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195-152
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: scanned by: Bevedy Dian~athan Lowell Is/ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ or ahp 4,i&\ THE STATE g k aska G and:. Gas of t Witt — - — 333 West Seventh Avenue \ ' G 0 V):��N`/U1-- i AA k1\11 f' Anchorage, Alaska 99501-3572 v t Main: 907 279 1433 AA.EAP ax 907.275.7542 � John McMullen Engineering Team Leader I a5 I BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06-03A Sundry Number: 314-173 Dear Mr. Bjork: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, , Daniel T. Seamount, Jr. Commissioner DATED this SS day of March, 2014. Encl. `' STATE OF ALASKA i L ` • ALASKA OIL AND GAS CONSERVATION COMMISSION ,,;1 ,k 18 2.0i- APPLICATION . i-i APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 A00 1. Type of Request: ❑Abandon ®Plug for Redrill • 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 195-152 3. Address: o Exploratory 0 Stratigraphic Alaska 99519 6612 ®Development 0 Service P.O. Box 196612,Anchorage, 6. API Number: 50.029-20186-01-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 06-03A - Will planned perforations require a Spacing Exception? ❑Yes ® No 9. Property Designatior 10.Field/Pool(s): ADL 028311 • Prudhoe Bay Field/Prudhoe Bay Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11155' • 9058' - 11091' 9043' 10659', 10749' Unknown(2) Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1530 520 Surface 2730' 13-3/8" 2730' 2730' 5380 2670 Intermediate Production 10480' 9-5/8" . 10480' 8888' 6870/8150 4760/5080 Liner 1333' 3-1/2" 9822'- 11155' 8342'-9058' 10160 10530 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10617'-11070' 8979'-9040' 5-1/2", 17# 13Cr80/L-80 9890' Packers and SSSV Type: 9-5/8"x 5-1/2" Baker S-3 Packer Packers and SSSV 9668'/8213' 9-5/8"x 5-1/2"Baker S-3 Packer MD(ft)and TVD(ft): 9807'/8329' 12. Attachments: 13.Well Class after proposed work: - ®Description Summary of Proposal ®BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic ®Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation. April 1, 2014 ❑Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended 17. I hereby certify that the foregoin• is true nd correct to the best of my knowledge. Contact: Travis Boltz,564-5750 Printed Name: Jo/Mn/ Title: Engineering Team Leader E ail:/Travis.Boltz@bp.com 4 Signature: r Phone: 564-4711 Date: 3 iy(ail/ Commission Use Only Condition- •f approval: Notify Commission so that a representative may witness Sundry Number: i V--t. \1'6,% .� ❑Plug Integrity BOP Test 0 Mechanical Integrity Test 0 Location Clearance RBD MAY 1 0 MS . 2014 Other: 3 0 P te,S 7. /-0 <5 D o p 5 , \ Ipv plaCz'k-v1 'r, "i a12p o Ecol pc� aoA�4C 25, /Z � � J Spacing Exception Required? 