" 21:00 - 22:00 1.00 CLEAN P DECOMP Pull up to neutral weight to release spear, put 12 wraps to the right with 10,000# of torque. Pulled up to 300,000# several times attempting to release the spear, P/U out of fish with spear, Sting back into fishand set spear to verify no damage to fish or spear. 22:00 - 22:30 0.50 CLEAN P DECOMP Monitor wellbore, pump dry job, blow down top drive, UD single. 22:30 - 23:30 1.00 CLEAN P DECOMP Perform Derrick and Top Drive Inspection. 23:30 - 00:00 0.50 CLEAN P DECOMP POOH with Spear Assembly from 10,380' to 9,528'. 2/8/2008 00:00 - 03:30 3.50 CLEAN P DECOMP Continue to POOH from 9,528' ,worked tight hole at 8,294' had to M/U Top Drive engage pumps at 4 bpm and rotate pipe to pull past 8,298'. Continue to POOH to 227'. 03:30 - 05:00 1.50 CLEAN P DECOMP Stand back Drill Collars and UD Spear Assembly, Intensifiers and Oil Jar ,Bumper Jar. 05:00 - 06:00 1.00 CLEAN P DECOMP P/U New Jar, Bumpers, Intensifier, M/U new Spear RIH with Drill Collars. 06:00 - 09:30 3.50 CLEAN P DECOMP RIH BHA on DP from Derrick. 09:30 - 00:00 14.50 CLEAN P DECOMP Stop at stand #106, P/U single, and RIH on stand #107. Get parameters: P/U wt 212,000-Ibs, S/O wt 146,000-Ibs, Pump Rate 4.0-BPM at 1,150-psi. RIH and tag washpipe fish at 10,380'. Work into washpipe and watch prssure increase to 2,600-psi. Work pipe jarring up, then alternately jarring down ~20-cycles each. Continue alternating at 20-30-cycles each. Jarring up as high as 400,000-Ibs and setting down to 110,000-Ibs. Losses increased to 130-BPH, while pumping at 5-BPM at 1300-hours. At 1500-hours the calculated loss rate increased to 440-BPH while pumping at 6-BPM. Slowed pump rate down to 1-2-BPM. Made about 4' of upward progress by 1530-hours. Made total 6' of upward movement as of 1600-hours. At 1600-hours, calculated loss rate decreased to 20-BPH while pumping at 1-2-BPM. Continue to Jar until crew change, discussed options with Anchorage engineering, decision made to release from fish. Top of Washpipe Fish at 10,374'. 2/9/2008 00:00 - 04:00 4.00 CLEAN P DECOMP Attempt to Release Spear from Washpipe Fish, combination of working torque into string 11,000 ft-Ibs Max and jarring and applying weight, over pull 140,000# Max, pumping at 2.5 bpm and 1,000 psi, using various combinations of the above. Grapple released at 04:00. 04:00 - 05:00 1.00 CLEAN P DECOMP Complete Derrick and Top Drive Inspection while Circulating Bottoms up. 30-BPH calculated fluid loss rate while circulating 14-BPM at 3,400-psi. 05:00 - 05:30 0.50 CLEAN P DECOMP Monitor wellbore, pump dry job, B/D Top Drive. Printed: 2/27/2008 2:57:42 PM • • BP EXPLORATION Page 18 of 21 Operations Summary Report Legal Well Name: F-17A Common Weil Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: I Date ,From - To ~ Hours Task Code NPT Phase Description of Operations 2/9/2008 05:30 - 10:00 4.50 CLEAN P DECOMP POOH from 10,326'. 12-BPH fluid loss rate while POH. Slow down at 8,300' to prepare to rotate through the Liner Lap. 10:00 - 11:00 1.00 CLEAN P DECOMP S/B DCs and break-out and UD BHA. The grapples were in good shape. 11:00 - 12:00 1.00 CLEAN P DECOMP Change out Grabber Cushions on Top Drive. 12:00 - 13:00 1.00 CLEAN P DECOMP N/D drilling riser and bell nipple. 13:00 - 13:30 0.50 CLEAN P DECOMP N/U Shooting Flange. 13:30 - 14:30 1.00 CLEAN P DECOMP PJSM. R/U Schlumberger full pressure control equipment and test lubricator and BOP to 3,000-psi. Took 50-Bbls to fill hole after being S/I for 3-hours. Use constant hole fill of 30-BPH. 14:30 - 17:15 2.75 CLEAN P DECOMP RIH with 4.00" LIB and 4.34" tapered swedge. Did not see 7", 26# Liner top at 7211' or the Liner Lap at the 7", 29# Liner Top at 8,257' while RIH. Lightly tag the top of the washpipe fish at 10,380' then continue R slow y o u tag on top o the 3-1 2 tail i e fish at 10 43 an ag ar er on ai pipe is . 17:15 - 18:00 0.75 CLEAN P DECOMP POH to evaluate LIB. Did not see any bobble on weight to indicate the bottom of the washpipe washover shoe at +/-10,410'. Break out lubricator and UD the LIB. Unmistakable im ression of the top of the fishing neck of a PX ron~g: 18:00 - 20:00 2.00 CLEAN P DECOMP RIH with PX Prong pu ing oo . a some i icu y ge ing Prong puller through the Wash Pipe. Attempted to pull Prong, 20:00 - 20:30 0.50 CLEAN P DECOMP POOH with retrieval tool. NO latch on Prong got on to fishing neck but sheared out and unlatched. Re-pinned retrieval tool and RIH run #2. 20:30 - 21:00 0.50 CLEAN P DECOMP Re-pinned Retrieval tool, M/U to tool string on the rig floor. 21:00 - 22:00 1.00 CLEAN P DECOMP RIH with Prong Retrieval Tool with 4.34" swedge. 22:00 - 22:30 0.50 CLEAN P DECOMP POOH with Prong Retrieval tool, No recovery of Prong. 22:30 - 23:00 0.50 CLEAN P DECOMP Rebuild Prong retrieval tool, M/U to tool string. 23:00 - 00:00 1.00 CLEAN P DECOMP RIH with retrieval tool. Approx 26 bph losses to Wellbore. 2110/2008 00:00 - 01:00 1.00 CLEAN P DECOMP Continue to R1H to Prong, Multiple attempt to latch. POOH, No Prong. SLB Service Quality Supervisor Came to the unit and Re-dressed tools, On the first attempt we had a Latch and Sheared out. On later runs longer prong catcher was used to get through the Washpipe area. On the 4th run we are going back to the first configuration with a down shear release. 01:00 - 02:30 1.50 CLEAN P DECOMP Re-configure pulling tool, and adjust sheave at rig floor. 02:30-03:30 1.00 CLEAN P DECOMP Run #4 RIH with JDC Pulling tool with bell guide to engage Prong. 03:30 - 04:30 1.00 CLEAN P DECOMP POOH with JDC and Prong. 04:30 - 05:00 0.50 CLEAN P DECOMP SLB to Cut Wire, and R/U to ull PX Plug. 05:00 - 08:00 3.00 CLEAN P DECOMP RIH with PX Plug Retrieval Tool. Work slickline. Stop hole fill to reduce head on plug. 08:00 - 09:30 1.50 CLEAN P DECOMP POH with no PX plug on the "hook". Call ADW Engineer and decide to make Junk Bailer runs, then RBIH with the GR tool to latch onto and pull the PX plug. 09:30 - 10:00 0.50 CLEAN P DECOMP M/U Junk Bailer to slickline and RIH to bail off the PX plug. 10:00 - 10:30 0.50 CLEAN P DECOMP POH with Junk Bailer. Find 8-oz of "drilling mud stuff" in bailer. 10:30 - 12:00 1.50 CLEAN P DECOMP RIH with GS retrieving tool. Could not get latched onto plug. Suspect fill is the problem. 12:00 - 12:30 0.50 CLEAN P DECOMP POH with GS retrieving toool and find that setdown pin had sheared, probably when the tool stacked out on the top of the Washpipe fish. 12:30 - 13:00 0.50 CLEAN P DECOMP RIH with 4.34" swedge and GS retrieving tool. Work tool, latch Printed: 2/27/2008 2:57:42 PM • BP EXPLORATION Page 19 of 21 Operations Summary Report Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours ~' Task Code NPT Phase ~ Description of Operations 2/10/2008 12:30 - 13:00 0.50 CLEAN P DECOMP up and looks like 40-Ibs added to the string. 13:00 - 13:30 0.50 CLEAN P DECOMP POH with GS tool and do not have plug. 13:30 - 14:30 1.00 CLEAN P DECOMP Change out GS to GR retrieving tool and TIH. Latch up in plug and set off jars a multiplicity of times. Shear out of plug. 14:30 - 15:30 1.00 CLEAN P DECOMP POH with GR retrieving tool and gather tools for next run. 15:30 - 18:00 2.50 CLEAN P DECOMP M/U GS retrieving tool with 2.72" swedge and RIH. Work jars for 1-hour with no retrieval of the plug. The well has not had a drink since 0700-hours. 18:00 - 19:00 1.00 CLEAN P DECOMP POOH with GS Retrieval Tool, Jar. 19:00 - 20:00 1.00 CLEAN P DECOMP R/D SLB wireline BOPs, Lubricator, and Sheaves. 20:00 - 21:00 1.00 CLEAN P DECOMP R/D Shooting Flange, Nipple up Flow Riser, Change out Saver Sub. 21:00 - 22:00 1.00 CLEAN P DECOMP Bring BHA tools to Rig Floor, and steam off Ice. 22:00 - 23:00 1.00 CLEAN P DECOMP M/U BHA #18 Hydraulic GS Spear. W.ellbore took 94 bbls to fill. Loss rate to keep the wellbore full is 13.2 by a cu a e ui level 1,284'. 23:00.- 00:00 1.00 CLEAN P DECOMP RIH to 2,2 '. 2/11/2008 00:00 - 03:00 3.00 CLEAN P DECOMP RIH with GS spear from 2,218' to 2,501', Break Circulation at 2 bpm with 2,820 psi. Continue to RIH to 10,370' 03:00 - 04:00 1.00 CLEAN P DECOMP Establish Circulation at 3 bpm with 3330 psi. Circulate a Drill Pipe volume B/D T/D. 04:00 - 05:00 1.00 CLEAN P DECOMP Obtain Parameters: Up Weight=215,000#, Down Weight 147,000#, Tag Top of Fish at 10,431'. Set max 15,000 # Down Weight, Jar up with 20,000# over string weight 3X, dead pull 30,000# over and weight indicator broke over. 05:00 - 10:30 5.50 CLEAN P DECOMP POOH from 10,431'. 30-stands out at 0650-hours. 61-stds at 0745-hours. 10:30 - 13:30 3.00 CLEAN P DECOMP Breakout and UD Intensifier, and S/B 4-3/4" DCs. B/O and UD Jars and Bumper Sub. Release PX plug from GS spear. B/O and UD 2-7/8" PAC DCs. RIH with 4-3/4" DCs and POH and UD through the Pipe Shed. 13:30 - 16:00 2.50 CLEAN P DECOMP RIH with DP from Derrick. 16:00 - 17:00 1.00 CLEAN P DECOMP Slip and Cut Drilling Line 115'. 17:00 - 00:00 7.00 CLEAN P DECOMP POH and UD DP through Pipe Shed. From 10,252' to 3225'. 2/12/2008 00:00 - 01:00 1.00 CLEAN P DECOMP Continue to POOH Laying down drill pipe. 01:00 - 01:30 0.50 BUNCO RUNCMP Pull Wear Ring. 01:30 - 03:30 2.00 BUNCO RUNCMP R/U Casing tongs ,Torque Turn Equipment, Compensator, Bails and Elevators. 03:30 - 04:00 0.50 BUNCO RUNCMP Waiting on Casing Torque Turn Equipment difficulties getting Equipment running. 04:00 - 10:00 6.00 BUNCO RUNCMP P/U and RIH with 4-1/2", 12.6-Ib, 13CR-80 Vam To o etion. 4,400-Ib-ft optimum makeup torque, using Jet Lube ea uar thread compound, and Torque Turning all connections. Baker-Lok all connections below the packer. Using constant hole fill with calculated loss of 18-BPH. Replaced joint #35 with a spare from outside the Pipe Shed. 10:00 - 12:00 2.00 BUNCO RUNCMP Limit switches failed on Pipe Skate. Make repairs and hold meeting to discuss hazards and prepare a written Hazard Assessment. 12:00 - 19:00 7.00 BUNCO RUNCMP Continue RIH with a total of 231 joints of 4-1/2", 12.6-Ib, 13CR-80, Vam Top Completion. 4,400-Ib-ft optimum makeup torque, using Jet Lube Seal Guard thread compound, and Torque Turning all connections. Printed: 2/27/2008 2:57:42 PM • ~ BP EXPLORATION Page 20 of 21 Operations Summary Report Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: ~ I Date From - To Hours Task Code NPT Phase ' Description of Operations 2/12/2008 19:00 - 20:00 1.00 BUNCO RUNCMP P/U landing joint and M/U to tubing hanger. Run hanger in hole and RILDS. R/D tubing tongs and tubing running equipment. 20:00 - 21:00 1.00 BUNCO WAIT RUNCMP Waiting on Vac trucks with hot seawater for displacement. Continue cleaning rig floor. Keep hole full by reverse circulating. Pump rate at 3 bpm with 150 psi. Loss rate at 23 bph. 21:00 - 22:00 1.00 BUNCO RUNCMP Vac trucks arrived on location. Spot vac trucks and R/U to pump inhibited seawater. 22:00 - 00:00 2.00 BUNCO RUNCMP Displace well over to corrosion inhibited seawater by reverse circulating at 3 bpm with 150 psi. Pump 150 bbls of 120 deg F seawater followed by 480 bbls of 120 deg F seawater treated with Correxit EC-1124A at a ratio of 168:1 or 25 gallons for 100 bbls. 2/13/2008 00:00 - 02:00 2.00 BUNCO RUNCMP Continue displacing well over to corrosion inhibited seawater by reverse circulating at 3 bpm with 150 psi. Pump 150 bbls of 120 deg F seawater followed by 480 bbls of 120 deg F seawater treated with Correxit EC-1124A at a ratio of 168:1 or 25 gallons for 100 bbls. 02:00 - 02:30 0.50 BUNCO RUNCMP PJSM. R/U and test circulating lines to 4500 psi. Drop Baker ball and rod and allow to seat. 02:30 - 03:00 0.50 BUNCO RUNCMP Pum down tubing to set packer with 4500 psi. Hold pressure for 5 minutes or pac er o se comp e e y. ee o pressure. 03:00 - 03:30 0.50 BUNCO RUNCMP ressure up 3 .c a e mmu es, goo es . ee o pressure to 1500 psi. 03:30 - 04:00 0.50 BUNCO RUNCMP Pressure u on annulus. Test acker to 3500 si. H I t 30 charted minutes, good test. 04:00 - 04:30 0.50 BUNCO RUNCMP Bleed off pressure on tubing to shear DCK valve with 2500 psi differential pressure. Pump both ways through DCK valve at 2 bpm with 230 psi. 04:30 - 05:00 0.50 BUNCO RUNCMP R/U and set TWC as per FMC Tech. 05:00 - 06:30 1.50 BUNCO RUNCMP R/U and test TWC to 1000 psi from below and 3500 si from above. Charte oth or 10-minutes--good tests. 06:30 - 07:00 0.50 BUNCO RUNCMP B/O and an mg om . 07:00 - 08:00 1.00 BOPSU P RUNCMP PJSM. N/D BOPE. 08:00 - 10:00 2.00 WHSUR P RUNCMP PJSM. N/U adaptor flange and torque stud nuts. Purge and test neck seals to 5,000-psi for 30 charted minutes. 10:00 - 11:00 1.00 WHSUR P RUNCMP Remove and repair LDS and gland nut on 9-5/8" spool per an earlier workorder from Wells group. 11:00 - 12:30 1.50 WHSUR P RUNCMP N/U tree. Torque all studs and nuts with Sweeney Wrench. 12:30 - 14:30 2.00 WHSUR P RUNCMP PJSM. Fill tree with diesel and function all valves to ensure diesel displaced into valve cavities. FMC tested new LDS on Casing head to 4,500-psi. Test tree to 5,000-psi for 30 charted minutes for rock solid test. 14:30 - 15:30 1.00 WHSUR P RUNCMP R/U Lil Red for freeze protect operations. R/D Derrick equipment including tong hanging lines and tongs; secure cables in Derrick. 15:30 - 16:30 1.00 WHSUR P RUNCMP P/U DSM lubricator and PT to 500-psi. Pull TWC, no pressure under TWC, pull TWC, VD lubricator. 16:30 - 17:00 0.50 WHSUR P RUNCMP PJSM with LRHOS and rig crew. Cover freeze protection operations and procedures. 17:00 - 18:00 1.00 WHSUR P RUNCMP Pressure test surface lines to 2500 psi. Pump 150 bbls of diesel with LRHOS for freeze protection at 2 bpm with 600 psi. Printed: 2/27/2008 2:57:42 PM • • BP EXPLORATION Page 21 of 21 Operations Summary Report Legal Well Name: F-17A Common Well Name: F-17A Spud Date: 12/29/1994 Event Name: WORKOVER Start: 1/19/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 2/13/2008 Rig Name: DOYON 16 Rig Number: Date ~ From - To ~ Hours Task Code NPT Phase Description of Operations 2/13/2008 17:00 - 18:00 1.00 WHSUR P RUNCMP 18:00 - 19:00 1.00 WHSUR P RUNCMP Tie tubing with annulus and allow well to U-tube to protect the top 2200' of well. 19:00 - 19:30 0.50 WHSUR P RUNCMP B!D freeze protection lines and monitor well. 19:30 - 20:00 0.50 WHSUR P RUNCMP Set BPV. Test BPV to 1000 psi from below for 10 charted minutes, good test. Bleed off pressure. 20:00 - 21:00 1.00 WHSUR P RUNCMP B/D freeze protection lines for LRHOS. R/D LRHOS. B/D mud manifold, bridle up derrick, R/D floor, remove 2nd annulus valve and secure cellar. Release rig at 21:00 hours 2/13/2008. Printed: 2/27/2008 2:57:42 PM Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, February 12, 2008 4:25 PM To: 'Roach, Frank' Cc: Reem, David C ~, ~ (p Subject: RE: F-17A (PTD: 194' new completion Frank and Dave, Unfortunate on the new debris in the well. Moving the packer shallower is not an issue. I will place a copy of this message in the file. Tom Maunder, PE AOGCC From: Roach, Frank [mailto:Frank.Roach@bp.com] Sent: Tuesday, February 12, 2008 2:25 PM To: Maunder, Thomas E (DOA) Cc: Reem, David C ~~ FEB 1 2 200 Subject: F-17A (PTD: 194-630) new completion Mr Maunder, «F-17A PROPOSED a NEW.pdf (Compressed)» Per our phone conversation, the change to the F-17A (producer) completion is as follows: The 7" x 4-1/2" Baker S-3 completion packer has moved from an anticipated set depth of 10,360' MD to ^9810' MD. This 550' movement will allow the well to be recompleted without recovering two fish in the well and also allow the option of a big bore CTD sidetrack at a later date. With the packer now at 9810', the end of the 4-1/2" tailpipe will be at 9900' MD. This will allow 100' CTD BHA to be in the 7" liner before kicking off at 10,000' MD. I have attached a wellbore schematic to illustrate the locations of the two fish and new completion. Please let me know if there is furfiher clarification needed. Regards, -Frank Roach 2/12/2008 TRFF= 4-1/16" FMC WELLHEAD =~ _FMC ACTUATOR= BAKER KB. ELEV = BF. ELEV = 65.6' 38.96' KOP = Max Angie = 2300' 95 @ 10959' Datum MD = __ _ 1038_1 ~ Datum TV D = 8800' SS ~ 13-318" CSG, 72#, L-80, iD = 12,347" 7" LNR, 26#, L-80, .0382 bpf, ID = 6.276" - TOP OF TNV 7" LNR 827 Minimum ID = 2.750" @ 2033' OTIS HXO SSSV NIPPLE PERFORATION SUMMARY REF LOG: ? ANGLEATTOPPERF:91 @ 11185' Note: Refer to Production DB for historical perf data SIZE 5PF INTERVAL Opn/Sqz GATE 2-3/4" 4 11185 - 11460 C 03/18/95 2-1/2" 4 11482- 11562 C 03/18/95 2-112" 4 1173$ - 11758 C 09!21/95 2-3i4" 4 11850 - 12200 C 09/21!95 4-1/2" TBG, 12.6#, 13Cr-80 Vam Top, .0152 bpf, ID = 3.958" -- p ~ ~ ~ ?~, SA' '.NOTES: HOF2IZONTAL W ELL, 70° @ P R®007 E ~ 108~AND 90° @ 10803' I TOP OF 4-112" Liner ( ~ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ] PBTD ~ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 1431• I TOP OF3-1/2"TAILPIPE FISH, MIN ID = 2.750", LENGTH OF FISH = 23' 10470' ELMD TT LOGGED 02!02195 ,' 10465 a-1x2"BxRISOLATiON PKR, ID = ? DATE REV BY COMMENTS DATE REV BY COMMENTS 01!16/95 MDO SIDETRACKCOMPLETION 02!02/85 DTR LAST WORKOVER 07/12/03 CMO/TLP KB ELEVATION, MAX ANGLE 10/20/06 GJF/PAG GLV GO (10/18/06) 04/01/07 JMF/PJC SET PX PLUG @ 10395' (10/31/06) PRUDHOE BAY UNff WELL: F-17A PERMff No: x1941630 API No: 50-029-20652-01 SEC 2, T11 N, R13E, 2215' FSL & 2197' FEL BP 6cploration (Alaska) 4-112" HES X NIP, ID = 3.813" GA5 Lii--T MANDRELS iT MD TVD DEV TYPE VLV LA7 2 3609 3500 4-1/2" Y' 1 6721 5800 4-1/2" 1" 9-5I8" X 7" BKR G2 ZXP LTP w / FLEXLOCK I LNR HGR, ID = 6.290" MILLOUT WINDOW (F-17A~ 8478' - 8528' ~! J-]d-112" HES X NIP, ID = 3.813" I _____~^~~ 7" X 4-1/2" BKR S-3 FKR ID - 3.875" 4-112" HES X NIP, ID = 3.813" 4-1/2" WLEG 10374' TOP OF 5-314" WASHPIPE FISH, MIN ~ ID = 4.750", LENGTH OF FISH = 32' • 9 ~ ~ # ~ ~ ~ t SARAH PALIN GOVERNOR ~.d , ~~ taisCa-7~A OIIt AID ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5EB'QA'1`IO1~T CODil-II5SI011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 ~ ~ ~~~~ Anchorage, Alaska 99519-6612 ~ ~A~ r _~ ~/ ~~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU F-17A Sundry Number: 308-006 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this /J day of January, 2008 Encl. ,~'~~,\ ~~V STATE OF ALASKA ~'~ ~~~1~ ALAS~IL AND GAS CONSERVATION COMM N ~'" APPLICATION FOR SUNDRY APPROVAL ~-~~`~ JAN ~ ~1QQ8 20 AAC 25.280 ~pfla4, ~iQ~~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Tt~~i~ 3 ~ A~ ~ ~ ,~/j/ (Alter Casing ® pair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspe~nti~~~Q~ (~~ ^ Change Approved Program ull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 194-163 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20652-01-00~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU F-17A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028281 ~ 65.58' ' Prudhoe Bay Field / Prudhoe Bay Pool 12: PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):. 12300 ~ 9054 12214 9052 10395 None Ca in L n h Siz MD TVD B r oll e Struct ral n to 11 rface 11 110' Surfa 2720' 13-3/8" 2720' 2708' 4930 2 70 Interm di to 8478' 9-5/8" 8478' 7082' 6870 47 Pro i n Liner 2535' 7" 277' - 10812' 6 1' - 9068' 816 7020 Lin r 1842' 4-1/2" 10458' - 1230 ' 8929' - 9054' 8430 750 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11185' - 12200' 9053' - 9052' 3-1/2", 9.2# L-80 10457 Packers and SSSV Type: 7" x 3-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 10409' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: January 25, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Frank Roach, 564-4373 Printed Name vid Reem Title Engineering Team Leader Prepared By Name/Number: _ Signature Phone 564-5743 Date I~ b Terrie Hubble, 564-4628 Commission Use Onl Sundry Numb r: Conditions of approval: Notify Commission so that a representative may witness 2~ ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance `~"~- ~~ Other: ~j ~~o (7S<i v~~ ~5 `'C' Subsequent Form Required: ~~~ A roved B O I SIONER THE OMMISSION Date /,) Form 10-403 Revised 06/2006 ~./ ~-~ ~~~~:.f~a~ ~ ~ ". Ob ORIGINAL Submit In Duplicate ~~~ by ~'~YaQrP~ad/~ei8ac F-17A Rig Workover • Scope of Work: Pull 3-%2" L-80 completion, find leak in casing and restore integrity through either 7" scab liner over 9-5/8" casing, 4-1 /2" scab liner over 7" production liner, or short 7" scab liner to cover leaking existing 7" liner top packer, recover production packer, replace 9-5/8" pack-offs, and run 4'h" 13Cr80 completion. MASP: 2543 psi Well Type: Producer Estimated Start Date: January 25, 2008 Pre- Ri O 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well is secured at this time with 3- %2" PX lu 10/31/2006 set . PPPOT-T. S 2 Pull PX prong and plug in nipple at 10395' MD. Drift tubing for PX plug and tubing cut to 10445' MD. Set PX plug at 10426' MD (Ref 01/16/1995 tubing summary. PX plug desired to be in 1St ni le rofile below SABL-3 acker . E 3 Power Jet cut 3 %2" tubing @ 10398' MD (Ref 01/16/1995 tubing summary). Jet cut desired to be in the to 2' of the u ~oint above packer. F 4 Circulate well with seawater and cap with diesel thru the cut. MITOA to 2000 psi. Bleed WHPs to 0 si. No CMIT re uired due to PC leak. F 5 Circulate well with seawater and FP w/diesel thru the cut. Bleed WHP's to 0 si. O 6 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the ri . Pro posed Procedure 1. MIRU. ND tree. NU and test ROPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean 9.8 ppg brine through the cut. 2. Pull and LD 3-%" tubing string to the cut. 3. Locate the casing leak in the well. The leak is either in the 9-5/8" production casing, 7" production liner, or the 7" liner top packer. 4. Restore casing integrity with one of the three scab liners listed below: a) If the leak is in the 9-5/8" casing, run 7" scab liner to 3000' and cement to top of liner. b) If the leak is in the 7" liner, run 4-%2" chrome scab liner and set the scab liner top in the 9-5/8" casing just above the 7" liner top (8200') and cement to top of scab liner. c) If the leak is in the 7" liner top packer, run short 7" scab liner. With all three options above, pressure test to 3500 psi for 30 charted minutes before drilling out shoetrack (options "a" and "b") and/or continuing with workover operations (option "c"). 5. Mill and retrieve 3?/2" x 7" production packer and tailpipe. 6. Run 4 %2" 13Cr80 completion with Baker S-3 packer. Position packer to be determined by what scab liner in step 4 is run (if option "a" or "c" is run, the packer will be set at 10350'. If option "b" is run, the packer will be set at 8100'). 7. Displace the IA to packer fluid and set the packer. 8. Test tubing and IA to 3500 psi. Freeze protect to 2000' MD. 9. Set BPV. ND BOPE. NU and test tree. RDMO. TREE= 3-1/8" FMC (W-4" QUl WELLHEAD= FMC ACTUATOR = BAKER KB. ELEV = 65.6' BF. ELEV = 38.96' KOP = 2300' Max Angle = 95 (~ 10959' Datum MD = 10381 Datum TV D = 8800' SS L 13-3/8" CSG, 72#, L-80, D = 12.347" ~ 27; Minimum ID = 2.750" ~ 2033' OTIS HXO SSSV NIPPLE TOP OF TMJ 7" LNR ~-~ $277' PERFORATION SUMMARY REF LOG: ? A NGLE AT TOP PERF: 91 ~ 11185' Note: Refer to Production DB for histor~al pert data SIZE SPF NJTERVAL Opn/Sqz DATE 2-3/4" 4 11185 - 11460 C 03/18/95 2-1/2" 4 11482 - 11562 C 03/18/95 2-1/2" 4 11738 - 11758 C 09/21/95 2-3/4" 4 11850 - 12200 C 09/21/95 SAFELY NOTES: HOW20NTAL WELL, 70° ~ 10667' AND 90° ~ 10803' F-17A 2033' H3-1@" OTIS HXO SSSV LAND NP, D = 2.75" • GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4706 8196 4303 6852 42 43 FMHO FMHO DMY DMY RK 0 RK 0 10!18/06 10/18/06 M~LOUT WINDOW (F-17A) 8478' - 8528' 3-1/2" TBG, 9.2#, L-80 NSCT, .0087 bpf, D = 2.992" ~ 1045T TOP OF 4-1/2" 104 ~ 7" LNR, 29#, L-80, .0371 bpf, D = 6.184" ~ 1/2" LNR, 12.8#, L-80, .0152 bpf, D = 3.958" H 12300' ~-~ 3-1 /2" PKR SWS N~, D = 2.750" ~ 5~ 3-1/2" PX PLUG (10/31/06) 10409' 7" X 3-1/2" BKR S-3 PKR W/K-22 ANCHOR, D = ? 10434' 3-1/2" HES X N~, D = 2.750" 10445' 3-1/2" HES X N~, ID = 2.750" 1045T ~3-1/2" WLEG, D=? 10470' ELMD TT LOGGED 02l02/95~ ` 10465' 4-1/2" BKR ISOLATION PKR, D = ? DATE REV BY COMMENTS DATE REV BY CONSENTS 01/16/95 MDO SIDE TRACK COMPLETION 02/02/85 DTR LAST WORKOV6t 07/12/03 CMO/TLP KB ELEVATION, MAX ANGLE 10/20!08 GJF/PAG GLV GO (10/18/06) 04/01!07 JMF/PJC SET PX PLUG 10395' (10/31/08} PRUDHOE BAY INJIT WELL: F-17A PERMR No: 1941630 AF1 No: 50-029-20852-01 SEC 2, T11 N, R13E, 2215' FSL 8 2197' FEL BP Exploration (Alaska) Tf2EE= 3-1/8" FMC (W-4" OUl WELLHEAD = FMC ACTUATOR= BAKER KB. ELEV = 65.6' BF. ELEV = 38.96' KOP = 2300' Max Angle = 95 Q 10959' Datum MD = 10381 Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ~ = 12.347" I 9-5/8" X 7" BKR G2 ZXP LTP w! FLEXLOCK I LNR HGR, ID = 6.290" GAS LIFT MANDRELS 7" LNR, 26#, L-80, .0382 bpf, ID = 6.276" TOP OF TNV 7" LNR - Minimum ID = 2.750" ~ 2033' OTIS HXO SSSV NIPPLE PERFORATION SUMMARY REF LOG: ? ANGLEATTOPPERF:91 @ 11185' Note: Refer to Productan DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 4 11185 - 11460 C 03/18!95 2-1l2" 4 11482 - 11562 C 03/18/95 2-1/2" 4 11738 - 11758 C 09/21!95 2-3/4" 4 11850 - 12200 C 09/21/95 4-1/2" TBG, 12.6#, 13Cr-80 VamTop, .0152 bpf, ID= 3.958" TOP OF 4-1/2" Lamer 17" LNR, 29#, L-80, .0371 bpf, D = 6.184" I ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3609 6721 3500 5800 4-112" 4-1/2" 1" 1" MLLOUT WINDOW (F-17A) 8478' - 8528' 14-i/2" HES X NIP, ID = 3.813" 1 7" X 4-1/2" BKR S-3 PKR ID = 3.875" 4-1/2" HES X NIP, ID= 3.813" 1 14-1/2" L1~2, 12.6#, L-80, .0152 bpf, D = 3.958" I DATE REV BY COMu~iTS DATE REV BY COMMENTS 01118l8S MDO SIDE TRACKGOMPLEfION 02/02195 DTR LAST WORKOVER 07/12/03 CMO/TLP KB ELEVATION, MAX ANGLE 10/20/06 GJF/PAG GLV GO (10/18/06) 04/01!07 JMF/PJC SET PX PLUG (~ 10395' (10/31/06) J--j4-1/2" WLEG 10470' ELMD TT LOGGED 02!02/95 10465 4-1/2" BKR ISOLAT~N PKR, D = PRUDHOE BAY UNR WELL: F-17A PERMff No: 1941630 API No: 50-029-20652-01 SEC 2, T11N, R13E. 2215' FSL & 2197' FEL ~ Drplorstion (Alssks) F-17A sA~r'NOTES: r~zoarAL we_L, 70~ ~ PROPOSED +os6raNaeoo~10803~ Plan "a" ~4-1/2" HES X NIP,ID = 3:813" ~ T.F2~ = 3_1!A" Flux. !w a^ n~ n WELLHEAD= FMC ACTUATOR= BAKER KB. ELEV = 65.6' BF. ELEV = 38.96' KOP = 2300' Max Angle = 95 (~ 10959' Datum MD = 10381 Datum TV D = 8800' SS 13-3l8" CSG, 72#, L-80, ID = 12.347" H 2720' Minimum ID = 2.750" @ 2033' ~TIS HXO SSSV NIPPLE 4-1/2" TBG, 12.6#, 13Cr-80 Vam Top, ~- .0152 bpf, ID = 3.958" 5-1/2" LNR, 17#, L-80, .0232 bpf, ID=4.892" (1 jt.) - TOP OF TfiN 7" LNR $277' PERFORATION SUMMARY REF LOG: ? ANGLEATTOPPERF:91 ~ 11185' Note: Refer to Productan DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 4 11185 - 11460 C 03/18/95 2-1/2" 4 11482 - 11562 C 03/18/95 2-1/2" 4 11738 - 11758 C 09/21!95 2-3/4" 4 11850 - 12200 C 09/21/95 4-1/2" LNR, 12.6#, 13Cr-80 VamTop, .0152 bpf, ID= 3.958" - TOP OF 4-1/2" Lner F -17A sart~r NoTes: I~zoNTAL we.L, 7a• ~ PROPOSED 10667" Ana 90• ~ , Os03' Plan "b" 4-1/2" HES X NIP, ID = 3.813" 9-5/8" X 4-1/2" BKR S-3 PKR ID = 3.875" 4-1 /2" HES X NIP, ID = 3.813" 9-518" X 7" BKR G2 ZXP LTP w / FLEXLOCK LNR HGR, ID = 6.290" 7" x 5-1/2" Crossover 5-1/2" x 4-1/2" Crossover MLLOUT W9NDOW (F-17A) 8478' - 8528' 10470' ELMD TT LOGGED 02/02/95 10465' 10465' 4-1/2" BKR ISOLATION PKR, ID = ? ~ 7" LNR, 29#, L-80, .0371 bpf, D = 6.184" ~ PBTD H 1 1@" LNR, 12.6#, L-80, .0152 bpf, D = 3.958" ~--~ 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 01M6/95 Mb0 31DETRACKCOMPLETION 02/02/95 DTR LAST WORKOVt3t 07/12/03 CMOlTLP KB ELEVATION, MAX ANGLE 10/20/06 GJF/PAG GLV GO (10/18/06) 04/01/07 JMF/PJC SET PX PLUG ~ 10395' (10!31/08) PRUDFIOE BAY UNIT WELL: F-17A PERMfC No: x1941630 API No: 50-029-20652-01 SEC 2, 711 N, R13E, 2215' FSL 8 2197' FEL BP Expiorati0n (Alaska) (4-1/2" HES X NIP, ID= 3.813" ~ GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DATE 2 3609 3500 4-1/2" 1" 1 6721 5800 4-1/2" 1" TREE= 3-1/8" FMC fW-4" OLI1 WELLHfAD= FMC ACTUATOR= BAKER KB. ELEV = 65.6' BF. ELEV = 38.96' KOP = 2300' Max Angle = 95 @ 10959' Datum ND = 10381 Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, D = 12.347" 7" LNR, 26#, L-80, .0382 bpf, ID = 6.276" -, TOP OF TNV 7" LNR - Minimum ID = 2.750" @ 2033' OTIS HXO SSSV NIPPLE PERFORATION SUMMARY REF LOG: ? ANGLEATTOPPERF:91 (c~ 11185' Note: Refer to Productan DB for histor~al pert data S¢E SPF INTERVAL Opn/Sqz DATE 2-3/4" 4 11185 - 11460 C 03/18/95 2-1/2" 4 11482 - 11562 C 03/18/95 2-1/2" 4 11738 - 11758 C 09/21/95 2-3/4" 4 11850 - 12200 C 09/21/95 4-1/2" TBG, 12.6#, 13Cr-80 Vam Top, .0152 bpf, ID = 3.958" , TOP OF 4-1/2" Lamer 17" LNR, 29#, L-80, .0371 bpf, D = 6.184" I 19-5/8" X 7" BKR C-2 ZXP LTP w 1 FLEXLOCK LNR HGR, ID = 6.290" MILLOUT WINDOW (F-17A) 8478' - 8528' 14-1 /2" HES X NIP, ID = 3.813" I 7" X 4-112" BKR S-3 PKR ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" I 12214' I ~4-1/2" LNR, 12.6#, L-80, .0152 bpf, D = 3.958" I ~~14-112" WLEG I 10470' -~~ TT LOGGED 02/02/95 10465' 4-1/2" BKR ISOLATION PKR D = ? DATE REV BY C,OMuBJTS DATE REV BY COMMENTS 01/15/93 AADO SIDE TRACKCOMPLtTION 02I0219S DTR LAST WORKOVt32 07/12/03 CMORLP KB ELEVATION, MAX ANGLE 10/20/06 G3F/PAG GLV GO (10/18/06) 04!01/07 JMF/PJC SET PX PLUG (6j 10395' (10/31/06) PRUDHOE BAY UNIT WFLL: F-17A PERNMF No: 1941630 APl W~: 50-029-20652-01 SEC 2, T11 N, R13E, 2215' FSL 8 2197' FEL ~ t;5cplaration (Alaska) F -17A saF~r Nom: HoR,zoNTal we.L, 7oa ~ PROPOSED 1068r am 90° (~ 10803' Plan "c" 14-1/2" HES X NIP, ID= 3.813" I GAS LIFT MANDRELS iT MD ND DEV TYPE VLV LAT 2 3609 3500 4-1/2" 1" 1 6721 5800 4-112" 1" Well Job# Log Description ae o or S-21 11695054 LDL 03/27/07 , Y-31 11628764 MEM GLS 04103/07 1 14-04 11660530 MEM PROD PROFILE 04/06/07 1 14-10 11626084 LDL 04/02/07 1 F-17A 11626083 LDL 03/31/07 1 F-30 11626078 LDL 03/26/07 1 X-21A 11660531 MEM PROD PROFILE 04/07/07 1 G-32A 11661134 MEM PROD PROFILE 03/30/07 1 X-36 11649959 MEM INJECTION PROFILE 04/12/07 1 06-24A 11637328 PRODUCTION PROFILE 04/16/07 1 X-36 11649959 MEM INJECTION PROFILE 04/12/07 1 12-02 N/A MEM INJECTION PROFILE 04/14/07 1 J-12 11686735 PROD PROFILE 04/13/07 1 B-26B 11628767 MEM PROD PROFILE 04/11/07 1 11-36 11626477 PROD PROFILE 04/17/07 1 03-18A 11626081 LDL 03/30/07 1 P2-59A 11630470 US IT 04/02/07 1 11-37 11626086 PRODUCTION PROFILE 04/22/07 1 X-10 11686739 LDL 04/23/07 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 04/30/07 NO. 4237 /0"( -1&3 sCANNE!JMAY 0'7 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay D t BL CI CD . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth t1AY 0 4 Z007 Received by: (( AI~ª Oil & Gas CoM. commission A~ F-17A (PTD #1941630) Classified as probleWII . All, Well F-17A (PTD #1941630) has sustained casing pressure on the IA and has been classified as a Problem well. A TIFL failed on 10/15/06. TIO's on 10/16/06 are 1270/1420/770. The plan forward for this well is as follows: 1. SL: Install DGLV's 2. DHD: Re-TIFL Attached is a wellbore schematic. Please call with any questions. «F-17A.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.com - ~ . >\¡~ \. 0ï.íN\.¡; . . .. Content-Description: F-17A.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 10/23/2006 9:26 AM . . TREE = 3-1/8" FMC (W-4" QU) W8.LHEAD = F~ F-17A SAFEiY NOTES: HORIZONTAL WELL., 700 @ A CTUtI TOR = BAKER 10667' AND 900 @ 10803' KB. ELEV = 65.6' BF. ELEV = 38.96' KOP- 2300' 1-13-1/2" OTIS HXO SSSV LA NO NIP, D = 2.75" I Max Ange - 95 @ 10959' I 2033' DatumMD= 10381 ~ DatumTVD = 8800' SS 113-3/8" CSG, 72#, L-80, ID= 12.347" 2720' µ ~ GAS LIFT MANDRELS J ST MD ND DEV TYPE VLV LATCH PORr DATE IMinimum ID = 2.750" @ 2033' 2 4706 4303 42 FMHO DOME RK 20/64 01/27/95 OTIS HXO SSSV NIPPLE 1 8196 6852 43 FMHO SlO RK 20/64 01/27/95 TOP OF 1lW 7" LNR 827T I I r.IILLOUT V\I1NDOW 8478' TO 8528' I ~ I 10409' 7" X 3-1/2" BAKER SABL-3 PKR I W/K-22 ANCHOR 10445' 3-1/2" HESX NIP, D-2.750" 1 3-1/Z' TOO, 9.2#, L-80 NSCT, .0087 bpf, ID - 2.992" I~ À 10457' 3-1/2" WLEG I 10457' ~ I 10470' I-1ELMDTTLOGGED02/02/95 I TOPOF4-1/2" 10465' I \ 10465' 4-1/Z' BAKER ISOLA TON PKR 17" LNR, 29#, L-80, 0.0371 bpf, ID - 6.184" H 10812' I j PERFORA TION SLMMA RY REF LOG: ? ~ I ANGLEATTOPPERF:91@ 11185' 12214' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE ~ 2-3/4" 4 11185 - 11460 0 03/18/95 2-1/Z' 4 11482-11562 0 03/18/95 ~ 2-1/Z' 4 11738- 11758 0 09/21/95 2-3/4" 4 11850 - 12200 0 09/21 /95 14-1/Z' LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 12300' I DUE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNrr 01/16/95 MDO SIDE TRACK COMPLETION WELL: F-17A 02102/95 DTR LAST WORKOVffi PERMrr No: 1941630 03/06/01 S I5-MH CO NV ERTB:> TO CA NV AS AA No: 50-029-20652-01 03/10/01 SI5-MD FINAL SEC2, T11N, R13E. 2215' FSL &2197' FEL 01/10/02 Rf'oVTP CORRECTIONS 07/12/03 CMO/TLP KB ELEVATION, MAXANGLE BP Exploration (Alaska) STATE OF ALASKA ..... ALASF¢, ,JIL AND GAS CONSERVATION CL,,v,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Acid 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2215' FSL, 2196' FEL, SEC. 02, T11 N, R13E, UM At top of productive interval 329' FSL, 1206' FEL, SEC. 03, T11N, R13E, UM At effective depth 517' FNL, 2479' FEL, SEC. 10, T11N, R13E. UM At total depth 562' FNL, 2553' FEL, SEC. 10, T11 N, R13E, UM t5. Type [~ well: Development [] Exploratory [] Stratigraphic [] Service (asp's 652649, 5973749) (asp's 647146, 5970906) (asp's 647073, 5970859) 6. Datum Elevation (DF or KB) KBE = 65.58' 7. Unit or Properly Name Prudhoe Bay Unit 8. Well Number F-17A 9. Permit Number / Approval No. ]94--I 63 10. APl Number 50- 029-20652-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 12300 feet true vertical 9055 feet Effective depth: measured 12214 feet true vertical 9053 feet Casing Length Structural Conductor 83' Surface 2693' Intermediate 8451' Production Liner 2535' Liner 1842' Plugs (measured) Junk (measured) Window milled in 9-5/8 csg (8478' - 8528'). Size Cemented MD TVD 20" x 30" 72 c.f. Concrete 110' 110' 13-3/8" 3280 c.f. PF II 2720' 2708' 9-5/8" 444 c.f. Class 'G' 8478' 7082' 7" 525 sx Class 'G' 8277' - 10812' 6931' - 9068' 4-1/2" Uncemented Slotted Liner 10458'- 12300' 8929' - 9054' Perforation depth: measured true vertical Open Perfs 11185'-11460', 11482'-11562', 11738'-11758', 11850'-12200' Open Perfs 9053'-9051', 9051'-9048', 9046'-9046', 9048'-9052' Tubing (size, grade, and measured depth) 3-1/2" 9.2#, L-80 tubing to 10409', with 3-1/2" tubing tail @ 10457'. Packers and SSSV (type and measured depth) 7" Baker SABL-3" Packer, Baker K-22 Anchor @ 10409'. 3-1/2" Otis HXO SSSVLN @ 2033'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17.1 hereby ce.~ t,~! the fo~n~is~ue and correct to the best of my knowledge Signed De,~Wa~¢~r~~~ Title Technical Assistant Prepared By Name/Number: Form10-404 Rev. 06,15,88 ~',.,~ ~--~ , ¢ i..,~t._.?,, .,; ,, ~' Date ~ ¢'/O,~"~/~ ¢o// DeWayne Schnorr 564-5174 Submit In Duplicat...~.~ F-17A Description of Work Completed NRWO OPERATIONS 04/12/2001 04/13/2001 04/15/2001 04/25/2001 ACID: TIFL ACID: PRE ACID TIFL ACID: TBG ACID PICKLE ACID: BULLHEAD ACID STIM SUMMARY 04/12/01 TIFL INCONCLUSIVE, WILL REPEAT 04/13/01 TIFL PASSED, PRE-ACID. 04/15/01 PUMPED PRE-ACID JOB TBG PICKLE PER PROCEDURE 1390-0 PSI. RETURNED WELL TO PRODUCTION. 04/25/01 RIG UP DOWELL PUMPERS; PT TO 3500, PUMP 120 OF 2% KCL AT 5 BPM TO KILL WELL, PUMP 26 BBLS OF GEL WITH WAX BEADS (PUMP 950# BEADS); SWITCH TO HCL, PUMP 24 BBLS OF HCL AT 5 BPM, PUMP 24 BBLS OF KCL, PUMP 10 BBLS OF GEL WITH WAX BEADS ( 350# BEADS), PUMP 42 BBLS OF HCL SEE DIVERTER HIT PERF.; REDUCE RATE FROM 5 BPM WHP=VAC. TO 3.8 BPM, WHP=870; 49 BBLS OF ACID AWAY; SWITCH TO KCL; 49 BBLS OF KCL AWAY 2ND STAGE OF BEADS HIT PERF. REDUCE RATE TO 2 BPM AT 1350 PSI; PUMP 150 BBLS OF KCL, FINAL PUMP RATE 2.5 BPM AT 1350 PSl;***GIVE WELL BACK TO PCC TO POP***; ACID TITRATION IS 12.2%; IRON STABILIZER IS LESS THAN 50 PPM Fluids Pumped BBLS. Description 74 DIESEL 24 12/10 DAD 3OO 2% KCL 36 BEADS/GEL (1300 # OF WAX BEADS) 72 ACID 5 MEOH 511 TOTAL MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO. THRU: Julia Heusser, COmmissioner Tom Maunder, P. I. Supervisor DATE: December 7, 2000 FROM: Jeff Jones, Petroleum Inspector SUBJECT: Safety Valve Tests Prudhoe Bay Unit BPX / F-Pad Thursday, December 7, 2000: I traveled to BPX's F-Pad in the Prudhoe Bay Field to witness Safety Valve System tests. Merv Liddelow, BPX rePresentative in charge of testing, performed the tests in a safe and proficient manner. Of the 28 wells tested, 10 failures were witnessed. For the most part, frozen contaminants (water) in the block valves upstream of the pilots and in the SSV hydraulic control lines caused the failures. On 12/8/00 Mr. Liddelow indicated to me that ail S¥S failures had been corrected and successfully re-tested. The 17.~%-SVS failure rate requires a 90-day~ test cycle for this pad. The AOGCC test report is attached for reference. I conducted 28 well house inspections concurrent with the SVS tests. Due to recent high winds, several well houses were drifted with snow inside. In addition, SVS hydraulic fluid leaks were noted on wells F-12 and F-13A. Mr. Liddelow indicated that these items would be addressed. No other exceptions were noted. SUMMARY: I witnessed SVS tests and conducted well house inspections on BPX's F-Pad in the Prudhoe Bay Field. 17.8% failure rate = 90 day test cycle. 28 wells, 56 components tested, l0 failures. 