0 Yes Li No Subsequent Form Required: ± '' / APPROVED BY Date: 2,5 +" Approved By: a\ /1/.i COMMISSIONER THE COMMISSION Form 10-403 Revised 10/2O 2Appr�v cRIJi sNa�fcr 12 months from the date of approval Submit In Duplicate VLF 3/75/11- C b, cPr 31zs IIL ./<' 3,z_e, // To: Alaska Oil & Gas Conservation Commission bp From: Travis Boltz p CTD Engineer Date: March 12, 2014 Re: 06-03A Sundry Approval Sundry approval is requested to plug the 06-03A perforations as part of the drilling and completion of proposed 06-03B coiled tubing sidetrack. History and current status 06-03 was originally completed in 1976. A Rig Workover wasd completed in 1987. Then 06-03A was CTD sidetracked as a Z2A well in 1995. In 2004 a leaky GLV was straddled. Annular communication issues post GLV straddle continued to 2006. A Rig Workover was performed in May 2007 to remediate the annular communitcaion. The well has low remaining value and no remaining wellwork options. The proposed sidetrack will access 46 acres on DS-06. Proposed plan: Sidetrack 06-03A to 06-03B location using Nordic 1 Coiled Tubing Drilling rig on or around May 1st, 2014. The 06-03B sidetrack will exit the existing 3-1/2" liner and kick off in the in Ivishak Zone 2C,tag HOT and invert and stay in Zone 2A. This sidetrack will be completed with a 2- 3/8" L-80 liner which will be cemented in place. This Sundry covers setting whipstock,plugging the existing 06-03B perforations via the primary cement job to top of the liner or a liner top packer if the liner lap test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. 3- Coaco.. tire (441/ r/6144,' Q r lei r4 2oo is/Q .- 4 G d'4 t'H G Koff p� ?0 pit S 1 B gni Ah.e./ I �r/e 11,4Q /ecIger e ti cover" i5 ' ;./. (5- �b�' °" p' 74 fro Pre-Rig Work (scheduled to begin April 1st, 2014) 1. C Mill out 3-1/2" HES CIBP Plug at 10,659' MD and push to bottom. Drift for 3-1/2" KB packer whipstock. 2. V Set TWC. 3. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange. 4. 0 Remove wellhouse and level pad. Rig Work (scheduled to begin May 1st, 2014) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. MASP= 2369psi 2. Set 3-1/2" Whipstock 80 degrees ROHS 3. Mill 2.8" window 10705' MD and 10' MD of rathole 4. Drill build and lateral: 3.25" OH, ' 2161' MD (26 deg DLS planned build, 12 deg DLS lateral) 5. Run 2-3/8" liner from 10560' to 12866' MD. 6. Pump Primary cement job: 14bbls of 15.8 ppg, TOC 10560' MD 7. Perform liner cleanout and MCNL or RPM log. 8. Perform liner lap test. 9. Perforate liner based on log interpretation (-200ft) 10. Freeze protect well to 2,500' MD. 11. Set TWC, RDMO *Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. Re-install wellhouse, flowline and pull BPV. 2. Set GLV's 3. Set liner top packer with slickline* if liner lap test fails. * Approved alternate plug placement if liner lap test fails per 20 AAC 25.112(i) Travis Boltz CTD Engineer 564-5750 CC: Well File Joe Lastufka v I l-E5X7 FMC 120S LLAD= FMC 06-03A SAi NOTES: WELL ANGLE >70°@ 10676' At!`TUATOR= BAKER "'"5-1/2"CHROME TUBING' ** OKB.ELEV= 60' BF.aEV= KOP= 2900' ' ' 2093' H5-1/2"HES X NP,D=4.562" Max Angle= 91"@ 10909'. 9-5/8"UPPER FCC -I 2404' Datum MD= 10445' 9-5/8"LOWER FOC H 2682' -'-.- Datum ND= 8800'SS GAS UFT MANDRELS J ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,MN-80 BTRS,ID=12.347' H 2730' 4 3272 3261 18 MAG DMY RK 0 02/01/14 IL 3 6510 5752 44 ti/MG DMY FE 0 02/01/14 2 8099 6941 39 MMG DMY RK 0 05/11/07 1 9556 8119 33 WIG DMY RK 0 05/11/07 Minimum ID = 2.992" @ 9828' 3-1/2" LNR XO PIN _ ' ' ( 9637' -15-1/2"HES X NP,ID=4.562" X- 9668' J-19-5/8"X 5-1/2"BKR S-3 PKR,D=4.750"I 5-1/2"TBG,17#,13CR-80 VAM TOP HC, H 9762' ' r-x_9702' H5-1/2"HES X NP,ID=4.562" .0232 bpf,ID=4.892" 5-112"TBG STUB(RIG TAGGED 5/10/07) --I 9759' I 9763' 1-19-518"X 5 V2"UNIQUE OVERSHOT RSH-3 CUTTER KNIVES(XX/XX/XX) -{ ? 980T -I9-5/8"X 5-1/2"BKR S-3 PKR,13=4.84" TOP OF 3-1/2"LNR 9822' 9822' -5-112"PBR DEPLOY SUB,D=3.0" w/G FISHING NECK \ 9823' -j 7-1/2"MLLOUT EXT,ID=6.00"(BEHIND PIPE) 9828' --I5-112"X 3-1/2"XO,ID=2.992" li9829' -17-112"X 5-1/2"XO,D=4.892" 9877' H5-1/2"OTIS XN NP,D=4.455" 5-1/2"TBG-FC,17#,L-80 LTC-M, - 9890' " 9890' H5-1/2"WLEG,D=4.892" I .0232 bpf,ID=4.892" 9861' -{ELM)11'LOGGED 09/02/87 - . •v 10311' ESTMATED TOP OF CEMENT •••••• Hii••• ••••• ••• • �., ..•• ••• 1 ••, •••••O MLLOUT WINDOW(06-03A) 10480'-10486' • i • 9-5/8"CSG,47#,RS-95/MN-80 BTRS, ID=8.681" H 10871' •�•�• .••�•� ••••� '.•• PERFORATION SUMAARY 41 •;..,•..7••• ♦ — 10659' � {3 1/2"HES CEP(09/16!12) I REF LOG_ BHCS ON 01/29/76 1 "4tI i ,il,e ♦ 10749' -13-1/2"WFD CBP(08/10/12) ANGLE AT TOP PERF: 59"@ 10617' •-•-•-•-•-•-•-•-• •••••••• Note:Refer to Production DB for historical perf data •••••••••••• &•.•.•4•••••••�4 1 ? FISH-BP RUBBERS SIZE SPF INTERVAL Opn/Sqz SHOT SQZ ♦ (09/15/04) 2-1/2" 6 10617-10622 0 09/16/12 d�• 1' 2-1/2" 6 10727-10732 C 08/09/12 4111 ��i�o 2" 4 10814-10854 - C 01/23/01 of ��f 2-1/8" 4 10854-11070 • C 10/07/95 P670 - 11091' 3-1/2"LNR,9.3#,L-80 FL4S,.0087 bpf,ID=2.992" -I 11155' DATE REV BY COMuENTS DATE REV BY COM ENTS PRUDHOE BAY UNIT 02/06/76 PKR 141 INITIAL COM PLET1ON 09/17/12 RWMJMD ADPERF/SET CUP(09/16/12) Wa.L: 06-03A 08/07/87 PKR 141 RWO 12/12/13 DU/JMD TREE C/O(04/18/09) _ PERMT No: 1951520 10/07/95 NORDIC CTD SIDETRACK(06-03A) ~ 02/01/14 JS/PJC GLV GO API No: 50-029-20186-01 05/16/07 D16 RWO 02/17/14 TH DELEI L LINER SEC 2,T1 ON,R14E,488'FSL 8 1139'FEL 03/09/09 MCZ/PJC FINAL DRLG CORRECTIONS 08/13/12 JTC/JMD ADPERF/SET CUP(08/09-10/12) BP Exploration(Alaska) = 7FMC vARlLHEAD= FMC PROPOSED 06_03R x+ SA5-1/2NOTES:CHROMEWELL ANGGLE >70°@ .' ACTUATOR= BAKER C OKB.ELEV= 60' REV 1 I BF.REV= ? J KOP= 2900' I I 2093' . 