17.8% failure rate. 28 Well ho.use inspections condtJcted. Attachments SVS PBU F Pad 12-7,00 JJ CC' NON-CONFIDENTIAL SVS PBU F Pad 12-7-00 JJ.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep' Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBF/PBU/F Pad Separator psi: LPS 156 Date: 12/7/00 HPS 828 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE · F-01 1700460 828 550 525 P P OIL F-02 1700560 828 550 500 P P OIL F-03 1700580 F-04 1710020~ 156 125 125 P P OIL F-05 1710O90 F-06 1710120 · F'07 1750230 F-08 1740110 F-09 1790760 F-10A 2000670 F-11A 2000620 828! 550 500 P P OIL F-12 1791070 828 550 550 P P OIL F-13A 1961520 828 550 525 P P OIL , F-14 1800120 F-15 1811300 828 550 490 P P OIL , F-16A 1961600 156 125! 0 1 P OIL ~F-17A 1941630 156 125 130 P P OIL F-19 1811060 F-21 1890560 156 125 125 P P OIL F-22 1890620 156 125 125 P P OIL F-23A 1990740 156 125 125 p p oIL F-24 1831540 F-26A 1581890 156 125 155 P 4 OIL F-27 1861690 828 550 0 1 P OIL F-28 1861590 828 550 500 P P OIL ~-29 1861330 828 550 250 3 4 Om F-30 1891100 F-31 1861570 F-32 1890~30 828 550 520 P P t, OIL F-33 1960030 ' F-34A 1~61090 ~F-35 1880810~ 828, 5501 525, P P OIL F-36 1951960~ 828 550 0' 2 P OIL F-37 1890990i 828 550 550 P P ~IL 12/13/00 Page 1 of 2 SVS PBU F Pad 12-7-00 JJ.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed gAS or CYCLE ! F-38 1901350 F-39 1901410 156 125 125 P P OIL F~40 1911170 828 550 0 1 5 OIL F-41 1911040 828 550 530 P P OIL F-42 1901580 F-43 1910750 156 125! 125 e e OIL · F-44 1910080 F-45 1910280 828 550! 0 1 P OIL F-46 1901780 828 550! 50 3 P OIL ~-47A 2000350 156 125! 130 P P OIL F-48 1910860 '156 125 100 P P OIL , . . 28 Components: 56. Failures: 10 Failure Rate: 17.8% ~]go ray Remarks: 12/13/00 Page 2 of 2 SVS PBU F Pad 12-7-00 JJ.xls BBFORB W P Ii! R i~'l I i' Si & -', i 8 r~ 9 k.-- 1 6 3 9a.~'~ 163 Ar"e dr'.y 7 0 I .3 rece'i ved"? Date; 'i 'i/20/96 iR U i'q D A 'T ~ ...... R E C V D 02/'20/'96 i 06/23/'95 · " '"~ :~ /95 I 06/ ,..~ ,, 'i 02/" i 7/95 ye..~ - Vie il 'i' s w e I I r-;.., o r" (.:., cJ 9,, y e s ~ ,-,'" r',, a 'i y s '¥ s a,.. d e s c r ~' p +,_ '¥ o n r' e c e i' v e d ? 't:: e :(-.;'i s r"equ'i'r'.ed';L /yes (j~ Rece'ived'? ~ i"~u 'i' n c: o I'n p 'J 'i' a r"~ cs e ~ - I n 'i' 't '¥ a "1 I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION , ELL COMPLETION OR RECOMP LETION REPORT AND LOG .,_ 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 94-163 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o-029-20652-01 4. Location of well at surface 9. Unit or Lease Name 3065'SNL, 2197'WEL, SEC. 2, T,,N,R,3E'; ' - ~ i ~,¥ "i':.; ;: :ii;i; ~'¢.~x"'"'~" · "-':'~'~ ' ~:" '"';'"" '-" '.~..,,.¢.~. ,,,, -,. .~...,,, ,, .. PrudhoeBayUni, , -'.¢ ...... lO. Well Number At Top Producing Interval//~"//"""/~'~'~-~--, :~ ,:~ ........ '_~ "~'"*'~'~'~":' "' F-17A (31-10-11-13) 329' NSL, 1206' WEL, SEC. 3, T11N, R13E ~.. ;: ~-';¢"?':' ~'--~ ! 11. Field and Pool At Total Depth ' ~ :!: !'z":(..~.~.,~. ~ Prudhoe Bay Fiold/Prudhoe Bay Pool 563' SNL, 2595' WEL, SEC. 10, T11N, R13E ,~. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 65.58' ADL 28281 1'2. Date Spudded 13. DateT. D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 12/29/94 1/10/95 1/16/95I N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12300' MD/9033' TVD 12214' MD/9031' TVD YES [] NO []I 2033' feet MDI 1900' (Approx.) 22. Type Electric or Other Logs Run GR 23. CASING, LINER AND CEMENTING RECORD SE'n-lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" x 30" Insulated conductor Surface 110' 36" 8 cu yds concrete 13-3/8" 72# L-80 Surface 2720' 17-1/2" 3280 cu fl PF II 9-5/8" 47# L-80 Surface 8478' 12-1/4" 444 cu fi Class "G" 7" 29# L-80 8277' 10812' 8-1/2" 525 sx Class "G 4-1/2" 12. 6# L-80 10458' 12300' 6" Uncemented slotted liner 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter 2-3/4" 4 spf 3-1/2", L-80 10457' 10409' MD TVD 11185'-11460' 9032'-9029' 11850'- 12220' 9027'-9031' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 2/11/95 Gas Lift Date of Test Hours Tested PRODUCTION FOR DIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED..~ DIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core,._chips. RECEIVED friAR - 6 1995 Alaska Oil & ~a$ Cons. Cor~iSslor~ Anchor~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .I 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sag River 100000' 8420' Shublik 10040' 8459' Sadlerochit 10122' 8538' 31. LIST OF A'FrACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Si g ned __ T itl e Drilling Engineer Suoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". RE6~IV[D Form 10-407 MAR -'6 1995 Alaska Oil & Gas Cons. Commission Anchors: ,, ~rLARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: F-17A NORTH SLOPE PRUDHOE BAY PRUDHOE BAY 50- ACCEPT: 12/23/94 10:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 12/23/94 ( 1) TD:l1480 PB: 0 RIG MOVE F/ F-06 - F-17A MW: 0.0 WAIT ON PREPARATION WORK ON F-17. STAND BY W/ CREWS. RIG DOWN, MOVING RIG AND CAMP TO F-17A. 12/24/94 (2) TD:l1480 PB: 0 12/25/94 ( 3) TD:l1480 PB: 0 12/26/94 ( 4) TD:l1480 PB: 0 CIRC WELL, TEST HYDRIL & RAMS MW: 0.0 SPOT RIG OVER WELL. LEVEL UP RIG. RIG UP TO CIRC WELL. TAKE ON SEAWATER. ACCEPT RIG @ 1000 HRS 12/23/94. RIG UP LUBRICATOR AND PULL BPV. CIRC. CIRC OUT DIESEL. PUMP ONE COMPLETE CIRC. TOOK APPROX. 35 BBLS TO FILL. INSTALL TWC. TEST BACK SIDE. NIPPLE DOWN TREE, NIPPLE UP BOPE. TEST BLIND RAMS, CHOKE MANIFOLD. RIG UP LUBRICATOR. PULL TWO WAY CHECK. TOOK 57 BBLS TO FILL. P/U JT TO TEST PIPE RAMS AND HYDRIL M/U INTO HANGER. FLOWING BACK THRU JT. R/U TO CIRC HOLE. CIRC. TEST HYDRIL AND UPPER RAMS WHILE CIRC. TRIP IN W/ CMT RETAINER MW: 0.0 M/U UP TEST JT INTO HGR. ATTEMPT TO TEST TOP RAMS. LEAKING BY THREADS. PULL HGR TO FLOOR. CIRC BOTTOMS UP. L/D LANDING JT AND HANGER. TRIP OUT L/D 5.5" TBG ABD ROLL UP CONTROL LINE. L/D SSSV. CLEAR FLOOR. M/U TEST PLUG ON 5.5" TBG W/ TEST JT ON TOP OF TEST PLUG. ATTEMPT TO RUN THROUGH. STACK STOPPED @ 15' PULL OUT AND LAY DOWN TEST PLUG. R/U AND PULL L/D 5.5 COMPLETION STRING. P/U BAKER STORM PACKER AND HANG OFF TBG STRING. P/U TEST PLUG AND TEST JT. TEST HYDRIL, PIPE RAMS AND KOOMEY TEST. L/D TEST EQUIP. PULL AND L/D STORM PACKER. R/U AND LAYING DOWN 5.5 COMPLETION STRING. CLEAR FLOOR. SET BORE PROTECTOR; MU 9 5/8" BAKER CMT RETAINER. TRIP IN HOLE W/ 9 5/8" BAKER CMT RETAINER. PICK UP 4.5" DP. SLIP AND CUT DRLG LINE. TRIP IN HOLE, W/ 9 5/8" BAKER CMT RETAINER. PICK UP 4.5" DP. TRIP IN HOLE MW: 0.0 TRIP IN HOLE W/ 9 5/8" BAKER CMT RETAINER. PICK UP 4.5" DP. SET RETAINER @ 8700' TEST 9 5/8". CIRC DP ABOVE RETAINER @ 8700' AND WAIT ON ORDERS. TRIP OUT. L/D BAKER RETAINER RUNNING TOOL. P/U 8.5" BIT, 3- BOOTBASKETS, 12 DC'S JARS, 15 HW. TRIP IN HOLE. KELLY UP. BREAK CIRC. TAG RETAINER @ 8700', MILL RET TO 8702'. TRIP INTO 9644' TOP OFF CUT OFF. TRIP OUT. L/D BOOT BASKETS. P/U REVERSE CIRC BASKET. TRIP IN HOLE. : F-17A _~TION: : NABORS 2ES PAGE: 2 12/27/94 (5) TD:l1480 PB: 0 12/28/94 ( 6) TD:l1480 PB: 8600 12/29/94 (7) TD:l1480 PB: 8528 12/30/94 (8) TD: 8939 PB: 7478 12/31/94 (9) TD: 9850' (9850) NIPPLE UP BOPE MW: 0.0 TRIP IN HOLE W/ REVERSE CIRC BASKET. R/U AND REVERSE CIRC DOWN TO 9644' REVERSE CIRC 156 STROKES. WORK REVERSE BASKET. RECOVERED SMALL PIECES RUBBER OVER SHAKER. TRIP OUT, BREAK DOWN REVERSE BASKET. RECOVERED 20 PIECES JUNK METAL. L/D REVERSE BASKET, CLEAR FLOOR. M/U MULE SHOE. TRIP IN HOLE W/ MULE SHOE OPEN ENDED. SLIP AND CUT DRILLING LINE. TRIP IN TO 9644' TAG STUB. RIG UP AND BREAK CIRC. PUMP CMT PLUG W/ BJ TEST LINES. POH SLOWLY TO 8100' REVERSE CIRC ONE CIRC. TEST CSG AND CMT TO 1000 PSI. P/U BAKER STORM PACKER AND HANG OFF DP @ 27'. TEST. PULL WEAR BUSHING. PULL 9 5/8" PACKOFF. NIPPLE DOWN BOP STACK, REMOVE TBG SPOOL AND REPLACE. INSTALL 9 5/8" PACKOFF AND TEST. NIPPLE UP BOPE. MILLING 9 5/8" CSG @ 8518' MW: 0.0 NIPPLE UP BOPE. TEST CSG, SET TESST PLUG TEST UPPER TBG FLG AND BLIND. SET BOWL PROTECTOR. P/U LATCH ASSY ENGAGE STORM PACKER PULL TO FLOOR AND LAY DOWN. TRIP IN HOLE TAG CMT @ 8680'. P/U KELLY AND BREAK CIRC. CIRC 7 DISPLACE SEAWATER TO MUD. SPOT 18 PPG MUD ON BTTM. L/D 37 JTS DP. POH FOR SECTION MILL. P/U SERVCO SECTION MILL ASSY, TRIP IN HOLE. KELLY UP BREAK CIRC, START MILLING SECTION @ 8478 - 8518'. MU BHA #4 MW: 0.0 FINISHED MILLING 9 5/8" SECTION TO 8528'. 90% RECOVERY OF METAL. CIRCULATED HOLE CLEAN. PUMPED DRY JOB. POH, LD SECTION MILL AND DC. MU MULESHOE. MILL 50% WORN. RIH W/ MULESHOE, WASHED THRU SECTION TO TOP OFF PLUG @ 8680'. CIRCULATED AND CONDITIONED MUD, BATCH MIXED CEMENT. PUMPED 5 BBLS WATER, TESTED LINES, PUMPED 15 BBLS WATER, 34 BBLS CEMENT, 5 BBLS WATER. DISPLACED W/ RIG PUMPS. BROKE OFF HEAD PIN + 1 JT DP, PLUG UNBALANCED. POH 10 STANDS AND PERFORMED HESITATION SQUEEZE. NO CEMENT SQUEEZED AWAY. PUMPED DRY JOB. POH AND LD MULESHOE. FLUSHED OUT BOP STACK. PWR AND PERFORMED STATE BOPE TEST. INSTALLED WEAR RING. PREPARING TO MU BHA #4. DRILLING MW: 0.0 MU BHA #4 AND RIH. FLOW CHECKED MWD. SLIPPED DRILLING LINE. RIH, TAGGED TOC @ 8302'. DRILLED HARD CEMENT. CBU. ORIENTED LOWSIDE AND BEGAN KICKOFF. PAST STUMP @8528'. DRILLED F/ 8528 - 8939' FINISHED DROP SECTION, DRILLING TANGENT SECTION. BIT IN KINGAK SHALE. DRILLING MW: 0.0 VIS: 0 DRILLED F/ 8939 - 9850'. MANIFOLD ON PUMP #1 WASHED OUT, BEING REPLACED. DRILLING W/ ONE PUMP. WILL MAKE BIT TRIP AT TOP OF SAG RIVER. RECEIVED ,..;.. : F-lTL _,~TION: : NABORS 2ES PAGE: 3 01/01/95 (10) TD: 9968' ( 118) 01/02/95 (11) TD:10343' ( 375) 01/03/95 (12) TD:10365' ( 22) 01/04/95 (13) TD:10501' ( 136) DRILLING MW: 0.0 VIS: 0 DRILLED F/ 9850 - 9944'. CONTINUED REPAIR OF WASHED OUT PUMP MANIFOLD, REQUIRED EXTENSION WORK TO REMOVE AND REPLACE. ESTIMATE BIT 15' ABOVE TOP SAG RIVER. PUMPED LO-VIS SWEEP AND CIRCULATED HOLE CLEAN. DROPPED SPERRY ESS. POH TO SHOE. MAXIMUM 35K DRAG, HOLE FILL UP NORMAL. MONITORED WELL AND BLEW DOWN KELLY AND MANIFOLD. POH TO BHA. CHANGED OUT BITS, PU GAMMA SONDE. RIH AND FLOW CHECKED. RIH TO 8400' SLIPPED AND CUT DRILLING LINE. FINISHED REPAIR OF #1 MUD PUMP. RIH TO 9865', PU KELLY, BENCHMARK SURVEYED AT 9868', REAMED F/ 9865 - 9944' DRILLED F/ 9944 - 9968' CBU MW: 0.0 VIS: 0 DRILLED F/ 9968 - 10047' SWIVEL PACKING LEAKED. LD 5 SINGLES AND CHANGED OUT SWIVEL PACKING. ROLL CHECKED MWD AT BENCHMARK. TOOL WITHIN JORPS. DRILLED F/ 10047 - 10287'. SWIVEL PACKING LEAKED. CHANGED OUT SWIVEL PACKING. DRILLED F/ 10287 - 10343' BIT IN LOWER ZONE 3, VARIABLE TORQUE. ROP ABNORMALLY LOW. BIT CUTTING STRUCTURE PROBABLE GONE, POTENTIALLY UNDERGAUGED. PUMPED HI-VIS SWEEP AND BEGIN CIRCULATING HOLE CLEAN. WILL TRIP F/ NEW BIT. MU BHA #7 MW: 0.0 VIS: 0 CIRCULATED HOLE CLEAN. MONITORED WELL, WELL STABLE. POH. 50K INTERMITTENT DEAG IN OPEN HOLE THRU KINGAK, HOLE FILL UP NORMAL. MONITORED WELL, PUMPED DRY JOB, AND BLEW DOWN KELLY AT SHOE. LD BHA #5, BUILT BHA #6. BIT #3 OUT OF GAUGE W/ OUTER ROW TEETH BROKEN, SOME JUNK DAMAGE. RING GROOVE CUT ON OUTER 1/4" ON CONES INDICATES UNDERGAUGED HOLE. BHA #6 BUILT TO GAUGE OUT HOLE. RIH. PU KELLY AT 10240' AND REAMED F/ 10240 - 10343' W/ 80 RPM, 5-7K WOB. DRILLED F/ 10343 - 10365'. CBU. MONITORED WELL, WELL STABLE. POH. 15K MAX DRAG IN OPEN HOLE, FILL UP NORMAL. MONITORED WELL, PUMPED DRY JOB, AND BLEW DOWN KELLY AT SHOE. LD BHA #6. LOW ROP F/ BIT #4 DUE TO SEVERLY ROUNDED GAUGE ON OUTER CUTTERS. DRILLING MW: 0.0 VIS: 0 LD BHA #7. MU BHA #8. FLOW CHECKED MWD AND MOTOR AT SURFACE. RIH W/ BHA #8 TO SHOE. SLIPPED DRILLING LINE. RIH, BENCHMARK SURVEYED AT 9868'~, OK.65RE-LOGGED F/ 10333 - 10365'. ORIENTED AND DRILLED =, 103 - 10501'. CIRCULATED HOLE. CLEAN. POH TO SHOE. TIGHT AT SHOE. MONITORED WELL AND PUMPED DRY JOB. BLEW DOWN KELLY. POH. HOLE FILL UP NORMAL. CHANGED OUT BITS. GAUGE ON OUTER ROUNDED; CAUSES REDUCED BUILD RATE. RIH W/ BHA #9. BENCHMARK SURVEY AT 9868' RIH, WASHED TO BOTTOM AND BEGAN ORIENTING. : F-17A _~TION: : NABORS 2ES PAGE: 4 01/05/95 (14) TD:10727' ( 226) 01/06/95 (15) TD:10812' ( 85) 01/07/95 (16) TD:10812' ( 0) 01/08/95 (17) TD:10812' ( 0) DRILLING MW: 0.0 VIS: 0 DRILLED F/ 10501 - 10627'. CIRCULATED HOLE CLEAN WHILE EVALUATING DIRECTIONAL RSULTS. DRILLED F/ 10627 - 10641'. CBU. POH. MONITORED WELL AND PUMPED PILL AT SHOE. MU BHA #10. FLOW CHECKED MWD AND MOTOR. RIH. WASHED F/ 10590 - 10641' DRILLED F/ 10641 - 10727'. PROJECTED TD 10760' MD 9041' TVD, 90 DEGREE. POH F/ 7" LINER MW: 0.0 VIS: 0 DRILLED F/ 10727 - 10812' CIRCULATED HOLE CLEAN. POH. HOLE FILL UP NORMAL, 20K MAXIMUM EXCESS DRAG IN OH. SLIPPED AND CUT DRLG LINE. POH. PUMPED PILL AND BLEW DOWN KELLY AT SHOE. LD BHA #10, MU BHA #11. RIH. INTERMITTENT EXCESS DRAG 25 - 35K BEGINNING AT 10450' PU KELLY AND REAMED F/ 10448 - 10812'. CIRCULATED HOLE CLEAN. SHORT TRIPPED 10 STANDS, 25K EXCESS DRAG UP, NO EXCESS DRAG RIH. PUMPED LO-VIS/HI-VIS SWEEP AND CIRCULATED HOLE CLEAN. POH F/ 7" LINER. CEMENTING MW: 0.0 VIS: 0 POH F/ 7" LINER. HOLE FILL UP NORMAL. LD BHA #11. CLEARED FLOOR. RU NCS. RAN 62 JTS 7" 29# L-80 NSCC LINER + TIW HYDRAULIC SET HANGER AND LINER PACKER. CIRCULATED LINER VOLUME AND RIH ON 4 1/2" DP. BROKE CIRCULATION AT SHOE, RIH. WORKED THRU 75K EXCESS DRAG F/ 10500 - 10700'. MU CIRCULATING HEAD, BROKE CIRCULATION AND TAGGED BOTTOM AT 10812' BEGAN RECIPROCATING PIPE AND STAGING PUMPS. COULD NOT RECIPROCATE ABOVE 5 BPM. RU BJ, BATCH MIXED CEMENT. CIRCULATED AND CONDITIONED MUD. PUMPED 5 BBLS PREFLUSH AND TESTED LINES. TIW CEMENTING HEAD LEAKED AT GREASE FITTINF. LD CEMENTING HEAD AND MU HEAD PIN. RESTABLISHED CIRCULATION W/ RIG PUMPS. SWITHCED TO BJ, PUMPED 20 BBLS PREFLUSH, TESTED LINES. MU BHA #12 MW: 0.0 VIS: 0 CONTINUED 7" LINER CEMENT JOB. BROKE OFF HEAD PIN AND DROPPED DP DART BY HAND, DISPLACED W/ RIG, BUMPED PLUG ON CALCULATED STROKES. ATTEMPTED TO INCREASE PRESSURE TO SET PACKER, PRESSURE BLED OFF AT 3900 PSI. BLED PRESSURE OFF DP. RELEASED RUNNING TOOL AND POH 15 STANDS. PIPE INTIALLY DRY. POH. PWR PERFORMED. MU TIW SEAL ASSEMBLY AND RIH. ENGAGED SEALS AND STAGED UP PRESSURE W/ NO LOSS. BLED OFF PRESSURE, DISENGAGED SEALS AND TESTED ANNULUS. PUMPED DRY JOB AND POH. SLIPPED DRILLING LINE. POH. LD 60 JTS CORKSCREWED AND BENT 4 1/2" E DP. MU BHA #12. : F-17A .~TION: : NABORS 2ES PAGE: 5 01/09/95 (18) TD:ll164' ( 352) 01/10/95 (19) TD:11666' ( 502) 01/11/95 (20) TD:12300' ( 634) 01/12/95 (21) TD:12300' ( 0) DRILLING MW: 0.0 VIS: 0 MU BHA #12, RIH AND FLOW CHECKED MWD. RIH. PU 3 1/2" DP, 60 JTS 4 1/2" DP. TAGGED LC AT 10727' DRILLED LC, FC AT 10767, SHOE AT 10812', + 10' NEW HOLE ~0 10821' DISPLACED TO FLOPRO. CLEANED SHAKERS. DRILLED F/ 10821 - 10861' CBU F/ SAMPLES. DRILLED F/ 10861 - 11164' RIH W/ BHA #13 MW: 0.0 VIS: 0 DRILLED F/ 11164 - 11666'. CIRCULATED HOLE CLEAN. POH. NO EXCESS DRAG, HOLE FILL UP NORMAL. LD 34 JTS 4 1/2" DP. DOWN LOADED LWD, CHANGED OUT BITS, UPLOADED LWD, AND RIH. FLOW CHECKED MWD. RIH. PU 33 JTS 3 1/2" DP. POH F/ 4 1/2" LINER MW: 0.0 VIS: 0 SLIPPED AND CUT DRILLING LINE. CONTINUED RIH TO 7" SHOE AT 10812' RE-LOGGED OH SECTION BY SLOWING TRIP SPEED TO 800 FPH. PU KELLY AND REAMED 60' TO BOTTOM (PRECAUTIONARY). HOLE CONDITIONS EXCELLENT. DRILLED F/ 11666 - 12300' TD 6" HOLE, HORIZONTAL SECTION 1488' CIRCULATED HOLE CLEAN. SHORT TRIPPED TO 7" SHOE, HOLE FILL UP NORMAL, NO EXCESS DRAG, HOLE IN EXCELLENT SHAPE. CIRCULATED HOLE CLEAN, SPOTTED 56 BBL VISCOSIFIED PILL TREATED W/ 2% LUBETEX IN OH. POH F/ 4 1/2" LINER. NO EXCESS DRAG, HOLE FILL UP NORMAL. RELEASING FROM 4 1/2" LINER MW: 0.0 VIS: 0 POH. O/H SECTION CLEAN, MONITOR WELL TO SHOE, POH WET. LD 24 JTS 3 1/2" DP. LD BHA AND RETRIEVE RABBIT. REPAIR KICKER ON SKATE IN PIPE SHED. LD BHA, CLEAR FLOOR AND R/U NCS. PU 4 1/2" LINER. BAKER LOK BOTTOM 3 JOINTS. FILL EVERY 5 JTS. CHECK AND TIGHTED SOME LOOSE BRAKE BLOCKS. WILL PROBABLY HAVE TO CHANGE BRAKES TODAY. FINISH PICKING UP 4 1/2" LINER, HYD-SET HANGER, LINER TOP PACKER AND C-2 SETTING SLEEVE. CIRC LINER VOLUME AND CLEAR RIG FLOOR. RIH SLOWLY W/ LINER, BREAKING CIRC EVERY 9 STDS, TAGGED UP ON BOTTOM W/ NO PROBLEMS. CIRC WHILE REICPROCATING LINER. BATCH MIX CEMENT. TEST LINES. BUMPED PLUG. RECEIVED : F-17A .~TION: ~IG : NABORS 2ES PAGE: 6 01/13/95 (22) TD:12300' ( 0) 01/14/95 (23) TD:12300 PB:12214 01/15/95 (24) TD:12300 PB:12214 CIRC HOLE CLEAN MW: 0.0 VIS: 0 RELEASE RUNNING TOOL FROM LINER HANGER AND PACKER. REVERSE CIR, R/D CMT HEAD, OBSERVE WELL AND POH. L/D BAKER RUNNING TOOL. REPLACE BRAKE BLOCKS ON DRAWWORKS. PU 3 3/4" ECONO-MILL AND 2 7/8" PAC DRILL PIPE. RIH W/. 