15-1/2"HES X NP,ID=4.562" Max Angle= °@ : 9-5/8"UPPER FOC -I 2404' I-- Datum MD= 9-5/8'LOWER FOC H 2682' r— — GAS LFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE [13-3/8"CSG,72#,MN-80 BTRS,D=12.347"1--F 2730' 4 3272 3261 18 MNG DMY RK 0 02/01/14 3 6510 5752 44 MMG DMY RK 0 02/01/14 Minimum ID = .. MG2 8099 6941 39 G DM/ FM 0 . 05/11/07 1 9556 8119 33 MNG DMY RK 0 05/11/07 9637' H 5-1/2"HES X NP,ID=4.562" Z. 9668' H9-5/8'X 5-1/2'BKR S-3 PKR D=4.750' 5-112"TBG,17#,13C R-80 VAM TOP HC, -I 9762' I I 9702' -15-1/2"HES X NP,CI=4.562' 0232 bpf,ID=4.892" 5-1/2"TBG STUB(RIG TAGGED 5/10/07) -I 9759' 9763' -j9-5/8"X 5-1/2'UNIQUE OVERSHOT FISH-3 CUfT132 KM/ES(XX/XX/XX) - ? 9807' J-19-5/8'X 5-1/2'BKR S-3 PKR,D=4.84" TOP OF 3-1/2'LN2 H 9822' R 9822' 15-1/2"PBR DEPLOY SUB,D=3.0' ---.\--`. wl G FISHING NECK 9823' -{7-1/2•NLLOIITEXT.D-6.00'(BEHIND PIPES J [ 9828' -I5-112"X 3-1/2'XO,ID=2.992" 9829' H7-1/2'X 5-1/2 XO,D=4.892 9877' H5-1/2"OTIS XN NP,D=4.455' 5-1/2"TBG-PC,17#,L-80 LTC-M, -I 9890' —' 9890' H5-1/2"W..EG,D=4.892' .0232 bpf,D=4.892' 9861' FWD TT LOGGED 09/02/87 34°INC .-. .s 1 10311' --I ESTIMATED TOP OF CEWU1T 9-5/8"CSG,47#,RS-95/MN-80 BTRS, D=8.681' --I -10480 •:•:• ♦'.4,'.I 16,X1\ w;y} MLLOUT VITDOW(06-03A) 10480'-10486' ....'.t.: REF LOG: ON XX/XX/14 4 . ANGLE AT TOP PER1 0560 DEPLOY SLV,D= F: -°@ � ~ L_ � (�-" " Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ -10560 -iTOP OF CEMENT I FALLOUT VVNJOW(06-038) 10705'- _ ' 1 / 76°INC -{SHORT PUP JOINT w/RA TAG i ��'•. -•..�a�_ HSHORT PUP JOINT w/RA TAG J .,• TOP OF 2-3/8'LNR - -.10560 . 4P�a. � • .y• FBTD -i 3-1/2"KB WHIPSTOCK(XX/XX/14) -10705N• .ti '' • y 'fit a;.• • 1 3-1/2"LNR,9.3#,L-80 FL4S,.0087 bpf,ID=2.992" -1 11155' 1 2-3/8'LNR,-#,L-80 , -I -1284] 00 bpf,D=_ " DATE REV BY CONVENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 02/06/76 PKR 141 INTIAL COMPLETION 02/05/14 T IPJC _ADD PUP JOINTS w/RA TAGS WELL: 06-03B 08/07/87 PKR 141 RWO 02/19/14 TWPJC TOL/CMT TOP ADILITM34T PERMT No: 10/07/95 NORDIC CTD SIDETRACK(06-03A) _ AR No: 50-029.20186-02 05/16/07 D16 RWO SEC 2,T1 ON,R14E,488'FSL 8 1139'FEL XX/XX/14 CTD SIDETRACK(06-038) _ 02/02/14 TFV PJC BOLD PROPOSAL BP Exploration(Alaska) If In 01 M_ i- O i-I 6 I 112 m 1 o " U a f Iii 8 p 11 = 1 Alen" 0 m 0 1 ;- I LI — E X11 O o Eliki 5 .., :.I I . . 1iiiDL m " q 8we a 2 o F pN4 \/ a R m - = 1 o 1 a lei a I Cl O 1 II : 1—.-1 i i O 1 J oft 1g + "I I I O III 1 1 8 c� a Z ] 1 I �& � Au a• 111 I 111 z O <4 in 1 O O !1/ U U 03 Q I . - ill III I $ t51 a EG 111 II 1 °. 11 LL III � 1I 1 it V - WI ■ • 11. 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N N N N N N N N N N N N H N N N N�I \ .c; w o a 5 > u oo 5 on a a c 0 c eo ao ao v a) roo rsi 0.0 • O r �; '� > ° o ° o N z ;. a a s v c o Q; '0 Z cn z Q Q L .�a 0° co o a, m o V, r` H oo v N m c0 V ,�.