3 1/2" AND 4 1/2" DRILL PIPE. SLIP DRILLING LINE AND ADJUST BRAKES. RIH TO TOP OF 4 1/2" LINER. BEGAN SEEING CMT STRINGERS @ 10537'; COULD NOT WASH PAST. STRINGERS DRILLED OUT EASILY W/ A MINIMUM OF WEIGHT AND TURNS. P/U KELLY. BEGAN CIRC. DRILLED STRINGERS 10537 - 10595' AND WASHED TO 10625'. RIH TO 10700'. TAGGED UP ANOTHER STRINGER AND WASHED TP 10750'. RIH AND TAGGED LANDING COLLAR @ 12214'; NO CEMENT @ LC. CIRC OUT; R/U TO REVERSE CIR 2 DP VOLUMES BEFORE DOING CASING TEST AND POH TO PU PERF GUNS. CIRC WELL MW: 0.0 CIRCA DP VOLUME WHILE RECIP AND ROTATING. REVERSE CIR. TEST CASING AND LINER LAPS. REVERSE CIRC AGAIN TO MAKE SURE NO CMT LEFT IN HOLE. GOT A LITTLE BIT BACK, THEN CLEANED UP. POH; LD CASING SCRAPER, 2 7/8" DRILL PIPE AND BHA AND 3 3/4" ECONOMILL. RU TO PICK UP PERF GUNS. PU PERF GUNS. RIH W/ PERF GUNS, PICKING UP 2 3/8" RTS-6 TUBING. RIH W/ 3 1/2" & 4 1/2" DP. TAGGED LS @ 12214' AND POSITIONED GUNS WITH BOTTOM OF GUNS @ 12200' SET CHAMP PACKER, SHOOT FLUID LEVELS AND HOOK UP EQUIPMENT. PRESSURE UP ANNULUS. GOT POSITIVE INDICATIONS OF GUNS GOING OFF. UNSEATED PACKER AND FILLED HOLE WITH 45 BBLS. HOLE LEVEL FALLING CONTINUOUSLY, INSIDE OF DRILL STRING FAIRLY STABLE. GUNS FREE. POH 10 STANDS. CIRC LONG WAY BECAUSE OF LOSS TRENDS TO MINIMIZE LOSSES. WELL STABLE, APPEARS TO HAVE HAD NO INFLUX INTO WELLBORE. CIRC. RUNNING 3 1/2" COMPLETION MW: 0.0 FINISH CIRC HOLE VOLUME. NO OIL @ SURFACE. POH LD DP. SLIP AND CUT DRILLING LINE. POH LD DP. LD PACKER AND PERF GUNS. ALL SHOTS FIRED. R/U NCS, PULL WER BUSHING. RUN 3 1/2" L-80 TUBING. POCKED UP SSSV, FAIRLY CLOSE TO LANDING STRING. : F-17A ~ATION: RIG : NABORS 2ES PAGE: 7 01/16/95 (25) TD:12300 PB:12214 01/17/95 (26) TD:12300 PB:12214 N/D BOPS MW: 0.0 RUN 3 1/2" L-80 COMPLETION. PU CAMCO SSSV AND TEST. MU TBG HANGER AND CONTROL LINES, TEST. REVERSE CIRC IN INHIBITED SEAWATER DOWN TO TAILPIPE ASSY. ERROR ON COMPUTER TALLY CAUSED BAD SPACE OUT. ADJUSTED TALLY AND RE-SPACED COMPLETION. RE-TESTED HANGER AND CONTROL LINE HOOK UP. LAND TUBING, RILDS. RU TDS PUPS AND CAMCO SLICKLINE UNIT AND BOPS. PULL INSERT AND INSTALL SSSV. CONTROL LINES WOULD NO HOLD PRESSURE. RETRIEVE SSSV; VALVE PARTED IN HOLE. FISHED FOR VALVE-GOT IT ON FIFTH TRIP. RE-RAN SSSV. SET PACKER AND TEST TUBING. BLED DOWN TUBING AND PRESSURED UP ANNULUS. FREEZE PROTECT ANNULUS AND TBG TO 2000'; LET U-TUBE INTO PLACE WHILE R/D SLICKLINE UNIT. BACK OUT LANDING JOINT AND SET TWC. TESTED TWC AND CLOSED BALL VALVE. ND BOPS. RELEASE RIG MW: 0.0 FINISHED N/D BOPS. N/U ADAPTER FLANGE AND TREE. INSTALLED AND TESTED CONTROL LINES. CHANGED OUT TOP UNION ON TREE FROM MPU STYLE TO PBU UTILIZED OTIS UNION. TESTED TREE. HOOKED UP VALVES AND GAUGES. RELEASE RIG @ 1200 HRS 01/16/95. SIGNATURE: (drilling superintendent) DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 SHARED SERVICES DRILLING PBU/F-17A 500292065201 NORTH SLOPE COMPUTATION DATE: 2/28/95 DATE OF SURVEY: 011095 MWD SURVEY JOB NUMBER: AK-MW-40097 KELLY BUSHING ELEV. = 65.58 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8394 6999.41 6933.83 8482 7065.63 7000.05 8651 7207.67 7142.09 8682 7236.17 7170.59 8713 7265.23 7199.65 41 7 40 38 24 30 21 47 19 0 S 68.39 W .00 1550.20S 3465.80W 3728.18 S 68.83 W .64 1571.11S 3519.17W 3783.88 S 78.50 W 10.01 1598.16S 3605.46W 3870.09 S 78.70 W 8.71 1600.57S 3617.40W 3881.25 S 79.00 W 9.04 1602.66S 3628.00W 3891.14 8744 7294.61 7229.03 8806 7353.60 7288.02 8901 7443.68 7378.10 8965 7504.06 7438.48 9058 7591.70 7526.12 18 6 17 47 19 12 19 30 19 36 S 79.30 W 2.92 1604.52S 3637.69W 3900.14 S 80.80 W .89 1607.83S 3656.51W 3917.44 S 77.80 W 1.78 1613.45S 3686.11W 3944.92 S 77.70 W .47 1617.95S 3706.83W 3964.47 S 72.90 W 1.73 1625.84S 3736.91W 3993.64 9151 7679.37 7613.79 9245 7768.03 7702.45 9339 7856.94 7791.35 9433 7946.13 7880.55 9527 8035.40 7969.82 19 23 19 23 18 30 18 17 18 12 S 72.20 W .33 1635.15S 3766.52W 4023.24 S 74.20 W .71 1644.17S 3796.41W 4052.89 S 70.60 W 1.57 1653.38S 3825.49W 4082.00 S 71.70 W .43 1662.96S 3853.57W 4110.50 S 72.20 W .20 1672.08S 3881.56W 4138.66 9622 8125.88 8060.30 9717 8216.53 8150.95 9812 8307.18 8241.60 9874 8366.55 8300.97 9978 8466.34 8400.76 17 17 17 30 17 17 16 12 16 30 S 70.30 W 1.13 1681.38S 3908.98W 4166.45 S 72.00 W .58 1690.56S 3935.87W 4193.74 S 71.90 W .21 1699.36S 3962.88W 4220.91 S 67.80 W 2.60 1705.49S 3979.65W 4238.17 S 71.00 W .91 1715.78S 4007.04W 4266.51 10041 8526.70 8461.12 10073 8557.32 8491.74 10104 8586.98 8521.40 10135 8616.62 8551.04 10165 8645.17 8579.59 16 47 17 0 16 47 17 17 18 23 S 70.60 W .51 1721.72S 4024.09W 4283.88 S 70.30 W .68 1724.83S 4032.86W 4292.85 S 68.70 W 1.63 1727.99S 4041.30W 4301.57 S 69.20 W 1.68 1731.25S 4049.78W 4310.39 S 63.20 W 7.14 1734.97S 4058.18W 4319.40 10196 8674.40 8608.82 10227 8703.26 8637.68 10259 8732.86 8667.28 10283 8754.99 8689.41 10320 8788.79 8723.21 20 30 22 17 22 17 23 12 24 47 S 59.90 W 7.64 1739.90S 4067.24W 4329.65 S 57.70 W 6.36 1745.76S 4076.91W 4340.94 S 56.60 W 1.31 1752.35S 4087.11W 4353.07 S 55.30 W 4.30 1757.55S 4094.80W 4362.35 S 55.70 W 4.35 1766.07S 4107.20W 4377.40 10352 8817.73 8752.15 10383 8845.21 8779.63 10415 8872.43 8806.85 10446 8897.43 8831.85 10478 8921.74 8856.16 25 42 29 23 34 0 38 30 42 35 S 55.20 W 2.89 S 55.20 W 11.94 S 56.10 W 14.45 S 55.80 W 14.53 S 56.40 W 12.87 1773.81S 4118.44W 4391.04 1781.99S 4130.21W 4405.38 1791.47S 4144.10W 4422.19 1801.73S 4159.28W 4440.51 1813.33S 4176.54W 4461.31 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING PBU/F-17A 500292065201 NORTH SLOPE COMPUTATION DATE: 2/28/9 DATE OF SURVEY: 011095 MWD SURVEY JOB NUMBER: AK-MW-40097 KELLY BUSHING ELEV. = 65.58 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORD DEGREES DG/100 NORTH/SOUTH EAST I NATES /WEST VERT. SECT. 10509 8943.92 8878.34 10540 8964.45 8898.87 10566 8980.06 8914.48 10604 9000.25 8934.67 10636 9014.77 8949.19 46 0 51 0 55 12 60 35 65 24 S 55.80 W 11.05 S 54.60 W 16.39 S 56.50 W 17.18 S 58.80 W 15.11 S 58.50 W 15.02 1825.41S 4194.51W 1838.66S 4213.56W 1850.41S 4230.71W 1867.61S 4257.90W 1882.44S 4282.24W 4482.95 4506.16 4526.95 4559.09 4587.53 10667 9026.38 8960.80 10698 9035.44 8969.86 10730 9042.07 8976.49 10772 9046.67 8981.09 10803 9047.32 8981.74 70 35 75 24 80 41 86 41 90 54 S 58.90 W 16.82 S 56.50 W 17.16 S 56.70 W 16.57 S 56.60 W 14.29 S 56.60 W 13.55 1897.37S 4306.79W 1913.21S 4331.84W 1930.44S 4357.97W 1953.38S 4392.82W 1970.43S 4418.69W 4616.21 4645.81 4677.09 4718.80 4749.77 10836 9046.78 8981.20 10866 9046.02 8980.44 10896 9044.50 8978.92 10928 9042.07 8976.49 10959 9039.45 8973.87 91 0 S 56.50 W .42 91 54 S 56.50 W 3.00 93 54 S 57.60 W 7.61 94 48 S 58.20 W 3.38 94 54 S 58.40 W .72 1988.62S 4446.22W 2005.17S 4471.23W 2021.47S 4496.37W 2038.42S 4523.39W 2054.65S 4549.67W 4782.76 4812.74 4842.67 4874.54 4905.38 10991 9037.00 8971.42 11022 9035.24 8969.66 11053 9034.21 8968.63 11084 9033.59 8968.01 11116 9033.03 8967.45 93 54 S 58.30 W 3.14 92 35 S 57.80 W 4.49 91 11 S 57.60 W 4.56 91 5 S 57.30 W 1.02 90 54 S 57.20 W .70 2071.39S 4576.83W 2087.77S 4603.09W 2104.33S 4629.28W 2121.00S 4655.40W 2138.31S 4682.31W 4937.23 4968.13 4999.08 5030.04 5062.01 11147 9032.41 8966.83 11179 9031.71 8966.13 11210 9031.17 8965.59 11242 9030.72 8965.14 11273 9030.37 8964.79 91 24 S 57.00 W 1.74 91 5 S 57.40 W 1.56 90 54 S 55.90 W 4.88 90 41 S 56.20 W 1.13 90 35 S 56.70 W 1.64 2155.14S 4708.34W 2172.48S 4735.23W 2189.51S 4761.12W 2207.38S 4787.66W 2224.51S 4813.49W 5092.98 5124.95 5155.93 5187.92 5218.91 11304 9030.07 8964.49 11336 9030.02 8964.44 11368 9030.41 8964.83 11399 9030.87 8965.29 11431 9030.76 8965.18 90 30 S 56.40 W 1.02 89 41 S 56.10 W 2.67 88 54 S 56.00 W 2.52 89 24 S 56.70 W 2.78 91 0 S 57.10 W 5.15 2241.60S 4839.36W 2259.38S 4865.96W 2277.25S 4892.51W 2294.42S 4918.31W 2311.90S 4945.11W 5249.90 5281.89 5313.88 5344.87 5376.85 11462 9029.95 8964.37 11493 9028.92 8963.34 11525 9027.88 8962.30 11556 9026.99 8961.41 11588 9026.18 8960.60 92 0 S 56.30 W 4.13 91 48 S 56.60 W 1.16 91 54 S 57.00 W 1.29 91 24 S 57.00 W 1.61 91 30 S 57.00 W .32 2328.91S 4971.01W 2346.03S 4996.83W 2363.54S 5023.59W 2380.42S 5049.58W 2397.84S 5076.41W 5407.82 5438.79 5470.76 5501.73 5533.70 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU/F- 17A 500292065201 NORTH SLOPE COMPUTATION DATE: 2/28/9 DATE OF SURVEY: 011095 MWD SURVEY JOB NUMBER: AK-MW-40097 KELLY BUSHING ELEV. = 65.58 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11618 9025.45 8959.87 91 18 S 57.40 W 1.49 2414.09S 5101.62W 11634 9025.10 8959.52 91 11 S 57.70 W 1.98 2422.67S 5115.12W 11665 9024.59 8959.01 90 41 S 58.10 W 2.07 2439.14S 5141.38W 11695 9024.25 8958.67 90 35 S 57.10 W 3.35 2455.22S 5166.70W 11727 9024.22 8958.64 89 30 S 57.90 W 4.25 2472.41S 5193.69W 5563.67 5579.65 5610.60 5640.57 5672.54 11758 9024.57 8958.99 89 11 S 57.50 W 1.61 2488.97S 5219.89W 11789 9025.03 8959.45 89 5 S 58.30 W 2.60 2505.45S 5246.15W 11821 9025.56 8959.98 89 0 S 57.10 W 3.76 2522.54S 5273.19W 11852 9026.24 8960.66 88 30 S 57.10 W 1.61 2539.38S 5299.21W 11882 9026.89 8961.31 89 0 S 56.70 W 2.13 2555.75S 5324.34W 5703.50 5734.46 5766.42 5797.39 5827.36 11913 9027.38 8961.80 89 11 S 56.70 W .64 2572.77S 5350.25W 11945 9027.85 8962.27 89 5 S 57.30 W 1.90 2590.20S 5377.08W 11977 9028.30 8962.72 89 18 S 57.30 W .62 2607.48S 5404.00W 12008 9028.62 8963.04 89 30 S 58.50 W 3.92 2623.96S 5430.26W 12040 9029.01 8963.43 89 5 S 57.40 W 3.66 2640.93S 5457.38W 5858.35 5890.32 5922.29 5953.25 5985.20 12071 9029.58 8964.00 88 48 S 57.80 W 1.61 2657.54S 5483.55W 12102 9030.12 8964.54 89 11 S 58.20 W 1.83 2673.97S 5509.84W 12133 9030.48 8964.90 89 30 S 58.20 W .97 2690.30S 5536.18W 12164 9030.61 8965.03 90 0 S 58.20 W 1.61 2706.64S 5562.53W 12196 9030.83 8965.25_ 89 11 S 58.20 W 2.50 2723.50S 5589.72W 6016.17 6047.12 6078.07 6109.02 6140.97 12227 9031.38 8965.80 88 48 S 57.70 W 2.07 2739.95S 5615.99W 12251 9031.92 8966.34 88 35 S 58.90 W 5.07 2752.55S 5636.41W 12300 9033.12 8967.54 88 35 S 58.90 W .04 2777.86S 5678.35W 6171.92 6195.87 6244.75 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6321.40 FEET AT SOUTH 63 DEG. 55 MIN. WEST AT MD = 12300 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 235.00 DEG. TIE IN POINT 8394.42' WINDOW POINT 8482' INTERPOLATED DEPTH 12300' SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/F-17A 500292065201 NORTH SLOPE COMPUTATION DATE: 2/28/95 DATE OF SURVEY: 011095 JOB NUMBER: AK-MW-40097 KELLY BUSHING ELEV. = 65.58 FT. OPERATOR: BP EXPLORATION 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 DIFFERENCE VERTICAL CORRECTION 8394 6999.41 6933.83 1550.20 S 3465.80 W 1395.01 9394 7909.50 7843.92 1659.16 S 3842.07 W 1484.92 10394 8855.08 8789.50 1785.26 S 4134.94 W 1539.34 11394 9030.82 8965.24 2291.91 S 4914.48 W 2363.60 12300 9033.12 8967.54 2777.86 S 5678.35 W 3266.88 89.91 54.42 824.26 903.28 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. Anchort SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/F-17A 500292065201 NORTH SLOPE COMPUTATION DATE: 2/28/95 DATE OF SURVEY: 011095 JOB NUMBER: AK-MW-40097 KELLY BUSHING ELEV. = 65.58 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 8394 6999.41 6933.83 1550.20 S 3465.80 W 1395.01 8481 7065.58 7000.00 1571.06 S 3519.08 W 1416.32 8603 7165.58 7100.00 1593.18 S 3584.79 W 1438.25 8713 7265.58 7200.00 1602.68 S 3628.11 W 1447.79 21.31 21.93 9.54 8818 7365.58 7300.00 1608.44 S 3660.30 W 1453.01 8924 7465.58 7400.00 1615.06 S 3693.57 W 1458.61 9030 7565.58 7500.00 1623.11 S 3728.01 W 1464.69 9136 7665.58 7600.00 1633.66 S 3761.90 W 1470.80 9242 7765.58 7700.00 1643.94 S 3795.57 W 1476.82 5.22 5.60 6.08 6.11 6.02 9348 7865.58 7800.00 1654.34 S 3828.22 W 1482.54 9453 7965.58 7900.00 1664.98 S 3859.68 W 1487.91 9558 8065.58 8000.00 1675.12 S 3891.01 W 1493.19 9663 8165.58 8100.00 1685.53 S 3920.64 W 1498.01 9768 8265.58 8200.00 1695.33 S 3950.55 W 1502.84 5.72 5.37 5.28 4.82 4.84 9872 8365.58 8300.00 1705.39 S 3979.39 W 1507.41 9977 8465.58 8400.00 1715.71 S 4006.83 W 1511.63 10081 8565.58 8500.00 1725.70 S 4035.22 W 1516.06 10186 8665.58 8600.00 1738.33 S 4064.45 W 1521.04 10294 8765.58 8700.00 1760.13 S 4098.53 W 1528.94 4.57 4.21 4.43 4.98 7.90 10406 8865.58 8800.00 1789.01 S 4140.47 W 1541.29 10541 8965.58 8900.00 1839.56 S 4214.90 W 1576.38 12300 9033.12 8967.54 2777.86 S 5678.35 W 3266.88 12.35 35.09 1690.50 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS STATE OF ALASKA ALA?~'~OIL AND GAS CONSERVATION COMMISSIr'-~-. REPORT SUNDRY WELL OPL..ATIONS Operations performed: Operation shutdown . Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3065' SNL, 2197' WEL, sEC. 2, T11N, R13E At top of productive interval 329' NSL, 1206' WEL, SEC. 3, T11N, R13E At effective depth 543' SNL, 2514'WEL, SEC. 10, T11N, R13E At total depth 563' SNL, 2595' WEL, SEC. 10, T11N, R13E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KB = 65.98' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number F-17a (31-10-11-13) 9. Permit number/approval number 94-163 / 10. APl number 50- 029-20652-01 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110' Surface 2693' Intermediate 8451 Production -- Liner 5742 Perforation depth: measured 12300' feet 9033' feet 12214' feet 9031' feet Size Plugs (measured) Junk (measured) Cemented 8 cy yds concrete 3280 cu ft PF II 444 cuft Class "G" !O" x 30" 13-3/8" 9-5/8" 7" 525 sx Class "G" 11185'-11460', 11850'-12223' Measured depth 137 272O 8478 8277-10812 True vertical depth BKB 137 2668 7024 6873-9009 true vertical subsea 9032'-9029, 9027'-9031' Tubing (size, grade, and measured depth) 3-1/2", L-80 to 10457' Packers and SSSV (type and measured depth) Packer @ 10409' SSS V @ 2033' FEB 26 1996 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure Al,~ska 0il & Gas Cons. Core, mission Anchom, ge 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 236 1638 19 0 229 Subsequent to operation 431 1429 101 0 217 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operati~!;}s Oil X Gas Suspended 17. I herebv.,certi, N that t~e fore(~(~ing is true arid c,~rmct to the best of my knowledge. Form 10-404 Rev 06/15/88 Service SUBMIT IN DUPLICATE 3/18/95 WELL F-17a (31-10-11-13) Addperf The following additional interval were perforated 1/2" guns, 4 SPF, zero orientation and 0° phasing. using 2 9/21/95 11482'-l1502'MD 11502'-11522'MD 11522'-11542'MD 11542'-11562'MD _ Addperf The following additional interval were perforated 1/2" guns, 4 SPF, zero orientation and 90° phasing. using 2 11738'-11758'MD LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 31 August 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: . ' ~ ?~"/:.. ~.~./.-.'~ '~s ~u~ ~+~ '-- ' ' ' G IOA ~.t"'-:~:"~'-----; ~."-'1 PLS FIN~ BL+~ ...:: Please sign and return to: Attn.' Rodney D -Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by-~//~ ' Date ~as ///'v . ...... 0 !:t I I--I-- I IM G S~I:I~I r' E S WELL LOG TRANSMITTAL To: State of Alaska June 20, 1995 Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 c{ ~f --/~ 3 MWD Formation Evaluation Logs - F-17A AK-MW-40097; AK-RB-950101 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-20652-01 1 Blueline 1 Rev Folded Sepia 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-20652-01 1 Blueline 1 Rev Folded Sepia RECEIVED JUN 2,5 1995 Alaska 0il & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3,,25.6 · Fax (907) 563-7252 A Dresser Industries, Inc, Company LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 7 February 1995 RE: Transmittal of Data Sent by: MAIL Dear sir/Madam, Enclosed, please find the data as described below: WELL 73 -- 7 C-04 B-19 C-31 ST (21-11-14% DESCRIPTION 1 PLS FINAL BL+RF 1PLS FINAL BL+RF 1PLS FINAL BL+RF 1PLS FINAL BL+RF 1 CCL FIN~ BL+RF 1PLS FINAL BL+RF ECC No. Run # 1 1423.07 Run # 1 3964.04 Run # 1 4335.02 Run # 1 5806.03 Run # 1 6290.01 Run # 1 6354.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Received by: Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 RECEIVED Date: FEB 17 1995 Alaska 011 & Gas Cons. Commission Please sign and retu~n to: Anchorage Petrctechnica! Data Cente.~ BP w-~ ........ +~'~ (Alaska) In~ 900~a~'~3 Benson Boulevard ' ~ec,.ived by .... : .... : ALASKA OIL AND GAS CONSERVATION COM~HSSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 22, 1994 Terry Jordan, Drlg Engr Supv BP Exploration (Alaska) inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit F-17A BP Exploration (Alaska) Inc 94-163 2215'NSL, 2197'WEL, Sec 2, T11 N, R13E, UM 5055'NSL, 1985'WEL, Sec 10, T11N, R13E, UM Dear Mr Jordan: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. 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 a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the Nodh Slope pager at 659-3607. Chairman ~ BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA UlL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrillb-"]llb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil[] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 12. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 65.88 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Poo/ P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 28281 4. Location of well at sur]ace 7. Unit or property Name 11. Type Bond(~ee 20 Mc 25.025 2215' NSL, 2197' WEL, SEC. 2, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 236'NSL, 1326' WEL, SEC. 3, T11N, R13E F-17A (31-10-11-13) 25100302630-277 At total depth 9. Approximate spud date Amount 5055' NSL, 1985' WEL, SEC. 10, T11N, R13E 12/'26/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD ,,d 'rw)) property line ADL 28280-1985 feet No close approach feet 2560 11592' MD/9004' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (me 2o AAC 25.035 (e)(2)) Kickoff depth esoo feet Maximum hole angleg~.z9 o Maximum surface 3330 pslg Al total depth (TVD) ~00'/4390 pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 NSCC 2438' 8350' 7000' 10788' 9030' 180 sx Class "G" 6" 4-1/2" 12.6# L-80 NSCC 900' 10692' 9022' 11592' 9004' Uncemented slotted liner · . 19. To be completed for Redrill, Re-entry, and Deepen Operations. L ~ L I V L ~,~ Present well condition summary Total depth: measured 11480 feet Plugs (measured) 't 6 '199z true vertical 9176 feet ^~s~. UAl & Gas Cons, Commission Effective depth: measured 11182 feet Junk (measured) ~ch0r~,. - true vertical 8992 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 20"x 30" 8 cu yds 142' 142' S u rface 2688' 13-3/8" 3280 cuft 2720' 2706' Intermediate 10285' 9-5/8" 1605 cuft 10317' 8422' Production Lin e r 1674' 7" 444 cuft 9806; 11480' 8063'-9176' Perforation depth: measured 11132;11138', 11164;11174', 11174'-11182'(open)11000;11238'(Tsqueezedintervals) true vertical 8889;8921'3 open intervals) 8807;8976' (7 squeezed intervals) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l'21 Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed report• 20 AAC 25.050 requirements• 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Sign ed ~It~ ,~..-~ "~-~,.¢~, ~ ~~ Title Drilling En~lineer Supervisor Date (27~(o/~ v j¢ Commission Use Only Permit Number IAPI number tApproval date ISee cover letter c~/~-//~'~,~ [50-O .2.. ,~' -- .2_ ~ .~' ~_-'C'~ ?I [for other requirements Conditions of approval Samples required [] Yes .RI No Mud Icg required []Yes J~ No Hydrogen sulfide measures [] Yes 'B3 No Directional survey required ~ Yes [] No Required working pressure for BOPE I-'I2M- 1-13M; ~r,5M; E]10M; I-I15M; Other: by order of Approved by Commissioner zne commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate IWell Name: ]DS F-17A Redrill Plan Summary Type of Redrill (producer or injector): ] Producer I ISurface Location: I 2214 FSL 2197 FEL S02 T11N R13E UM Target Location: 236 FSL 1326 FEL S03 T11N R13E UM Bottom Hole Location: 5055 FSL 1985 FEL S10 TllN R13E UM I AFENumber: l unknown I I Rig: I Nabors 2ES Estimated Start Date: I January, 95 I I Operating days to complete: 12~ MD: I 11592' ] [TVD: I 8938ss I ! KBE: 165.88 Well Design (conventional, slimhole, etc.): I Horizontal Sidetrack Objective: F-17A will access untapped Zone 1 reserves, obtain additional standoff from the Zone 2 gas, and move towards better quality Zone 1 rock. Hazards Mud Program: ISpecial design considerations After dressing off the kickoff plug we will displace to KCL system (Xanvis) and drill to 7" shoe depth with @ 10.00 ppg to 10.20 ppg. Horizontal hole ( 6" ) will be drilled with Flo-Pro mud with 9.00 ppg. Density PV YP INT 10MIN FL OIL SOLIDS (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 10.00 14 47 22 31 6.5 0 7 tO tO tO tO tO tO tO tO tO 8.5"TD' 10.2 15 47 22 30 6 0 7 6" Holer -- 9.0 8 32 19 22 5.8 0 0.25 Directional: I KOP: 1850O MD I Maximum Hole Angle: ] 91.79° Close Approach Well' NONE Casing/Tubin:: Prog ram: ~ Wt/Ft Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8.5 7" 29# L-80 nscc 2438 8350/7.,~ 10788/9030 VED D ' EC 1 9 '1994 Alaska Uti & Gas Cons. Commission Anchors ~. 