= O N N m ,-, ,--r N J r-1 N N a1 Q f00) u' Ta: 0, W a A f a N z z 0::` 7 17- vi a' p U: O 0: cc z z ac Cr CC CC Z.A. cL cc a J' u- lL 11 u- LL LL LL LL LL LL LL LI- ; LL LL LL LL- 0 0 0 0 0 0 0 0 0 0 0 0 0 W 0 0 0 0 I— H f— H H H- H H H H H H I H_ H H H ...:r0 0 0 0 0 0 0 0 0 0 0 0 �t 0 0 0 0 W LU LU W w w w w w w w W * w w w w N , u G+ ,: w � cc m .-1 Q HI I i m _J) 1— , t6 4•13 u X X X X X X X X X X X XE5' pp x x x x I NI 1 ii di Z an e" Q w1 0 , 0 , O a Co* CO I CD i �, V r' �. m LO 01 N. N o0 N M N Ol m'j N� M O _ m N N N rn m m �� v N CC p y o 0 0 8c)„ ,90000 („ 8 8 O: p. O p 3, a W. ' �' 00000. g899 , 000;�, o 0 c,O N. '^ m m LL _ \ U' w• y' U p N. �j 0_ 0 w Q iD d > N >-, oo. Cr) w. -1 v ri N CIO X Q- L7 d A 0 ,-I 't ' >S iV- N a1 00 f®1 a OM m TC) U U U CD. U CO U CO CO U U co? U MO -0 In 1 > to-,` ro CO .0 CD O IIII Q a, "`u;e,aJ aJ i,OD V z (-)0 m t E w; Lail .. ,Z3 LO o Cr) r-- 0mo LD h co ,1 Om (ANO 0 V i L..�-/' (... cr V) Gl r� > N <1 :4t'1 - Z 2 O O O x U w Z 7 U O 6 E. Do O� Q ZG\,CL‘,,\ DATE: 5- Nov -12 Stephanie Pacillo TRANS#: 6192 Data Delivery Services Technician . /IVIakanaK Bender Schiumberger Oilfield Services , Natural Resources Technician II 1 WIRELIKE r` P..h: i.- Oil f'.c Grif? C011:?G ~i 0i (2e)ni) ;11(61 2525 Gambell St, Ste, 400 SCANNED FEB 2 5 2013 a _ > , 7." f , vK ; , r lii „ , '.r ii I ) l:t.('f: , t rat - 1: -1 Anchorage, AK 99503 I': Office: (907) 273 -1770 ' W 1 g, ! ij:-'4 ,E119,01 ' 0 RE5ERH „CN! MECH LOG DESCRIPTION, DATE B/W COLOR 1 NAME. ORDER # OIST; . - . DIST, ' DIST ,, I ,..•.. r ;:.�I�I�k� f�RtFSITS :. PRIM . Z -34 BTJO -00034 X USIT MSIP 8- Sep -12 1 1 CD H -02B C4W7 -00035 X PPROF 24- Aug -12 1 1 CD III G -29B C1 UB -00030 X LEAK DETECTION LOG 13- Sep -12 1 1 CD D -27A C2JC -00056 X LDL W/ WATERFLOW 5- Sep -12 1 1 CD L -100 C3NA -00041 X SFRT CH FORMATION RESISTI\ 15- Oct -12 1 1 CD 06-03A C4W7 -00036 X CEMENT BOND LOG 15- Sep -12 1 1 CD MPL -08 C600 -00036 X MEMORY INJECTION PROFILE 10- Aug -12 1 1 CD 15 -04B C600 -00045 X MEMORY PPROF 7- Sep -12 1 1 CD F -06A C3NA -00038 I X PPROF W DEFT & GHOST 16- Sep -12 1 1 CD C -20C BCRC -00212 X MEMORY PPROF 1- Oct -12 1 1 CD 14 -27 C3NA -00039 X LEAK DETECTION LOG 17- Sep -12 1 1 CD V -221 BBSK -00135 X (PROF W/ WFL 22- Aug -12 1 1 CD MPC-42 C600-00057 X MEMORY IPROF 9- Oct -12 1 1 CD MPC -28A C600-00056 X MEMORY IPROF 9- Oct -12 1 1 CD MPL -16A C5XI -00033 I X MEMORY IPROF 13- Sep -12 1 1 CD C -18B C600 -00053 X MEMORY PPROF 3- Oct -12 1 1 CD NK -22A BYS4 -00052 X LEAK DETECTION LOG 4- Sep -12 1 1 CD ; e MPG -01 C2JC -00054 X RST WATERFLOW LOG 31- Aug -12 1 1 CD 13 -36 BYS4 -00053 X LEAK DETECTION LOG 12- Sep -12 1 1 CD X X J G�,�� . � 4..., Please return a signed copy to: Please return a signed cefay to: BP PDC LR2-1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 CO U CP E Ja1 ritUtli tU STATE OF ALASKA Gc( 0 9 2012 f iKA OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other El 5c-f• p 1 vq Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ j Change Approved Program ❑ Operat. ShutdowrE Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory ❑ 195 -152 -0 3. Address: P.O. Box 196612 Stratigraphk❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20186 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028311 PBU 06 -03A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11155 feet Plugs measured 10659, 10749 feet true vertical 9057.73 feet Junk measured 9807, 11079 feet Effective Depth measured 10659 feet Packer measured See Attachment feet true vertical 8998.89 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H-40 30 - 110 30 - 110 1530 520 Surface 2701 13 -3/8" 72# MN -80 29 - 2730 29 - 2730 5380 2670 Intermediate None None None None None None Production 10843 9 -5/8" 47# RS -96 / MN -80 28 - 10871 28 - 9031.75 0 0 Liner 1333 3 -1/2" 9.3# L -80 9822 - 11155 8342.02 - 9057.73 10160 10530 Perforation depth Measured depth 10617 - 10622 feet 10727 - 10732 feet 10814 - 10854 feet 10854 - 11070 feet True Vertical depth 8979.23 - 8981.79 feet 9018.38 - 9019.42 feet 9030.06 - 9031.63 feet 9031.63 - 9039.86 feet Tubing (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 27 - 9890 27 - 8398.83 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JAN 10 2013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 64 8815 0 -15 360 Subsequent to operation: 656 8890 0 -15 284 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil- 1j Gas ❑ WbSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summer BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician Signat "� satr 4t lr /AIrIfi /iU� _, -_ �' Phone 564-4035 Date 10/8/2012 REoMS OCT 0"f / I (2 Form 10-404 Revised 10/2012 0 ' {� Submit Original Only Daily Report of Well Operations ADL0028311 ACTIVITYDATE I SUMMARY 9/14/2012 'oa• o oat U. ►► ' con'nue• o •- - ***WSR continued form 9- 15 -12 * ** T /1tO = 1927/1069/169 ( Assist E -Line / Load TBG for Logging ) Rig to TBG. Pump 3 bbls neat meth followed by 300 bbls 2% KCL to load TBG © Max Rate not to exceed 3000 Psi. Continue pumping 67 bbls 2% KCL @ .5 bpm while E -Line makes logging passes. Swap to dead crude and pump 70 bbls down TBG for freeze protect. RDMO. FWHP= 1440/1190/200 E -Line on well @ departure. IA and OA open to gauges. Operator notified of departure. ( Performed 9/15/2012 Fire / Man down drill ) * ** WELL SI ON ARRIVAL * ** (ELINE SCMT. CIBP, ADPERF) INITIAL T /I /O = 2200/1100/150 RIH W/ HEAD /ERS /SWIVEL/WB /PBMS /SCMT OAL =38' OAW = 250LBS MAX OD = 2.125 FN = 1.38" LOGGED PASS FROM DEVIATION TO TOP OF LINER, 10760' - 9771' AT 30FPM LOGGED 200' REPEAT PASS WITH 50' OF FREE PIPE. FIELD PICK TOC = 10344' POOH AND RIG UP FOR PLUG. RIH W/ HEAD /ERS /WB X2 /UPCT /HALLIBURTON SETTING TOOL AND PLUG OAL = 30.5' OAW = 230LBS MAX OD = 2.69" FN = 1.38" PLUG