6 4.5" slotted L-80 nscc 900 10692/9022 11592/9004 N/A 4.5" 12.6 L-80 nscc 10200 Surface 10200/8690 Cement Calculations: [ Liner Size: 1 7" Basis:I 503/0 open hole ex~ess, 80' shoe joint, 150' liner lap and 150' excess above line~' with DP. Total Cement Volume: @ 180 sxs of Class G Blend @ 1.18 ft3/sx [ Liner Size: 1 4.5" (Slotted Liner). No cement Basis:I Total Cement Volume: Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. .SUMMARY PROCEDURE:. 1. Move in drilling rig. Test 9-5/8" intermediate casing pack-off if not done during pre-rig work. 2. Pull BPV. Circulate diesel freeze protection cap from well and recover for future use. 3. Install a BPV and test tree plug to 1000 psi.. Remove the production tree. 4. Install BOP's and test to 250 psi / 5000 psi. Remove the test plug and BPV. 5. Pull and lay down the 5-1/2" tubing from the cut to surface. Inspect for NORM prior to moving off the location. 6. P/U bridge plug. RIH and set it at 8700' MD (~ 200' below proposed 9-5/8 section). P&A well by using down squeeze method. 7. Displace to milling fluid and spot a 18 ppg pill on bottom and cut a 45' section in the 9-5/8" casing starting from about 8500' MD. 8. Spot a balanced cement kick-off plug (180 cubic feet minimum) through open- ended drillpipe from 100' below the base of the section to 200' above the top of the section. 9. Run in with an 8--1/2" steerable drilling assembly ( Incl'd GR / MWD ) and dress the cement to 5' below the section top. Prior to kickoff circulate hole clean so that it is free of cement. Kickoff and directionally drill to the target with 91.87° hole angle at 8964'ss as per the attached directional plan. Obtain Direction / GR / CNL formation evaluation logs via drill pipe conveyed method starting from the top of the Sag River Fm. ~ E C ElY E D DEC 1 6 199~ Alaska .Oil & Gas Cons. Commission : gnchora ,~, 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Run a 7" 29 # L-80 liner assembly to bottom in the 8-1/2" hole and space the liner hanger (L-80) and top isolation packer (L-80) 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 80' shoe volume, 150' lap volume and 150' excess on top of the liner with drillpipe in the hole. ( Note: if the caliper Icg is available use it and add 20% to caliper volume ) P/U 6" bit and drilling assembly ( Incl'd GR / MWD ) and clean-out 7" liner plus drill @ 10' of new hole. Displace to FIo-Pro fluid. Drill 6" horizontal section to TD @ 11562' MD as per directional plan. ( Catch Samples as described in Side Track General Notes ) Run 4.5" slotted liner. Space out and set TIW 7 x 4.5 packer so that it does not cover any possible additional zones of interest that may be perfed later. Run the 3-1/2" L-~0 completion string assembly. Space out and circulate with corrosion inhibitor before setting the tubing packer. Test tbg to 4000 psi. Install a BPV and test plug. Remove B©P's. Install and test the production tree to 5000 psi. Pull tree test plug and BPV. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear FIP valve in the upper GLM and freeze protect the well. Set a BPV. Release rig. Complete appropriate documentation and hand-over to Production Additional Information; , Ivishak Sand BHP = 3535 psi or 7.72 ppg EMW at 8800 TVDss ( Estimated. Based on offset well information ) Top of Sag River Gas @ 9956 MD/8443 TVD. Est. BHP = 3700 psi or 8.4 ppg EMW. Possible Hazards and Contingency Plan: In the event that the trouble is encountered while drilling 8.-5" hole ( i.e. differential sticking, tight hole ect... ) we will set 7-5/8" liner and drill to TD, including horizontal, with 6.75" bit and will do one of the following things: a) b) c) Will run 4.5" slotted liner x 4.5" solid liner utilizing ECP Will run / cmt 5.5" liner and DP conveyed perforate with 3-3/8" guns Will line-Out well to taroet and run / cmt 4.5" liner and have CTU drill it out. RECEIVED DEC 1 6 1994 A!aSka Oil & Gas Cons. Commission Anchora - , _ ....... _pR.U.OHOb B.,,A.,,Y OR T _L Z NG GROUP , i i ii ii1! , .......... A) T~E-ZN / K0P 8/~00 8500 7079 37~5 40.54 B) ~NB QF 8/,00 gURVE 87B7 73~9 3930 i7.56 VERTICAL SECTION VIEW E) ~NO OF ~5/~00 6URVE ]0788 9030 4744 g~.7g Section at: 235.00 F) .TO t~592 ~004 554g gJ.Tg TVD Scs]e.' Z &nc~ = ~200 fee~ . Oep Scale.' J inch ~ ~200.feet <KB> o' j .... "' ],,:Oes~n - ]2/]2/94 . 600 ....... .: ......... _.. ____, .... i ~nadri 1] ,,~h]umberger . ..................... ~200 ..... fSO0 .I ................ ~ .................. m ; ANADRtLL ~KA-DPC . , 2400 ' ', i ~ ...... B ~ooo- , % i' - . ~ , - .... : B ' 3600 ,,, ~ ........................ 4800 '"~,, ....................... ~.._._... ..... '"' ........................................... ,..~..,,, . ........... . ..... [[E"C E IV E ).... ,..:'" '":- 6000" '~':~ ' ~;~ ........... , ........... - *~ ,= - - ' . I i ,, AikS~ JJl & Gas gons. Col imissJon as00--- i -~-~C=_: ' -~ .... ,,-%:' ......... - ......... '~-'~ ~ ...... ~ I ~ ' '-~ ~ ~ ....... .... : ............... , ........... ._....,~ .- ...... :::::~ .......... ~ - ~00 -- - ~ ............ -1200 -600 0 600 1200 t800 2400 3000 3500 4200 4800 5400 6000 6600 7200 Section Bepsmtume l~¢~J~ l~)g9 F~2~ BJ_~2 ~:n~ ~ ~ "' ' ". ..... ~ 5~00 Anadrj l ] Schlumberger F- 17A (P4) PLAN V - mi i i i CLOSURE · 5623 fbet at Azimuth 244,30 PRUDHO'E BA'Y _ ,_a , I]RILLIN$ (3ROL!p imlll i . · mil ..... m · )ECL IN/),f I ON - 29 338, E ] . I i ! 'I I t ! ~CALE ' 1 inch = 200 feet I i : : · )F:JA~Im',l · ~_I:12/q4 i ....... ,?- . ,, . ---- 7 ! ~ ,,mm ' A ~' ~'~' 4arker' Ider~Lif ication ),iD N/S E/W ! - ' .. -."~' - . ........ ~1 TIE-IN / KOP.8/IO0 8500 1575 3530 I .'.] START iS/tOO CURVE 10209 )779 4085 I ]] TAFt, E f lO/DB i977 4408 · _-] END OF 15/100 CraVE 10~88 i977 4408 _....,~.~' J ..... ............. ..... ~_ T.~~ ~ ....... ! / ........... " ~ ~. AN DRILL )PC ', · :,,,. I .i .... ,- == i ./ '~"-- /- ' ' ,..o ~ INITIAL · -- =,.,. ..~__~ ~ . ~: - ,._.~' · .: I / .... , _~. I : I °1 ,i ..... . . =' ... ; : i. i .... ! ..... _.i L__. ~ , i , .................. : ......... : . .. ....... :.. i - :, ...... ......... ......... i ............ ~ ....... I 5'100 5000 4'900 4800 4700 ,tBO0 4500 4400 4300 4200 4JO0 4000 3900 3BOO 3700 3600 3500 3400 <- NEST _ _ _ I~ma'Jrlil !c]93 FI?AD4 B1 ,.,::' ~ 'J: 10 ~H )] 1400 lBO0 t900 oo BP EXPLORATION BP Exploration (Alaska) Inc. P,O. Box I96612 Anchorage, Alaska 99519-6612 ARCO Alaska, Inc. . TELECOPY TO: FROM: NOTES: SATELLITE UNIT Name: __ .'~_. co Location: ..... .., ... _ .... Name & E=.: -, ~~% .... )_G- ' Depa~ment: ~ ,. - , .... RECEIVED PAGES TO FOLLOW _ DEC 19 t994 _Alaska 0il & Gas Cons. Comm_'tssF~-r~ ~ngho[ag.~, .... (Do not include cover sheet) SECURITY CLASSIFICATION PRIVATE SECRET SATELLITE FAX MACHINE CONFIDENTIAL ----.,, ,, .- FAX# ......907 564-5193 CONFIRM# 907 564- Z' r~ ~. STATE OF ALASKA AL/ ~, OIL AND GAS CONSERVATION COMMISS APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend __ Operation Shutdown__ Re-enter suspended well__ Alter casing__ Repair well__ Plugging x , Time extension__ Stimulate __ Change approved program ,. Pull tubing Variance__ Perforate__ Other x ~ Plugbcck for redrlll 2. Name of Operator 5. Type of Well: 6. BP Exploration Development x Exploratory __ 3. Address Stratigraphic __ 7, P. O. Box 196612, Anchorage, Alaska 99519-6612 Service__ 4. Location of well at surface 8. 2215'NSL, 2197' WEL, SEC. 2, T11N, R13E At top of productive interval 9. 262'NSL, 1607' WEL, SEC. 3, T11N, R13E At effective depth 10. 130'NSL, 2244' WEL, SEC. 3, T11N, R13E At total depth 11. 97' NSL, 2475' WEL, SEC. 3, T11N, R13E 12. Present well condition summary Total depth: measured 11480 feet Plugs (measured) true vertical 9176 feet Effective depth: measured 11182 feet true vertical 8992 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Datum elevation (DF or KB) KBE = 71.46 Unit or Property name Prudhoe Bay Unit Well number F-17(34-3-11-13) Permit number 81-131 APl number 50- 029-20652 Field/Pool Prudhoe Bay Field/Oil Pool Junk (measured) fill @ 11182' (5/90) Length Size Cemented Measured depth True vertical depth feet 110' 20" x 30" 8 cu yds 142' 2688' 13-3/8" 3280 cu ft 2 720' 10285' 9-5/8" 1605 cu ft 10317' 142' 27O6' 8422' 1674' 7" 444 cu ft measured 11132'-11138, 11164'-11174', 11174'-82'(open) 11000'-11238' (7 squeezed intervals) true vertical 8889'-8921' ( 3 open intervals) 8807'-8976' ( 7 squeezed intervals) Tubing (size, grade, and measured depth) 5-1/2", L-80 tubing to 9757' w/4-1/2" tailpipe to 9891' 9806s11480' Packers and SSSV (type and measured depth) 9-5/8" Baker SAB packer @ 9757~ 5-1/2" SSSV @ 2081' 8063'-9176' RECEIVED DEC 1 6 1994 Alaska Oil & Gas Cons. Commissl~ Anch0ra!~e 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 12/21/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas ,., Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed'~f~. ~----~/.~,, ~ ~.'"'{,)~,~,~,t Title Drilling EngineorSupervisor - ~ ~/ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test__ Mechanical Integrity Test~ Approved by order of the Commission Location clearance Subsequent form required 10- Commissioner Date Form 10-403 Rev 06/15/88 ~ SUBMIT IN TRIPLICATE PERMIT CHECKLIST WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev [] redrll~ aery [] //Jr ON/OFF s.o ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. ~Y 6. Well located proper distance from other wells ..... ' 7. Sufficient acreage available in drilling unit ..... .IY 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... .~ 12. Permit can be issued without administrative approval..t~ 13. Can permit be approved before 15-day wait ....... ENGINEERING APPR 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ....... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22 Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ............ __. ....... 26. BOPE press rating adequate; test to ~ O-~ psig~ 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. GEOLOGY APPR D~ · ,. -- 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... Y / 33. Seabed condition Survey (if off-shore) ........ N 34. [exploratory only] / Contact name/phone for weekly progress reports .... GEOLOGY ~. ENGINEERING: COMMISSION: Comments/Instructions: Z .... ~"c:~.heklist rev 03/94 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 * , ............................ . ....... SCHLUIViBERGER ....... JUL 0£ 1998 ,~Jaska Oil & Gas ~ns. Commission An6horage COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAI~i~ : F- 17A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292065201 REFERENCE NO : 98293 Date_~~....._. LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/06/26 ORIGIN · FLIC REEL NA~E : 98293 CONTINUATION # : PREVIOUS REEL : C0~4~2~T · BP EXPLORATION, F-17A, PRUDHOE BAY, API # 50-029-20652-01 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE . 98/06/26 ORIGIN : FLIC TAPE NAME : 98293 CONTINUATION # : 1 PREVIOUS TAPE : CO~4MENT : BP EXPLORATION, F-17A, PRUDHOE BAY, API# 50-029-20652-01 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: F-17A API NUMBER: 500292065201 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 26-JUN-98 JOB NUMBER: 98293 LOGGING ENGINEER: H KIRKBY OPERATOR WITNESS: K BULLOCH SURFACE LOCATION SECTION: 2 TOWNSHIP .. 1 iN RANGE: 13E FNL : FSL: 2215 FEL: 2197 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 65.98 DERRICK FLOOR: 64.58 GROUND LEVEL: 38.19 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 4. 500 12300.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN ND?4~ER : PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 10702.5 10697.5 10692.5 10676.5 10675.0 10659.0 10657.0 10651.5 10649.5 10646.0 10643.0 10636.5 10633.5 10629.5 10629.0 10623.5 10619.5 10619.0 10617.0 10610.5 10607.5 10602.5 10596.0 10595.0 10593.0 10588.0 10579.5 10572.0 10558.0 10553.0 10542.0 10533.0 10532.0 10526.5 10521.5 10515.5 10507.0 10506.0 10500.0 10498.0 10494.5 10491.5 10481.5 10477.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH RST .............. 88891 . 5 88894.5 10709.0 10701.0 10701.0 10695.0 10695.0 10677.0 10677.0 10660.5 10660.0 10654.0 10654.0 10651.5 10651.5 10647.5 10646.0 10642.5 10638.0 10633.5 10637.5 10630.0 10630.0 10626.0 10626.0 10621.5 10621.5 10612.0 10612.0 10609.0 10602.0 10598.5 10597.5 10597.5 10593 . 0 10593 . 0 10585.5 10585.5 10576.0 10576.0 10558.5 10558.5 10554.5 10554.5 10545.0 10545.0 10532.5 10532.5 10530.5 10530.5 10525.0 10525.0 10521.0 10521.0 10513.5 10513.5 10504.5 10504.5 10500.0 10500.0 10493.5 10493.5 10484.0 10480.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 10472.0 10473.5 10468.5 10469.5 10462.0 10465.5 10461.5 10465.5 10456.0 10458.5 10455.5 10458.5 10450.0 10451.5 10451.5 10448.5 10450.5 10450.5 10445.5 10447.5 10447.5 10436.0 10439.0 10439.0 10432.5 10434.5 10432.0 10434.5 10429.0 10431.5 10426.5 10428.0 10428.0 10421.0 10424.0 10414.5 10415.5 10414.0 10415.5 10412.0 10411.5 10405.0 10407.0 10403.0 10406.0 10402.0 10406.0 10398.5 10400.5 10397.5 10400.5 10393.0 10395.0 10395.0 10388.5 10389.5 10389.5 100.0 101.0 101.0 $ REY~KS: CO1PTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON BP EXPLORATION'S F-17A WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE MWD GAbP4A RAY, ALSO BASE PASS #1 SIGMA AND THE MWD GA2PqA RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/06/26 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. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: FILE SU~ff4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10709.5 10381.0 RST 10722.5 10381.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH RST R~S: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1209226 O0 000 O0 0 1 1 1 4 68 NBAC RST CPS 1209226 O0 000 O0 0 1 1 1 4 68 FBAC RST CPS 1209226 O0 000 O0 0 1 1 1 4 68 SBNA FIL CU 1209226 O0 000 O0 0 1 1 1 4 68 SFNA FIL CU 1209226 O0 000 O0 0 1 1 1 4 68 SBFA FIL CU 1209226 O0 000 O0 0 1 1 1 4 68 SFFA FIL CU 1209226 O0 000 O0 0 1 1 1 4 68 TRAT FIL 1209226 O0 000 O0 0 1 1 1 4 68 IRAT FIL 1209226 O0 000 O0 0 1 1 1 4 68 CIRNFIL 1209226 O0 000 O0 0 1 ! 1 4 68 CIRF FIL 1209226 O0 000 O0 0 1 1 1 4 68 BSALRST PPK 1209226 O0 000 O0 0 1 1 1 4 68 SIBF RST CU 1209226 O0 000 O0 0 1 1 1 4 68 TPHI RST PU-S 1209226 O0 000 O0 0 1 1 1 4 68 SFFC RST CU 1209226 O0 000 O0 0 1 1 1 4 68 SFNC RST CU 1209226 O0 000 O0 0 1 1 1 4 68 SIGM RST CU 1209226 O0 000 O0 0 1 1 1 4 68 DSIG RST CU 1209226 O0 000 O0 0 1 1 1 4 68 FBEF RST UA 1209226 O0 000 O0 0 1 1 1 4 68 CRRARST 1209226 O0 000 O0 0 1 1 1 4 68 GRCH RST GAPI 1209226 O0 000 O0 0 1 1 1 4 68 TENS RST LB 1209226 O0 000 O0 0 1 1 1 4 68 CCL RST V 1209226 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10722.500 NBAC.RST SFNA.FIL 21.808 SBFA.FIL IRAT. FIL 0.426 CIRN. FIL SIBF.RST 75.234 TPHI.RST SIGM. RST 16.664 DSIG.RST GRCH. RST -999.250 TENS.RST DEPT. 10381.000 NBAC.RST SFNA.FIL 17.268 SBFA.FIL IRAT. FIL 0.446 CIRN. FIL SIBF.RST 64.923 TPHI.RST SICM. RST 11.275 DSIG.RST GRCH.RST 9.280 TENS.RST 2304 813 51 326 0 795 39 577 3 555 1429 000 FBAC.RST 4952.941 SBNA.FIL 56.344 SFFA.FIL 18.993 TRAT. FIL 0.964 CIRF.FIL 1.933 BSAL.RST 142.454 SFFC.RST 16.643 SFNC.RST 19.497 FBEF.RST 61.334 CRRA.RST 2.327 CCL.RST 0.001 2171.445 FBAC.RST 2860.428 SBNA.FIL 62.380 54.273 SFFA.FIL 13.266 TRAT. FIL 0.724 0.765 CIRF. FIL 2.404 BSAL.RST 116.615 17.852 SFFC.RST 11.278 SFNC.RST 14.105 2.453 FBEF.RST 57.019 CRRA.RST 2.172 1485.000 CCL.RST -0.031 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 98/06/26 ~ REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS ~ER : 2 DEPTH INCRESIENT: 0.5000 FILE SUR2VgLRY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10705.0 10393.5 RST 10719.5 10392.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 10701.5 10697.5 10692.5 10681.0 10676.5 10674.0 10669.5 10663.0 10657.0 10649.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88891.0 88895.5 10700.5 10694.5 10686.5 10677. 0 10664. 0 10659.0 10651.5 10709.0 10677.0 10671.0 10664.0 10652.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 10648.0 10650.5 10643.0 10646.0 10639.0 10641 . 5 10635.0 10641.5 10630.0 10637.5 10626.5 10633.5 10623.0 10630.0 10622.5 10630.0 10618.0 10625.5 10614.0 10618.5 10612.0 10621.5 10606.5 10615.5 10595.5 10599.0 10593.0 10597.0 10587.5 10593.0 10585.0 10591.0 10582.5 10589.0 10579.5 10585.5 10570.5 10575.5 10560.5 10564.0 10557.5 10558.5 10553.5 10555.0 10544.5 10547.5 10544.0 10545.0 10537.5 10538.5 10533.5 10535.0 10530.5 10529.5 10528.0 10527.0 10523.0 10523.0 10522.5 10517.0 10516.5 10515.0 10514.0 10514.0 10513.0 10505.5 10504.5 10500.0 10500.0 10497.5 10500.0 10494.5 10493.5 10491.5 10493.5 10486.0 10488.0 10481.5 10484.0 10477.5 10480.5 10475.0 10476.5 10471.5 10473.5 10469.0 10471.5 10467.5 10469.5 10464.0 10468.0 10462.0 10465.5 10460.5 10465.0 10459.0 10462.5 10456.0 10459.5 10454.5 10457.5 10450.0 10452.5 10446.5 10452.0 10445.0 10447.5 10441.0 10444.0 10437.5 10441.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 10437.0 10440.0 10434.5 10438.5 10431.5 10434.5 10434.0 10429.5 10432.0 10428.5 10431.5 10426.5 10428.0 10425.0 10427.0 10421.5 10423.5 10420.0 10424.0 10414.5 10416.0 10413.5 10416.0 10411.5 10411.5 10404.5 10407.5 10407.0 10401.0 10405.5 10398.0 10400.5 10396.0 10400.0 10394.5 10398.0 10393.0 10395.5 100.0 103.5 102.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1209226 O0 000 NBAC RST CPS 1209226 O0 000 FBAC RST CPS 1209226 O0 000 SBNA FIL CU 1209226 O0 000 SFNA FIL CU 1209226 O0 000 SBFA FIL CU 1209226 O0 000 SFFA FIL CU 1209226 O0 000 TRAT FIL 1209226 O0 000 IRAT FIL 1209226 O0 000 CIRNFIL 1209226 O0 000 CIRF FIL 1209226 O0 000 BSAL RST PPK 1209226 O0 000 SIBF RST CU 1209226 O0 000 TPHI RST PU-S 1209226 O0 000 SFFC RST CU 1209226 O0 000 SFNC RST CU 1209226 O0 000 SIGM RST CU 1209226 O0 000 DSIG RST CU 1209226 O0 000 FBEF RST UA 1209226 O0 000 CRR~RST 1209226 O0 000 GRCH RST GAPI 1209226 O0 000 TENS RST LB 1209226 O0 000 CCL RST V 1209226 O0 000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 65 0000000000 ** DATA ** DEPT. 10719.500 NBAC.RST 2305.445 FBAC.RST 3074.199 SBNA.FIL SFNA.FIL 22.542 SBFA.FIL 47.442 SFFA.FIL 18.916 TRAT. FIL IRAT. FIL 0.434 CIRN. FIL 0.779 CIRF. FIL 1.933 BSAL.RST SIBF.RST 73.211 TPHI.RST 35.746 SFFC.RST 16.588 SFNC.RST SIGM. RST 16.587 DSIG.RST 3.151 FBEF.RST 60.280 CRRA.RST GRCH.RST -999.250 TENS.RST 1457.000 CCL.RST 0.004 DEPT. 10392.500 NBAC.RST 2277.719 FBAC.RST 2912.903 SBNA.FIL SFNA.FIL 15.991 SBFA.FIL 57.541 SFFA.FIL 12.751 TRAT. FIL IRAT.FIL 0.438 CIRN. FIL 0.799 CIRF. FIL 2.324 BSAL.RST SIBF.RST 69.983 TPHI.RST 23.036 SFFC.RST 10.926 SFNC. RST SIGM. RST 10.900 DSIG.RST 2.180 FBEF.RST 57.946 CRRA.RST GRCH.RST -999.250 TENS.RST 1496.000 CCL.RST 0.000 59.739 0.925 137.452 19.875 2.318 65.472 0.784 129.399 13.508 2.249 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 10 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCRE~fENT: 0.5000 FILE SUF~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10688.5 10284.0 RST 10710.5 10283 . 5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 BASELINE DEPTH 88888.0 10700.5 10682.0 10680.5 10674.0 10673.0 10669.5 10664.5 10661.5 10657.0 10656.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88884.5 88896.5 10677.0 10672.0 10664.5 10659.0 10709.0 10684.0 10677.0 10671.5 10664.5 10660.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26~JUN-1998 16:05 PAGE: 11 10650.0 10653.0 10648.5 10651.5 10650.0 10645.0 10647.5 10644.0 10647.5 10642.5 10646.0 10637.5 10640.5 10636.0 10642.0 10632.0 10637.5 10626.5 10635.0 10626.0 10633.5 10624.0 10628.5 10621.5 10631.0 10618.0 10621.5 10617.0 10625.5 10612.0 10612.5 10610.5 10615.5 10604.5 10609.0 10600.5 10606.0 10599.0 10597.5 10597.5 10600.0 10594.0 10598.5 10587.0 10592.5 10586.5 10585.5 10584.5 10591.0 10582.0 10589.0 10578.0 10585.0 10573.5 10579.5 10570.5 10572.0 10557.0 10558.5 10552.0 10555.5 10543.5 10545.0 10548.0 10540.0 10540.5 10533.5 10535.5 10534.5 10532.0 10533.0 10529.5 10529.5 10528.5 10527.5 10526.5 10526.5 10521.0 10522.0 10513.0 10512.5 10509.5 10511.0 10508.0 10508.5 10505.0 10504.5 10496.5 10500.5 10494.0 10493.5 10488.0 10491.5 10486.0 10488.0 10484.0 10487.0 10480.5 10484.5 10479.5 10480.5 10478.5 10481.5 10473.5 10477.0 10470.0 10473.5 10467.5 10469.0 10462.5 10468.0 10461.5 10465.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 12 10459.5 10456.0 10454.5 10452.5 10449.0 10446.0 10445.0 10443.5 10439.5 10436.0 10434.5 10434 0 10431 5 10429 5 10427 5 10424 0 10423 5 10419 5 10419 0 10412.5 10409.5 10407.5 10403.5 10400.0 10398.0 10395.0 10394.5 10393.5 10391.0 10384.0 100.0 $ 10461.5 10458.0 10451.5 10450.5 10440.0 10438.5 10434.5 10431.5 10428.0 10424.0 10400.0 10398.0 10388.0 104.0 10465.0 10459.0 10452.5 10450.5 10447.5 10444.0 10438.5 10432.0 10427.5 10424.0 10415.0 10411.5 10409.5 10407.5 10403.5 10400.5 10397.5 10394.5 103.5 REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 13 TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 1! 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ND?4~ SAMP ELE~ CODE (HEX) DEPT FT 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF FIL 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 BSALRST PPK 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST CU 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RST UA 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 CRRARST 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V 1209226 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10710.500 N-BAC.RST 2260.250 FBAC.RST 3090.018 SBNA.FIL SFNA.FIL 30.278 SBFA.FIL 49.344 SFFA.FIL 25.394 TRAT. FIL IRAT. FIL 0.423 CIRN. FIL 0.548 CIRF. FIL 1.277 BSAL.RST SIBF. RST 74.603 TPHI.RST 43.945 SFFC.RST 22.295 SFNC.RST SIGM. RST 22.374 DSIG.RST 5.249 FBEF.RST 59.223 CRRA.RST 62.678 1.007 140.896 27.267 2.348 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 14 GRCH. RST -999.250 TENS.RST 1492.000 CCL.RST DEPT. 10283.500 NBAC.RST SFNA.FIL 14.926 SBFA.FIL IRAT. FIL 0.445 CIRN. FIL SIBF. RST 72.036 TPHI.RST SIGM.RST 9.887 DSIG.RST GRCH. RST -999.250 TENS.RST 2318.182 FBAC.RST 45.868 SFFA.FIL 0.899 CIRF. FIL 15.177 SFFC. RST 2.113 FBEF. RST 1500.000 CCL.RST O. 012 2894.204 11.857 2.995 9.815 53.133 0.000 SBNA. FIL TRAT. FIL BSAL. RST SFNC. RST CRRA. RST 61.530 0.680 134.529 11.848 2.111 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE AUJMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10704.0 10060.0 RST 10719.0 10064.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 15 BASELINE DEPTH 88888.0 10699.5 10691.0 10688.5 10683.5 10681.0 10677.0 10674.5 10667.5 10661.0 10657.5 10655.5 10651.0 10645.5 10643.0 10640.0 10635.0 10631.5 10628.0 10625.5 10621.5 10620.5 10617.5 10616.5 10610.5 10609.0 10603.0 10600.0 10595.0 10590.5 10589.5 10585.0 10580.5 10569.5 10552.0 10551.5 10548.0 10543.0 10541.5 10539.0 10537.5 10532.5 10530 0 10528 0 10520 5 10516 0 10511 5 10509 0 1O508.0 10504.0 10495.5 10488.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88892.0 88897.0 10695.0 10691.5 10682.5 10677.0 10665.0 10659.5 10653.0 10646.0 10637.5 10633.5 10628.0 10626.0 10612.5 10602.5 10593.0 10559.0 10555.0 10549.5 10545.0 10535.0 10514.0 10500.0 10493.0 10708.5 10687.5 10677.0 10671.0 10661.0 10651.5 10646.0 10642.5 10637.5 10630.0 10625.5 10615.5 10609.0 10599.5 10597.0 10591.5 10589.0 10575.5 10556.0 10548.0 10544.5 10535.0 10528.5 10522.5 10516.0 10512.5 10509.0 10504.5 10500.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 16 10482 0 10481 0 10477 0 10474 0 10473 0 10470 0 10469 5 10463 0 10462 0 10460.5 10458.5 10457.0 10456.0 10454.5 10453.5 10451.0 10448.5 10446.0 10439.0 10435.5 10433.0 10430.5 10426.5 10423.0 10420.5 10418.5 10412.0 10411.5 10409.0 10406.0 10403.0 10399.0 10395.0 10390.5 100.0 $ 10485.5 10484.0 10481.0 10475.0 10469.5 10465.5 10462.0 10460.0 10458.0 10455.0 10440.5 10434.5 10427.5 10423.0 10413.0 10406.0 100.0 10486.5 10477.0 10473.5 10468.0 10465.0 10458.5 10452.5 10450.5 10444.0 10438.5 10435.5 10431.5 10427.0 10424.0 10415.0 10411.5 10407.5 10405.5 10400.5 10395.0 104.5 REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #4. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #4 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #4 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERVUNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 BSALRST PPK 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RST CU 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RST PU-S 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RST CU 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RST CU 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 SICM RST CU 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RST CU 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RST UA 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 CRRARST 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 TENS RST LB 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 CCL RST V 1209226 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 18 ** DATA ** DEPT. 10719.000 NBAC.RST SFNA.FIL 22.310 SBFA.FIL IRAT. FIL 0.434 CIRN. FIL SIBF. RST 76.179 TPHI.RST SIGM. RST 16.292 DSIG.RST GRCH. RST -999.250 TENS.RST DEPT. SFNA.FIL IRAT. FIL SIBF. RST SIGM. RST GRCH. RST 10060 000 -999 250 -999 250 -999 250 -999 250 35 885 NBAC. RST SBFA. FIL CIRN. FIL TPHI.RST DSIG. RST TENS. RST 2337.375 FBAC.RST 48.760 SFFA.FIL 0.777 CIRF. FIL 36.107 SFFC. RST 3.367 FBEF. RST 1394.000 CCL.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC.RST -999.250 FBEF. RST -999.250 CCL.RST 3115.864 SBNA.FIL 18.557 TR~T. FIL 1.912 BSAL.RST 16.335 SFNC.RST 60.599 CRRA.RST 0.001 -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC.RST -999.250 CRRA.RST -999.250 58.432 0.928 144.779 19.810 2.380 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE · 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS RST 1, 2, 3, 4, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 19 ~S: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF BASE PASSES 1,2, 3 & 4. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 0 66 0 66 0 73 84 66 1 66 73 65 68 0.5 65 FT 66 12 68 66 0 65 FT 66 68 66 1 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD AU]MB SAMP ELEM CODE (HEX) DEPT FT 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC RST CPS 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC RST CPS 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA RSAV CU 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA RSAV CU 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA RSAV CU 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA RSAV CU 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT RSAV 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT RSAV 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNRSAV 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF RSAV 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 BSALRSAV PPK 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF RSAV CU 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI RSAV PU-S 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC RSAV CU 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC RSAV CU 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 20 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) SIGM RSAV CU 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG RSAV CU 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF RSAV UA 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA RSAV 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH RST GAPI 1209226 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10722.500 NBAC.RST 2304.813 FBAC.RST 4952.941 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV -999.250 IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBF. RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF. RSAV -999.250 CRRA.RSAV -999.250 GRCH. RST -999. 250 DEPT. 10283.500 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV -999.250 IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBF. RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF. RSAV -999.250 CRRA.RSAV -999.250 GRCH. RST -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION . O01CO1 DATE ' 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 21 FILE HEADER FILE AUu?4~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH RST 10753,0 $ LOG HEADER DATA 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): STOP DEPTH 10329.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESERVOIR SATURATION $ 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) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 09-FEB-98 8C0-609 1459 09-FEB-98 12300.0 12300.0 10060.0 10716.0 1800.0 TOOL NUMBER CGRS-A RST-A 8.500 12300.0 PRODUCED FLUIDS 9.00 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 22 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) : 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 2 TOOL STANDOFF (IN): REMARKS: Tied into Atlas Static Pressure Survey 2-Feb-95 Minitron was turned on prior to logging, therefore gamma ray was activated on first pass. First two passes logged at 1800 fph Second two passes logged at 3600 fph THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS1 F/HR 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS1 LB 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 23 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) NPHVPS1 V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PSl V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS1 V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 NSCR PSi 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 AQTMPS1 S 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CHV PSi V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CPSV PSi V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PSi V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CM2V PS1 V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 RCFR PSi 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 RCLC PSi 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 RCRC PSI 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 RCAKPS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 FPHVPS1 V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PS1 V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 FSCE PSi V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS1 S 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS1 PSIG 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 HVPV PSi V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 BMCU PS1 UA 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 GDCU PS1 MA 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS1 UA 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 NBEF PSi UA 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PS1 UA 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 NPGF PSi 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 BSPR PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 MARC PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 X~fV PS1 V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 XP5V PS1 V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS1 V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 XM2V PSi V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 RXFR PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 RXLC PSi 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 RY~RC PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 RXAKPS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS1 MA 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL PS1 PPK 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL SIG PPK 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNPS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNFIL 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PS1 CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS1 CPS 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT PSi 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 24 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) NBAC PS1 CPS 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PS1 CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA PS1 CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA PS1 CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA PS1 CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA SIG CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA SIG CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA SIG CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA SIG CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF PSi CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC PS1 CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS1 CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS1 CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF SIG CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM SIG CU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 TP~T SIG 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 RDIX PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS1 KHZ 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS1 tfHZ 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS1 DEGC 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS1 DEGC 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 TAV PS1 KV 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS1 AMP 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CACU PS1 AMP 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 BUST PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS1 PU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS1 V 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 RSCS PS1 1209226 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10730.000 CS.PS1 NPDE. PS1 1552.430 NSCE. PS1 AQTM. PS1 0.661 CHV. PS1 CM2V. PS1 -12.250 RCFR.PSl RCAK. PS1 0.000 RTDF. PS1 FSCE. PS1 2.083 FSCR.PS1 HVPV. PS1 160.627 BMCU. PS1 NBEF. PS1 26.083 FBEF. PS1 1904 469 2 453 202 308 0 000 0 000 0 034 30 845 59 072 TENS. PS1 CRRA. PS1 CPS V. PS1 RCLC. PS1 FPHV. PS1 AQTF. PS1 GDCU. PS1 NPGF. PS1 1425 000 2 265 5 050 0 000 1506 349 1 102 59 801 1 004 NPHV. PSl NSCR. PS1 CP2 V. PS1 RCRC. PS1 FPDE. PS1 SF6P. PS1 EXCU. PSi FPGF. PS1 1562.501 0.073 12.187 0.000 1496.812 120.065 5.242 0.991 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 25 BSTR. PS1 XPSV. PS1 RXLC. PS1 BSAL. PS1 CIRN. FIL IRAT. PS1 SFFA. PS1 SFFA. SIG SFFA. FIL SFNC. PSi SIGM. SIG GR. PS1 CTM. PS1 CACU. PS1 TPHI. PS1 13 068 5 046 0 000 133 916 0 8O4 0 438 18 309 0 355 18 481 19. 268 0.287 60. 564 86. 914 2. 547 35. 416 BSPR. PS1 XP2V. PS1 RXRC. PS1 BSAL. SIG CIRF. FIL IRA T. FIL SBNA. PSl SBNA. SIG SBNA. FIL SFFC. PSi TRAT. PS1 RDIX. PS1 XTM. PSi BUST. PS1 TPHI. SIG DEPT. 10329.000 CS.PS1 NPDE. PS1 1554.414 NSCE. PS1 AQTM. PS1 0.441 CHV. PS1 CM2V. PS1 -12.231 RCFR.PS1 RCAK. PS1 0.000 RTDF. PS1 FSCE. PS1 2.044 FSCR.PS1 HVPV. PS1 160.870 BMCU. PS1 NBEF. PS1 26.331 FBEF. PS1 BSTR.PS1 12.938 BSPR.PS1 XPSV. PS1 5.047 XP2V. PS1 RXLC. PS1 0.000 RXRC.PS1 BSAL.PS1 116.821 BSAL.SIG CIRN. FIL 0.695 CIRF.FIL IRAT. PS1 0.443 IRAT. FIL SFFA.PS1 16.481 SBNA.PS1 SFFA.SIG 0.463 SBNA.SIG SFFA.FIL 17.001 SBNA.FIL SFNC. PS1 18.376 SFFC.PS1 SIGM. SIG 0.264 TRAT. PS1 GR.PS1 9.762 RDIX.PS1 CTM. PS1 87.891 XTM. PS1 CACU. PS1 2.542 BUST.PSi TPHI.PS1 19.579 TPHI.SIG 1.151 12 042 0 000 3 359 2 004 0 437 56 399 4 045 59 929 16. 157 O. 919 61855. 