SET MID ELEMENT AT 10660'. TOP OF PLUG AT10659' RIH. HEAD /ERS /2X WB /UPCT /5' 2.5" PJOMEGA6 SPF 60DEG GUN. EH: 0.32" PEN: 30.6" CCL -TOP SHOT: 3.3'; CCL STOP DEPTH: 10613.7' INTERVAL: 10617 - 10622' WELL LEFT SI ON DEPARTURE. VALVES OTG. FINAL T /I /O = 1170/1100/200 9/15/2012 ** *JOB COMPLETE * ** • • Packers and SSV's Attachment ADL0028311 SW Name Type MD _ ND Depscription 06 -03A PACKER 9668 8152.67 5 -1/2" Baker S -3 Packer 06 -03A PACKER 9807 8269.45 5 -1/2" Baker S -3 Packer TREE _ �_, : NOTES: WELL ANGLE > 70° a 10676' MLLE-EAT). = FMC 0 6 _0 3A *•• 5 -1t2" CHROME TUBING*** A CTUATOR = AXH SON KB. E-EV = 60' BF. BEV= ? KOP= 2900' , I 2093' H 5 -1 /2" HES X NP, D = 4.562" Max Angie = 91° @ 10909 Datum MD = 10445' I 2404' - 9- F Datum TVD= 8800' SS A I 2682' , --19-518" FCC 1 13 -3/8" CSG, 72 #, MN 80 MRS, D = 12.347' H 2730' GAS LFT MA•DRH-S L ST MD ND 0EV TY FE VLV LATCH PORT DATE 4 3272 3261 18 MMG DOME RK 16 05/29/07 3 6510 5752 44 MMG SO RK 20 05/29/07 Minimum ID = 2.992" @ 9828' 2 8099 6941 39 MMG DM1 RK 0 05/11/07 3 -1/2" LNR XO PIN 1 9556 8119 33 WAG D•Y RK 0 05/11/07 ' I 9637' H5-1/2" I-ES X NP, D = 4.562" I M IJ 9668' H9-5/8" X 5-1/2' BKR S-3 PKR, D = 6.00" 15 -1/2" TBG STUB (05- 09-07) H 9757' ' 9702' — 15 -1/2' HES X NP, ID = 4.562" 5-1/2" TBG, 17 #, 13CR 80 VAM TOP HC, H 9762' j---______ 1 1 9763 I -19 -5/8" X 5-1/2" UMQUE OVERSHOT 1 .0232 bpf, D = 4.892" I FISH - 3 CUTTER ONES (XX/XX/X() —I ? - 9807' H9-5/8" X 5 -1/2" BKR S-3 PKR, D = 6.00" ( TOP OF 3-1/2" LNR 1-1 9822' 1 Al ' 9822' I--15 -1/2" PBR CE PLOY SUB, D= 3.0" w / G FIST -SIG NECK 9823' H7-1/2" W ILLOUT EXT, D = 6.00' (BROND PIPE) I 9828' I- 15-1/2" X 3 -1/2" XO, ID = 2.992" 9829' — 17 -1/2" X 5 -1/2" XO, ID = 4.892" (BEHIND PIPE) I I[ I 9877' 1H5 -112" OTIS XN NP, 113 = 4.455" (BRAND PIPE) 5 -1/2" TBG, 17#, L-80 PC LTGM —1 9890' 1 9890' - -15- 112" WLEG, ID = 4.892' (BBOND PIPE) I .0232 bpf, D = 4.892" I I 9861' —I B-MD TT LOGGED 09/02/87 I r* V• I 10311' —1 ESTIMATED TOP OF CE4I3'TT I ► •• � • � • J l 10871' ' * ► ►iii 9- 518" CSG, 47#, RS-95 / MLLOUT WINDOW (06.03A) 10480' - 10486' I D = 8.681' MN-80 MRS, ' ► �� � � 4 ��: ►••, __________ _— —_.7.— — .._ • FE2FORATDN SUMMARY • • + t 1 �� 10669' (-I 112' HES CEP (09/16112)' REF LOG: BHCS ON 01 /29/76 •,• 0110 10749' 3 -1/2" WFD COP (08/10/12) ..... L . ; ANGLE AT TOP PERF: 59° @ 10617' • • .• • • • • • • • • ►•••••♦ Note: Refer to Roduction DB for historical pert data j • � • � • � • � • •• �/ ` ? —FISH - BP RUBBERS • E SPF INTERVAL • . ♦����♦ ■ �� ► • • • • •••••••• (09/15/04) - ■•••••• 2-1 6 11 . 7- 1 •22 0 09/16/12 1 • Alto. . 2- 6 10 - a 32 C I . o1 ►•••••••••••• ' ! i ��ii ■•••••• .WI 2" 4 10814 - 10854 C 01/23/01 ►'• iiii PBTD 11091' 'it' 2 -1/8" 4 10854 - 11070 C 10/07/95 13 -1/2" LNR, 9.3#, L -80 FL4S, .0087 bpf, D= 2.992" H 11155' DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDI-OEBAY tNT P 1976 PKR 141 ORIGINAL COMPLETION 02/19/09 ?