000 86.426 0.000 0.944 1929.682 2.493 202.066 0.000 0.000 -0.132 31.145 56.411 1.083 12.039 0.000 2 444 2 100 0 441 63 699 2 728 60 213 14 984 0.749 72547.000 87.327 0.000 0.667 MARC. PSI JOI2V. PS1 RXAK. PS1 CIRN. PS1 DSIG.PS1 NBAC.PS1 SBFA.PS1 SBFA.SIG SBFA.FIL SIGM. PS1 TRAT. SIG CRNI.PS1 TAV. PS1 BUSP. PS1 CCLC. PS1 TENS. PS1 CRRA. PS1 CPS V. PS1 RCLC. PS1 FPHV. PS1 AQTF. PS1 GDCU. PS1 NPGF. PSi MARC. PS1 2242V. PSi RXAK. PS1 CIRN. PS1 DSIG. PS1 NBAC. PS1 SBFA. PS1 SBFA. SIG SBFA. FIL SIGM. PS1 TRAT. SIG CRNI . PS1 TAV. PS1 BUSP. PS1 CCLC. PS1 0.000 -12 219 1 000 0 789 3 296 2879 858 50 410 4 176 49 938 16 156 0 017 451.753 95.031 0.000 0.000 1518.000 2.142 5.040 0.000 1518.556 0.441 60.113 1.009 0.000 -12.220 0.000 0.684 3.522 2210.874 43.659 6.221 49.079 14.965 0.015 449.192 94.965 0.000 -999.250 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC.PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRA T. FIL CRFI.PS1 FICU. PS1 RSXS.PS1 RSCS.PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC.PS1 FPDE. PS1 SF6P.PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRA T. FIL CRFI. PS1 FICU. PSi RSXS.PS1 RSCS.PS1 200.975 0.000 42.252 2.076 3581.386 22.464 0 617 21 977 71 790 1 348 0 921 199 471 2 343 8878 000 8463 000 1557.618 0.008 12.187 0.000 1497.308 122.421 5.372 0.999 200.966 0.000 44.327 2.164 2938.325 21.141 0.450 21.811 65 004 0 960 0 748 209 668 2 340 8878 000 8459 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 26 **** FILE HEADER **** FILE NA~E : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/26 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: 2 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH RST 10774.5 $ LOG HEADER DATA STOP DEPTH 10333.0 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 ......................... GR GAMMA RAY RST RESERVOIR SATURATION $ 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) : 09-FEB-98 8C0-609 1459 09-FEB-98 12300.0 12300.0 10060.0 10716.0 1800.0 TOOL NUMBER CGRS-A RST-A 8.500 12300.0 PRODUCED FLUIDS 9.00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 27 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 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): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 2 TOOL STANDOFF (IN): REMARKS: Tied into Atlas Static Pressure Survey 2-Feb-95 Minitron was turned on prior to logging, therefore gamma ray was activated on first pass. First two passes logged at 1800 fph Second two passes logged at 3600 fph THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 28 TYPE REPR CODE VALUE 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVU-NIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1209226 O0 000 O0 0 7 1 1 4 CS PS2F/HR 1209226 O0 000 O0 0 7 1 1 4 TENS PS2 LB 1209226 O0 000 O0 0 7 1 1 4 NPHVPS2 V 1209226 O0 000 O0 0 7 1 1 4 NPDE PS2 V 1209226 O0 000 O0 0 7 1 1 4 NSCE PS2 V 1209226 O0 000 O0 0 7 1 1 4 CRRA PS2 1209226 O0 000 O0 0 7 1 1 4 NSCR PS2 1209226 O0 000 O0 0 7 1 1 4 AQTMPS2 S 1209226 O0 000 O0 0 7 1 1 4 CHV PS2 V 1209226 O0 000 O0 0 7 1 1 4 CPSV PS2 V 1209226 O0 000 O0 0 7 1 1 4 CP2V PS2 V 1209226 O0 000 O0 0 7 1 1 4 CM2V PS2 V 1209226 O0 000 O0 0 7 1 1 4 RCFR PS2 1209226 O0 000 O0 0 7 1 1 4 RCLC PS2 1209226 O0 000 O0 0 7 1 1 4 RCRC PS2 1209226 O0 000 O0 0 7 1 1 4 RCAK PS2 1209226 O0 000 O0 0 7 1 1 4 RTDF PS2 1209226 O0 000 O0 0 7 1 1 4 FPHVPS2 V 1209226 O0 000 O0 0 7 1 1 4 FPDE PS2 V 1209226 O0 000 O0 0 7 1 1 4 FSCE PS2 V 1209226 O0 000 O0 0 7 1 1 4 FSCR PS2 1209226 O0 000 O0 0 7 1 1 4 AQTF PS2 S 1209226 O0 000 O0 0 7 1 1 4 SF6P PS2 PSIG 1209226 O0 000 O0 0 7 1 1 4 HVPV PS2 V 1209226 O0 000 O0 0 7 1 1 4 BMCU PS2 UA 1209226 O0 000 O0 0 7 1 1 4 GDCU PS2 MA 1209226 O0 000 O0 0 7 1 1 4 EXCU PS2 UA 1209226 O0 000 O0 0 7 1 1 4 NBEF PS2 UA 1209226 O0 000 O0 0 7 1 1 4 FBEF PS2 UA 1209226 O0 000 O0 0 7 1 1 4 NPGF PS2 1209226 O0 000 O0 0 7 1 1 4 FPGF PS2 1209226 O0 000 O0 0 7 1 1 4 BSTR PS2 1209226 O0 000 O0 0 7 1 1 4 BSPR PS2 1209226 O0 000 O0 0 7 1 1 4 MARC PS2 1209226 O0 000 O0 0 7 1 1 4 ~ PS2 V 1209226 O0 000 O0 0 7 1 1 4 XPSV PS2 V 1209226 O0 000 O0 0 7 1 1 4 XP2V PS2 V 1209226 O0 000 O0 0 7 1 1 4 XM2V PS2 V 1209226 O0 000 O0 0 7 1 1 4 RXFR PS2 1209226 O0 000 O0 0 7 1 1 4 RXLC PS2 1209226 O0 000 O0 0 7 1 1 4 RXRC PS2 1209226 O0 000 O0 0 7 1 1 4 RXAK PS2 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 29 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SHCU PS2 MA 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS2 PPK 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG PPK 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS2 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF PS2 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG PS2 CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS2 CPS 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS2 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 I~BAC PS2 CPS 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS2 CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS2 CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS2 CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS2 CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS2 CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS2 CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS2 CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS2 CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS2 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS2 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS2 K~Z 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS2 K~Z 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS2 DEGC 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS2 DEGC 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 TAV PS2 KV 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS2 AMP 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS2 AMP 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS2 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS2 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 RSXS PS2 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS2 PU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS2 V 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 RSCS PS2 1209226 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 30 ** DATA ** DEPT. NPDE. PS2 AQTM. PS2 CM2V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR.PS2 XP5V. PS2 RXLC. PS2 BSAL.PS2 CIRN. FIL IRAT. PS2 SFFA.PS2 SFFA.SIG SFFA.FIL SFNC. PS2 SIGM. SIG GR.PS2 CTM. PS2 CACU. PS2 TPHI.PS2 DEPT. NPDE. PS2 AQTM. PS2 CM2V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR.PS2 XPSV. PS2 RXLC. PS2 BSAL.PS2 CIRN. FIL IRAT. PS2 SFFA.PS2 SFFA.SIG SFFA.FIL SFNC. PS2 SIGM. SIG GR.PS2 CTM. PS2 CACU. PS2 TPHI.PS2 10730.000 1554.414 1.102 -12.211 0.000 2.031 160.726 26.075 13.535 5.047 0 000 138 325 0 812 0 441 18 638 0 474 18 399 19 638 0 287 61 514 87 891 2 547 38 761 10333 000 1555 253 0 661 -12 211 0 000 2 016 160 941 26.455 12.953 5.044 0.000 119.669 O. 837 0. 458 11. 972 O. 273 12. 025 12.438 0.174 15.359 87.402 2.547 18.433 CS.PS2 NSCE. PS2 CHV. PS2 RCFR.PS2 RTDF. PS2 FSCR.PS2 BMCU. PS2 FBEF. PS2 BSPR.PS2 XP2V. PS2 RXRC.PS2 BSAL.SIG CIRF.FIL IRAT.FIL SBNA.PS2 SBNA.SIG SBNA.FIL SFFC. PS2 TRAT. PS2 RDIX. PS2 XTM. PS2 BUST. PS2 TPHI.SIG CS.PS2 NSCE.PS2 CHV. PS2 RCFR.PS2 RTDF. PS2 FSCR. PS2 BMCU. PS2 FBEF. PS2 BSPR . PS2 XP2V. PS2 RXRC.PS2 BSAL.SIG CIRF.FIL IRAT.FIL SBNA.PS2 SBNA.SIG SBNA.FIL SFFC. PS2 TRAT.PS2 RDIX. PS2 XTM. PS2 BUST. PS2 TPHI.SIG 1911 933 2 513 202 187 0 000 0 000 -0 065 30.879 60 595 1 060 12 045 0 000 2 671 1 915 0 441 62 486 3 285 60 453 16 085 0 951 77560 000 87 337 0 000 1 007 1914.993 2.513 201.823 0.000 0.000 0.035 31.034 56.415 1.114 12.043 0.000 2.355 2.510 0.458 60.817 2.998 63.134 10.076 0.728 88134.000 87.368 0.000 0.553 TENS.PS2 C~.PS2 CPSV. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 X~2V. PS2 RXAK. PS2 CIRN. PS2 DSIG. PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRAT. SIG CRNI. PS2 TA V. PS2 BUSP.PS2 CCLC. PS2 TENS.PS2 CRRA.PS2 CPSV. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 X~I2V. PS2 RXAK. PS2 CIRN. PS2 DSIG.PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRAT. SIG CRNI. PS2 TAV. PS2 BUSP. PS2 CCLC. PS2 1425.000 2.324 5.050 0.000 1513.673 0.661 59.706 0.995 0.000 -12.216 1.000 0.799 3.060 3025.784 52.919 5. 623 50. 102 16. 098 O. 017 451.885 95.022 0.000 -0.001 1530 000 2 133 5 060 0 000 1513 673 0 661 60 129 1 002 0 000 -12.218 0.000 0.858 2.557 2409.969 55.621 4.721 55.305 10.062 0.013 444.856 94.949 0.000 -999.250 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC.PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS.PS2 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P.PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 R~FR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF.SIG TRAT.FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS.PS2 1561.281 0.010 12.187 0.000 1498.109 123.003 5.234 1.000 200.919 0.000 41.517 1.839 3409.190 21.485 0.466 22.105 73.564 1.078 0.956 194.454 2.358 8878.000 8463.000 1562.501 -0.041 12.217 0.000 1499.521 124 122 5 411 1 002 200 941 0 000 44 691 2 447 2945 633 15 012 0 346 15 332 66 125 0 928 0 730 208 605 2 320 8878.000 8463.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 31 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE . FLIC VERSION : O01CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH RST 10754.5 $ LOG HEADER DATA STOP DEPTH .......... 10228.0 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 GR GARff4A RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 09-FEB-98 8C0-609 1459 09-FEB-98 12300.0 12300.0 10060.0 10716.0 3600.0 TOOL NUMBER CGRS-A RST-A 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 32 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 12300.0 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 (DEG) : PRODUCED FLUIDS 9.00 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 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): 0 FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 2 TOOL STANDOFF (IN): REMARKS: Tied into Atlas Static Pressure Survey 2-Feb-95 Minitron was turned on prior to logging, therefore gamma ray was activated on first pass. First two passes logged at 1800 fph Second two passes logged at 3600 fph THIS FILE CONTAINS THERAW DATA FOR BASE PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 33 TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CS PS3F/HR 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 NPHVPS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 NPDE PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 NSCE PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CRRA PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 NSCR PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 AQTMPS3 S 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CHV PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CP5V PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CP2V PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CM2V PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 RCFR PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 RCLC PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 RCRC PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 RCAKPS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 RTDF PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 FPHVPS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 FPDE PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 FSCE PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 FSCR PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 AQTF PS3 S 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SF6P PS3 PSIG 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 HVPV PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 BMCU PS3 UA 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 GDCU PS3 MA 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 EXCU PS3 UA 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 NBEF PS3 UA 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 FBEF PS3 UA 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 NPGF PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 FPGF PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 BSTR PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 34 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) BSPR PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 MARC PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 X~V PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 XPSV PS3 V 1209226 O0 000 O0 0 8 ! 1 4 68 0000000000 XP2V PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 X~2V PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 RXFR PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 RXLC PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 RXRC PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 RXAKPS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SHCU PS3 MA 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL PS3 PPK 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL SIG PPK 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNPS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNFIL 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF FIL 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 DSIG PS3 CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS3 CPS 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT FIL 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 NBAC PS3 CPS 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA PS3 CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA PS3 CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA PS3 CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA PS3 CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA SIG CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA SIG CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA SIG CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA SIG CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA FIL CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA FIL CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA FIL CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA FIL CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF PS3 CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SFNC PS3 CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SFFC PS3 CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS3 CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF SIG CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM SIG CU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT SIG 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 TROT FIL 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 RDIX PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CRNI PS3 K~Z 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CRFI PS3 K~Z 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CTM PS3 DEGC 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 XTM PS3 DEGC 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 TAV PS3 KV 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 FICU PS3 AMP 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 35 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) CACU PS3 AMP 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 BUST PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 BUSP PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 RSXS PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS3 PU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI SIG PU 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 CCLC PS3 V 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 RSCS PS3 1209226 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 10730.000 CS.PS3 3594.090 TENS.PS3 1447.000 NPHV. PS3 NPDE. PS3 1554.986 NSCE. PS3 2.519 CRRA.PS3 2.389 NSCR.PS3 AQTM. PS3 0.661 CHV. PS3 201.823 CPSV. PS3 5.069 CP2V. PS3 CM2V. PS3 -12.093 RCFR.PS3 0.000 RCLC. PS3 0.000 RCRC. PS3 RCAK. PS3 0.000 RTDF.PS3 0.000 FPHV. PS3 1516.114 FPDE. PS3 FSCE. PS3 2.014 FSCR.PS3 0.030 AQTF. PS3 0.661 SF6P. PS3 HVPV. PS3 160.797 BMCU. PS3 30.102 GDCU. PS3 59.848 EXCU. PS3 NBEF. PS3 24.710 FBEF. PS3 59.039 NPGF. PS3 0.998 FPGF. PS3 BSTR.PS3 13.455 BSPR.PS3 1.096 MARC. PS3 0.000 XHV. PS3 XPSV. PS3 5.047 XP2V. PS3 12.050 ~2V. PS3 -12.226 RXFR.PS3 RXLC. PS3 0.000 RXRC. PS3 0.000 RXAK. PS3 0.000 SHCU. PS3 BSAL.PS3 138.857 BSAL.SIG 3.728 CIRN. PS3 0.707 CIRF. PS3 CIRN. FIL 0.715 CIRF. FIL 1.942 DSIG.PS3 3.227 FBAC. PS3 IRAT. PS3 0.411 IRAT. FIL 0.411 NBAC. PS3 2584.240 SFNA.PS3 SFFA.PS3 18.334 SBNA.PS3 66.211 SBFA.PS3 60.146 SFNA.SIG SFFA.SIG 0.477 SBNA.SIG 4.194 SBFA.SIG 5.585 SFNA.FIL SFFA.FIL 18.191 SBNA.FIL 67.171 SBFA.FIL 58.961 SIBF. PS3 SFNC. PS3 19.932 SFFC.PS3 16.028 SIGM. PS3 16.005 SIBF. SIG SIGM. SIG 0.343 TRAT. PS3 0.894 TRAT. SIG 0.021 TRAT. FIL GR.PS3 114.398 RDIX. PS3 91327.000 CRNI.PS3 455.911 CRFI.PS3 CTM. PS3 89.356 XTM. PS3 87.402 TAV. PS3 94.978 FICU. PS3 CACU. PS3 2.549 BUST. PS3 0.000 BUSP.PS3 0.000 RSXS.PS3 TPHI.PS3 31.800 TPHI.SIG 1.114 CCLC.PS3 0.000 RSCS. PS3 DEPT. 10228.000 CS.PS3 NPDE.PS3 1556.512 NSCE. PS3 AQTM. PS3 0.661 CHV. PS3 CM2V. PS3 -12.231 RCFR.PS3 RCAK. PS3 0.000 RTDF. PS3 FSCE. PS3 2.017 FSCR.PS3 HVPV. PS3 160.889 BMCU. PS3 NBEF. PS3 26.012 FBEF. PS3 BSTR.PS3 12.298 BSPR.PS3 XPSV. PS3 5.047 XP2V. PS3 RXLC. PS3 0.000 RX~C. PS3 BSAL.PS3 137.016 BSAL.SIG CIRN. FIL 0.828 CIRF.FIL IRAT. PS3 0.437 IRAT. FIL 3684.172 2 522 201 581 0 000 0 000 -0 064 30 510 61 355 1 143 12.041 0.000 3.026 2.597 0.440 TENS.PS3 CRRA.PS3 CPSV. PS3 RCLC. PS3 FPHV. PS3 AQTF. PS3 GDCU. PS3 NPGF. PS3 MARC. PS3 ~2V. PS3 RXAK. PS3 CIRN. PS3 DSIG.PS3 NBAC. PS3 1559 000 2 359 5 069 0 000 1508 790 0 661 59 637 0.998 0.000 -12.233 0.000 0.824 2.057 2336.050 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC. PS3 FPDE. PS3 SF6P. PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 1562 501 -0 091 12 187 0 000 1500 245 124 296 5.869 1.000 201.006 0.000 43.332 1.926 3492.933 23.285 0.668 22.717 73. 778 1. 505 O. 883 190.813 2.309 8878.000 8463.000 1562.501 -0.070 12.231 0.000 1500 207 124 743 5 580 0 997 200 958 0 000 44 784 2 679 2990 668 16 835 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 36 SFFA. PS3 SFFA.SIG SFFA.FIL SFNC. PS3 SIGM. SIG GR.PS3 CTM. PS3 CACU. PS3 TPHI.PS3 13 972 0 287 14 163 13 943 0 232 12 760 87. 402 2. 554 18. 078 SBNA.PS3 67.071 SBFA.PS3 SBNA.SIG 4.962 SBFA.SIG SBNA.FIL 66.822 SBFA.FIL SFFC. PS3 12.318 SIGM. PS3 TRAT. PS3 0.725 TRAT. SIG RDIX. PS3 98440.000 CRNI.PS3 XTM. PS3 87.402 TAV. PS3 BUST. PS3 0.000 BUSP. PS3 TPHI.SIG 0.683 CCLC. PS3 42.955 SFNA.SIG 4.721 SFNA.FIL 49.888 SIBF. PS3 12 316 SIBF. SIG 0 016 TRAT. FIL 437 558 CRFI.PS3 94 929 FICU. PS3 0 000 RSXS.PS3 -999 250 RSCS.PS3 0.581 16.722 73.036 1.219 0.720 185.509 2.357 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : 0 O1 CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SU~J~RY VENDOR TOOL CODE START DEPTH ........................... RST 10768.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): STOP DEPTH 10010.5 09-FEB-98 8C0-609 1459 09-FEB-98 12300.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 37 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 ......................... GR GA~ff~A RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12300.0 10060.0 10716.0 3600.0 TOOL NUMBER ........... CGRS -A RST-A 8.500 12300.0 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 (DEG) : PRODUCED FLUIDS 9.00 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 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): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 2 TOOL STANDOFF (IN): REMARKS: Tied into Atlas Static Pressure Survey 2-Feb-95 Minitron was turned on prior to logging, therefore gamma ray was activated on first pass. First two passes logged at 1800 fph Second two passes logged at 3600 fph THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #4. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 38 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 8 9 11 12 13 14 15 16 0 0.5 FT 2 65 68 65 66 68 66 0 65 FT 66 68 66 1 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 CS PS4 F/HR 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS4 LB 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 NPHVPS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 NPDE PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 NSCE PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 CRRA PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 NSCR PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 AQTMPS4 S 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 CHV PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 CPSV PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 CP2V PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 CM2V PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 RCFR PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 RCLC PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 RCRC PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 RCAKPS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 RTDF PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 FPHVPS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 FPDE PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 FSCE PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 39 NA~IE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NOMB SAMP ELEM CODE (HEX) FSCR PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 AQTF PS4 S 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SF6P PS4 PSIG 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 HVPV PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 BMCU PS4 UA 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 GDCU PS4 MA 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 EXCU PS4 UA 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 NBEF PS4 UA 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 FBEF PS4 UA 1209226 O0 000 O0 0 9 I 1 4 68 0000000000 NPGF PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 FPGF PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 BSTR PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 BSPR PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 MARC PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 XHV PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 XPSV PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 XP2V PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 X~I2V PS4 V 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 RXFR PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 RXLC PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 RXRC PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 RXAKPS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SHCU PS4 MA 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL PS4 PPK 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL SIG PPK 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNPS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNFIL 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF FIL 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 DSIG PS4 CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS4 CPS 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT FIL 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 NBAC PS4 CPS 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA PS4 CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA PS4 CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA PS4 CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA PS4 CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA SIG CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA SIG CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA SIG CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA SIG CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA FIL CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA FIL CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA FIL CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA FIL CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF PS4 CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SFNC PS4 CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SFFC PS4 CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS4 CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF SIG CU 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 40 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) SIGM SIG CU 1209226 O0 000 O0 0 9 1 1 4 TRAT PS4 1209226 O0 000 O0 0 9 1 1 4 TRAT SIG 1209226 O0 000 O0 0 9 1 1 4 TRAT FIL 1209226 O0 000 O0 0 9 1 1 4 GR PS4 GAPI 1209226 O0 000 O0 0 9 1 1 4 RDIX PS4 1209226 O0 000 O0 0 9 1 1 4 CRNI PS4 ICqZ 1209226 O0 000 O0 0 9 1 1 4 CRFI PS4 ICqZ 1209226 O0 000 O0 0 9 1 1 4 CTM PS4 DEGC 1209226 O0 000 O0 0 9 1 1 4 XTM PS4 DEGC 1209226 O0 000 O0 0 9 1 1 4 TAV PS4 KV 1209226 O0 000 O0 0 9 1 1 4 FICU PS4 AMP 1209226 O0 000 O0 0 9 1 1 4 CACU PS4 AMP 1209226 O0 000 O0 0 9 1 1 4 BUST PS4 1209226 O0 000 O0 0 9 1 1 4 BUSP PS4 1209226 O0 000 O0 0 9 1 1 4 RSXS PS4 1209226 O0 000 O0 0 9 1 1 4 TPHI PS4 PU 1209226 O0 000 O0 0 9 1 1 4 TPHI SIG PU 1209226 O0 000 O0 0 9 1 1 4 CCLC PS4 V 1209226 O0 000 O0 0 9 1 1 4 RSCS PS4 1209226 O0 000 O0 0 9 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. NPDE.PS4 AQTM. PS4 CM2V. PS4 RCAK. PS4 FSCE. PS4 HVPV. PS4 NBEF. PS4 BSTR.PS4 XP5V. PS4 RXLC.PS4 BSAL.PS4 CIRN. FIL IRAT.PS4 SFFA.PS4 SFFA.SIG SFFA.FIL SFNC. PS4 SIGM. SIG GR.PS4 CTM. PS4 CACU. PS4 TPHI.PS4 10730.000 CS.PS4 1555.063 NSCE.PS4 0.661 CHV. PS4 -12.211 RCFR.PS4 0.000 RTDF. PS4 2.014 FSCR.PS4 161.098 BMCU. PS4 26.160 FBEF. PS4 12.336 BSPR.PS4 5.041 XP2V. PS4 0.000 RXRC. PS4 133.591 BSAL.SIG 0.791 CIRF. FIL 0.437 IRAT. FIL 17.320 SBNA.PS4 0.533 SBNA.SIG 17.641 SBNA.FIL 20 058 SFFC. PS4 0 348 TRAT. PS4 87 87 2 38 3600.096 TENS.PS4 2 529 CRRA.PS4 201 581 CP5V. PS4 0 000 RCLC.PS4 0 000 FPHV. PS4 0 007 AQTF.PS4 31 096 GDCU. PS4 58.825 NPGF. PS4 1.055 MARC.PS4 12.035 XM2V. PS4 0.000 RXAK. PS4 3.144 CIRN. PS4 1.903 DSIG.PS4 0.438 NBAC.PS4 56.419 SBFA.PS4 3.958 SBFA.SIG 59.297 SBFA.FIL 15.373 SIGM. PS4 0.955 TRAT. SIG 707 RDIX. PS4 102173 . 000 CRNI. PS4 402 XTM. PS4 87. 542 TAV. PS4 548 BUST. PS4 O. 000 BUSP. PS4 477 TPHI.SIG 1.267 CCLC. PS4 1392 000 NPHV. PS4 2 249 NSCR.PS4 5 079 CP2V. PS4 0 000 RCRC. PS4 1506 349 FPDE. PS4 0 441 SF6P. PS4 60.527 EXCU. PS4 1.001 FPGF. PS4 0.000 XHV. PS4 -12.217 EXFR.PS4 0.000 SHCU. PS4 0.792 CIRF. PS4 3.037 FBAC. PS4 2877.482 SFNA.PS4 39.733 SFNA.SIG 6.863 SFNA.FIL 44.877 SIBF. PS4 15.260 SIBF. SIG 0.022 TRAT. FIL 446.177 CRFI.PS4 95.072 FICU. PS4 0.000 RSXS.PS4 0.001 RSCS.PS4 1562.501 -0.108 12.231 0.000 1499 826 124 816 5 354 1 002 200 923 0 000 42 694 1 952 3480.392 23.712 0.640 22.678 71.659 1.261 0.953 198.414 2.291 8878.000 8463.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 41 DEPT. NPDE. PS4 AQTM. PS4 CM2 V. PS4 RCAK. PS4 FSCE. PS4 HVPV. PS4 NBEF. PS4 BSTR . PS4 XPSV. PS4 RXLC. PS4 BSAL. PS4 CIRN. FIL IRAT. PS4 SFFA. PS4 SFFA. SIG SFFA. FIL SFNC. PS4 SIGM. SIG GR. PS4 CTM. PS4 CACU. PS4 TPHI. PS4 10010 500 1555 749 0 661 -12 172 0 000 2 037 161. 133 26.578 13. 634 5. 047 O. 000 161. 234 O. 350 O. 418 36. 008 1. 657 37. 606 40. 564 1.200 20. 121 87. 402 2. 558 54. 140 CS.PS4 NSCE.PS4 CHV. PS4 RCFR.PS4 RTDF. PS4 FSCR.PS4 BMCU. PS4 FBEF. PS4 BSPR.PS4 XP2V. PS4 RXRC. PS4 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS4 SBNA.SIG SBNA.FIL SFFC. PS4 TRAT. PS4 RDIX. PS4 XTM. PS4 BUST. PS4 TPHI.SIG 3626.399 2 519 201 823 0 000 0 000 -0 052 31 054 60 683 1.186 12.035 0.000 3.022 0.679 0.415 68.014 4.052 69.876 33.819 1.253 112708.000 87.472 0.000 3.663 TENS.PS4 CRRA.PS4 CPSV. PS4 RCLC. PS4 FPHV. PS4 AQTF. PS4 GDCU. PS4 NPGF. PS4 MARC. PS4 X~I2V. PS4 RXAK. PS4 CIRN. PS4 DSIG.PS4 NBAC.PS4 SBFA.PS4 SBFA.SIG SBFA.FIL SIGM. PS4 TRAT. SIG CRNI.PS4 TAV. PS4 BUSP.PS4 CCLC.PS4 1429.000 2.283 5.060 0.000 1506.349 0 661 59 496 1 003 0 000 -12 225 0 000 0.375 4.452 2222.816 59.063 5.593 61.434 33.950 0.051 444.613 94.949 0.000 -999.250 NPHV. PS4 NSCR.PS4 CP2V. PS4 RCRC.PS4 FPDE. PS4 SF6P.PS4 EXCU. PS4 FPGF. PS4 XHV. PS4 RXFR.PS4 SHCU. PS4 CIRF. PS4 FBAC. PS4 SFNA.PS4 SFNA.SIG SFNA.FIL SIBF. PS4 SIBF. SIG TRAT. FIL CRFI.PS4 FICU. PS4 RSXS.PS4 RSCS.PS4 1562.501 0.022 12.173 0.000 1499.024 125 255 5 354 1 001 201 027 0 000 46 689 0 654 3032.591 41.553 1.510 43.745 82.949 1.258 1. 265 194. 734 2. 352 8878.OOO 8459.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NASIE : EDIT DATE : 98/06/26 ORIGIN : FLIC TAPE NAME : 98293 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT ' BP EXPLORATION, F-17A, PRUDHOE BAY, API# 50-029-20652-01 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-JUN-1998 16:05 PAGE: 42 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 98/06/26 ORIGIN · FLIC REEL NAME : 98293 CONTINUATION # : PREVIOUS REEL : CO~k~ENT : BP EXPLORATION, F-17A, PRUDHOE BAY, API # 50-029-20652-01 _ subfile 2 is type: LIS TAPE HEADER PRUDHOE BaY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 6578.00 R. FRENCH G. BECK F-17A 500292065201 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 09-FEB-96 MWD RUN 3 R. FRENCH G. BECK MWD RUN 4 R. FRENCH G. BECK MWD RUN 5 JOB NI/MBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: R. FRENCH G. BECK MWD RUN 6 R. FRENCH G. BECK MWD RUN 7 R. FRENCH G. BECK 2 liN 13E 2214 2197 65.98 64.58 38.19 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8478.0 8.500 7.000 10812.0 6.000 12300.0 MWD - GR/EWR4 ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. MWD RUNS 2, 3, 4 & 5 ARE DIRECTIONAL WITH GAMMA R3~Y (NGP) . MWD RUNS 6 & 7 ARE SLIMHOLE DIRECTIONAL WITH GAMMA RAY (NGP) AND SLIMHOLE DUAL GAMMA RAY (DGR) WITH ELECTROMAGNETIC WAVE RESISTIVITY PHASE - 4 (EWR4) . THERE IS ALSO A MAD PASS CONTAINING DUAL GAMMA RAY (DGR) WITH ELECTROMAGNETIC WAVE RESISTIVITY PHASE - 4 (EWR4) DATA FROM 10792' MD TO 11659' MD. GAMMA RAY IS FROM TWO DIFFERENT PROBES: 9879.00' MD - 10611.50' MD SGRD FROM "NGP" PROBE 10612.00' MD - 12186.00' MD SGRC FROM "DGR" PROBE 12186.50' MD - 12246.50' MD SGRD FROM "NGP" PROBE NO DEPTH SHIFTING WAS DONE SINCE THIS IS THE DEPTH REFERENCE FOR THIS WELL. ~mE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 9879.0 10619.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: STOP DEPTH 12247.0 12193.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 9944.0 10343.0 10343.0 10501.0 10501.0 10641.0 10641.0 10812.0 10812.0 11667.0 11667.0 12300.0 MERGED MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : F-17A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI RPX MWD 68 1 OHMM RPS MWD 68 1 OHMM RPM MWD 68 1 OHMM RPD MWD 68 1 OHMM FET MWD 68 1 HR ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 s~Aq 866 s~Aq ~9 :M~Bu~I p~om~ mnmTx~M :M~Bu~I p~om~ mnmyuyM E :~Iy~qns smn~p £LL8£ 89 :~poD dsH :A~mmns 5uypom~p spom uoy~u~s~ds~ $Iq O0000S'O = 5UToeds IS~% aIT~ adeL 000000'8A86 = q~dsG puz ~IT~ ~d~i O00000'IO£EI = q~ds~ ~e~S ~IT~ sdeL 8~ tSI :sp~oosH ~q~ ImqOi 00000S'0 = 6u~DPds TSA~ ~T~ 000000'06£0I = q~ds~ pu~ ~I~Z sdPi 000000'§99II = u~d@Q ~S ~T~ ~ S,WLXS 866 ( 0 #,WdX,I,) ~MODZ~ %f,T,lf~ ~ 8~ 66 966 ~6 P 66 966 ~6 P 66 ~66 96 P 66 S66 ~6 P 66 ~66 ~6 P 66 ~66 ~6 P 66 ~66 96 f poM sIO ctX£ ctXi q~Bu~ szys s~!u~ ssIdmms spoD IOOi Sm~N :ssA~nD L ~ :GI q~d~p 0'6S9II IDMS~ : ZdO~IS H,T,%ION : Xlf~ ZOHGi1Hd : tfLI -A : (¥MSIfT~) NOI,T,tfHO~IdXZ d~t : 0'£I60I I 9 dO£ Z©HZM 'ON SS~d (ItfM 'OM NflH Q-fM 0'LSSII 0'6PSII H£dZ~ dO£S 0'66L01 0'~6LOI HLdZJ LYtfLS NDOD NM MD :SM~ZM M~OD ~ooL asa Z~OD ~OOi n~d 000S' :LNZMZHDNI HLdZQ 'ssssmd qSSTI~S Bumsn ps6~sm sun~ GtfN IIe ts~A~no p~ddTiO pue psq~TqS qqd~G SI% :sclXq sT £ SiT~qns ~ S$~Xq 866 :q~BU~I p~oo~ mnmyx~M ss~Xq E9 :q~Bu~I p~oos~ mnmyuIM smn~ep 600~I 89 :spoo d~H :X~mmns BuTPOm~p ~pom UOTq~qu~s~d~ ~e Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NGP 9879.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIM UMANGLE: STOP DEPTH 10278.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 2. 02-JAN-95 MSC 1.32 PCDWD 1.16 NGP 5.41 DEP 2.041 MEMORY 10343.0 9944.0 10343.0 0 16.5 23 .2 TOOL NUMBER NGP 69 8.500 8478.0 KCL BIOPOLYMER 10.20 .0 10.4 30000 .0 .000 .0 .000 158.5 .O00 .0 .000 .0 .00 .000 .0 0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : F-17A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 12 Tape File Start Depth = 10367.000000 Tape File End Depth = 9878.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 41715 datums Tape Subfile: 4 75 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes 0 0' : (ZH) XON.~i"J.b~'~I,ff ~Lvt_,";r : (NI) ,4,40CINrtf,T,S qO0,T, 000 ' 00' : (NI) NOIIOZHHOD ZqOH :XIISNZG qOOi NOHI~ZN 0' 000' 0' 000' 6'fiPI 000' 0' 000' ~'S 0000£ 8'6 0'09 0I'0I 0'8£58 OOfi'8 : (i,~) HId,~G DNIS~fD S : (NI) ,~ZIS iI~ ,~IOH N,qdO 69 d©N E~NDN ~OOi Z~O%Id ~D ~i%fN dON ZdXi ~O0i ZfIOD ~IOOi %tO~N,~A (N0ii0~ Oi dOi) DNI%~iS ~I00i fi'8£ 8'~ 0 0'I0fi0I 0'£££0I 0'I0fi0I I~0'g dZQ I~'fi dUN 9I'T ~M~Dd E£'I DSM fi6-N-~f~-50 0'I~0I :Z~©Ntf WflNIXtfH (OZ~) NOII~NI~DNI Z~OH : (Nde) ~ZZdS ©NIi~iO~ LIE : (i~) qtfA~ZLNI ©0~ : (i~) ~A~ZLNI ©0~ dOi :NOISHZA Z~MI~0S Z~ML~OS :GZDDO~ 0'CL[0I dOM X~S ZqIS 000S' :~NZ~Z~DNI SIT :sd. Xq CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : F-17A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 6 Tape File Start Depth = 10505.000000 Tape File End Depth = 10270.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15423 datums Tape Subfile: 5 69 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes ~e Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NGP 10442.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10581.0 04-JAN-95 MSC 1.32 PCDWD 1.16 NGP 5.41 DEP 2.041 MEMORY 10641.0 10501.0 10641.0 0 42.6 58.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 168 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8478.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL B IOPOLYMER 10.10 60.0 9.8 30000 5.4 .000 .0 .000 145.9 .000 .0 .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 4. ss~Xq ~IOI :q~BusI p~oss~ mnm~x~M ss~Xq E9 :q~Bu~I p~oos~ mnmTuTM '''sp~oo~ 89 9 :~I~qns smn~mp 6~6~5 89 :~poD :~mmns 5u~poo~p ~poo uo~u~s~d~ SI~ 00000~'0 = 6uTo~dS I~A~ ~IT~ 000000'0~0I = q2d~ puZ sI~f 000000'~90I = q2d~ 2~2S sI~ I0 018 06 ~ I0 0I£ 06 ~ ~ EHd~ I 89 GMM dOE E ~ IdYll I 89 GM~ E© I SqTUD ssIdmes @pod IOOL smeM :ssA~nD E ~ :GI q~d~p (~9 #ZdXi) GHODZH i~O~ ~ YZS~ : ZdO~IS H,T,HON : X%fS ZOH(Ifl%td : ~f/.I -,~ : (%f'~S~f~I%f) NOI,T,¥~O~dXZ dS : NnOD NM ND 0 0' 000 ' 00' 0' 000' 0' 000' 6'S~I 000' 0' 000' 9'S 000E£ 6'6 0'£9 0I'0I ~A~O~OI~ 0'8L~8 00S'8 69 d©N ~'~8 9'09 0 0'EISOI 0'T~90I 0'EI80I 9T'T ~M~Dd g£'T DSH ~6 -N-~£- S 0 : (NI) .~.~O~NIf. T.S qO0,1. : (NI) NOIID~OD ~qOH :XI~i~fN qOOi : (NI) ~ZIS &IS ~%OH ~i~ ©NIS~D ~N-~ ~qOH~O~ ZdX,l. qO0£ ,'q'(/OD qO0,I, %tOGNZA (NOL£O~t OJ. dO£) ©NI%ILS qOO,l. 0 ' 9~LOI SIq :ecl/iq sT £ eil~qns p~ ss~Aq 5IOI :q~BusI p~oss~ mnmTx~M s~Aq E9 :q~BusI p~oo~ mnm~uTM · ''SpXOO~l 69 L :~ITgqns sd~£ smn~mp £E69I 89 :spoD d~H :X~mmns 5u~poo~p ~poo uo~u~s~d~ SI~ 00000~'0 = 6uTo~dS T~A~q ~TT~ 000000'~9~0I = qqd~ pu~ ~I7~ 000000'~ISOI = q2d~ ~e2S ~IT~ 9 :sp~oos~ m~m~ I~Oi ~ SZLX~ ~IOI (0 #ZdXi) ~ODZ~ ~i~ ~ I0 018 06 ~ I0 0I£ 06 5 ~ ~Hd~ I 89 ~MM dO~ E ~ IdYll I 89 ~MM ~© I poM sIO ctXL clXi q~6usq szTs A~D A~D 6o% s~Tu~ ssidmeS ~poo IOOL sm~N :s~A~no ~ ~ :GI q~dsp ~M Sk~f~ : ZdO~S HLHON : X~fS ,WOHgfl%Id : %f£I -,4 : (¥MS~fq~f) NOILYHOTdXZ d~{ : ND ~ Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RJkW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 10612.0 EWR4 10619.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11553.0 11560.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 10-JAN-95 MSC 1.32 PCDWD 1.16 NGP 5.41 DEP 2.041 MEMORY 11667.0 10812.0 11667.0 0 89.4 94.9 TOOL NUMBER 6.000 10812.0 KCL FLO PRO 9.00 53.0 10.9 42000 6.0 .000 .000 .000 .000 .0 154.4 .0 .0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 6. $ : BP EXPLORATION (ALASKA) : F-17A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 69 Tape File Start Depth = 11670.000000 Tape File End Depth = 10610.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 59918 datums Tape Subfile: 8 134 records... Minimum record length: Maximum record length: 62 bytes 998 bytes 000 ' 00' : (NI) NOIIDZMMOD ZqOH qOOi NOMIfl~N o O' S' O' 000 ' 000 ' 000 ' 000 ' I'9 000£P 6'6 0'£S 0I'6 OMd 0%,~ ~ID)t : (ED) SSO~ ~I~ : (Mdd) SZGIMO%HD ClflN :Hd G£1N : (S) XZISODSIA Grin :(D/ST) XIISMSG Gn~ SMOILIGMOD Z%OHZMOS 0'EISOI 000'9 : (Id) HidZCI ©bIISVD S ,MZ%%IMG : (MI) ZZIS lilt Z%OH M,qdO VLVG ©MI SVD CLNVf Z%OHZMO~ 69 dOM P 'SISZM 'DIfI4OMLDZ~Z PMJ4Z Xtf%I~D q~f~G MDG (NOiiO~ Oi dOi) DNI~IS ~OOi E'I6 S'88 0 0'00£gI 0'£99II 0'00£~I IP0'E dig IP'9 dON 9I'I ~MGDd ~£'I DSM S6-NVD-II SIT :~ctK; sy 6 ~IY~qns ~ s@~Xq ~IOI :~Bu@I pxoo@~ mnm!x~M s~Xq E9 :~Bu~I pzoo~z mnm!u!M · ''spxoo~x £gI 6 :@II~qns smn~p SSPOE 89 :~poo d~ :A~mmns Bu!poo~p ~poo uoi~u~s~d~ SI~ ~ = s~u~ q~d~ ~I~ 00000~'0 = 6u~o~ds I~A~ ~I7~ 000000'0SSII = q2dsG pu~ sI7~ 000000'I0£gI = q~d~ ~P~S ~T7~ I0 0IE 06 P I0 018 06 P I0 08I 06 P 99 0gI 06 P 9P 0~I 06 P 9P 0gI 06 P 9~ 0gI 06 ~ I0 0I£ 06 P poM sIO clKL dXL q~6us% ~zTS s~yu~ ssIdmes spoo IOOi :ssA~nD 8 ~ :~I q~d~p ~dei (P9 #ZdXi) ~MODZ~ £~k~O~ ~ ~QIS~ : ZdO~IS Hi%ION : X~f~t ZOHCKI%Id : %ftI -M : (~S~I~f) NOIi¥~O~IdXZ dE : NflOO NM 0 0' : (NI) ~OQN~fLS ~ 0 ' : (NZ) ,_-.4,40GNTy'£S '-ZOO;f, 000 ' 00' . 0' ~' 0' 000 ' 000 ' 000 ' 000 ' 0'9 000g~ 6'0I 0'£S 00'6 O~I,~ ~ID)t 0'EISOI 000'9 6'~'6 ~"68 0 0'6S9II 0'~6LOI 0'L99TI I~0'E dZG IT'S d©N 9T'T GMGDd g£'T DSM S6-N-%f~-0I (,4S2G) ,~LFI,T&FaIZdN2,T, ,Tar (NNH0) A,T, IAI,T, SIS2~ : (SD) SSOq aInq,~ : (Ndd) S,~GI%IO~IHD GflM : Hd GflN : (S) A,T, ISODSIA GDN : ,~dX,l, SNOI,T,I(INOD : (MI) HZIS ,T,I~{ ,q~IOH ~T,T,~TG ©MIS%rD GNtf ~IOH,~HO~t ~ ' S I SZ%t ' O~40%tLDZ~I,g ZdX,T, ~IO0,T, Z(IOD ~iO0,T, (MOLLO~ O,T, dO,T,) ©NI%~LS ~IO0,T, 0'65SIT 'SSiTJ ~q~z[~d~s uT un~ qow~ ~o ss~d qoe~ a:oj ~qep :~spesq BoI pue ss~no 6 : %~Z~{N/]/~ Z~I I.~ %fZCr~ZH Z~IId SIq :~d. Xq sT 0I eITJqns ~d~ ss~Xq 866 :q~BusI pzomsz mnmix~ :q~Bu~I pxom~z mnmiu!~ OI :sIT~qns ~deL smn~p L[6£L 89 :spoD dsm :X~mmns 6uipoo~p ~pom uoi~u~s~ds~ O0000S'O = BuToPdS I~A@~ SIT~ 000000'06£0I = q~d~Q puz ~IT~ @del 000000'S99II = q~d~ ~S ~ITZ I0 018 S6 P I0 08I S6 P 9~ 0EI S6 P 9P 0EI S6 P 9P 0EI S6 P 9P 0gI S6 P TO 0I£ 56 P po~ sIO cIXi clK£ q~Bus% SZTS s~Tu~ SeTdmeS ~poo TOOL amen :S~A~nD £ ~ :~I q~dsp YZ S~I~f : ZdO~IS H.I,%ION : X~f~ ZOHfIfl%Id : %fAI -,q : (~F~{S~fq%f) MOI,I,~OqdXZ dS : MD_OD NM ND 0 : (ZH) XONZfl0ZM~ ' _~e Subfile 11 is type: LIS 96/ 2/ 8 01 **** REEL TRAILER **** 96/ 2/13 01 Tape Subfile: 11 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 13 FEB 96 ll:07a Elapsed execution time = 2.36 seconds. SYSTEM RETURN CODE = 0