/ PJC DRLG CORREGOONS WELL: 06-03A 0800087 PKR 141 RWO 03/09/09 MCZ/PJC FINAL DRLG CORRECTIONS PERMIT No: '1951520 10/07/95 CTD SIDETRACK (06 -03A) 08/13/12 JTC/JMD ADPERF & SET CEP (08/09- 10/12) API No: 50- 029 - 20186 -01 05116/07 D16 RWO 09/17/12 RIMWJMD ADPE2F & SET CEP (09 /16/12) SEC 2, T1 ON, R14E, 489' FSL & 1139' FE_ 06/01/07 CJNPAG GLV CIO (05/29/07) 01/19/09 ? /JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) n BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~, , by Mr. Tom Maunder ~~~.~;6~~~' JAi~ ~ ~' ~~~ Alaska Oil and Gas Conservation Commission r 333 West 7th Avenue t (fir 5" .~ I Anchorage, Alaska 99501 4 _ ` ~,3 Subject: Corrosion Inhibitor Treatments of GPB DS 06 ~ ~ / Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 06 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-06 Data' 1?/1(1/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 06-01 1750490 50028201720000 NA Sealed NA 06-02 1770780 500292o2s2oooo NA Sealed NA o6-03A 1951520 50029201860100 NA Sealed NA os-oaA 2001020 50029201780100 NA Sealed NA os-o5 1780200 5ooz92o29soooo NA Sealed NA 06-066 2050980 50029202010200 NA Sealed NA os-07 1780210 50029202990000 NA Sealed NA os-osA 1951950 5oozszo3oool0o NA Sealed NA 06-09 1790730 50o292oaoooooo NA Sealed NA o6-1oA 1981960 50o292oao2oloo NA Sealed NA 06-11 1791100 50029204280000 NA Sealed NA 06-12A 1920640 50029204560100 NA 0.5 NA 3.40 10/8/2009 06-13A 2061020 50029204570100 NA Sealed NA os-148 2090120 50029204580200 NA Sealed NA 06-15 1800320 50029204590000 NA Sealed NA 06-16 1800330 50029204600000 NA Sealed NA 06-18A 2090630 50029207670100 NA 0.3 NA 1.70 11/5/2009 06-19A 2081020 50029207910100 NA 1.5 NA 6.80 10/4/2009 06-20A 2050790 50029207990100 NA 1 NA 5.10 10/4/2009 06-21B 2080990 50029208020200 NA 6 NA 42.50 12/14/2009 os-22A 1930570 500292o8os01oo NA 1.5 NA 5.10 10/4/2009 06-23C 2080920 50029208080300 NA 4.6 NA 30.60 10/6/2009 os-zaA 2000960 5oo2s2os22o1oo NA Sealed NA ~ -!'A(~ .. STATE OF ALASKA ¿ ~.D..~" {, ~ ;...,. ALAYA OIL AND GAS CONSERVATION CO&ION l \~Cl2'/' -"1"'" REPORT OF SUNDRY WELL OPERA TIONS4/e. ,,_b-J JÚN () (.I'(" ,; "~ ',ftr;J a '/' '11 Ã>. Jr" 1. Operations Performed: uHS Co ",/ o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Erí10f:~~~~Well o Alter Casing 181 Pull Tubing o Waiver qUe ", /l>'fl¡,' o Perforate New Pool o Other ' ';/'(ì/¡ o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 195-152 " 3. Address: ~ o Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20186-01-00 - 7. KB Elevation (ft): 60' , 9. Well Name and Number: PBU 06-03A r 8. Property Designation: 10. Field / Pool(s): ADL 028311 r Prudhoe Bay Field / Prudhoe Bay Pool- 11. Present well condition summary Total depth: measured 11155 ' feet true vertical 9058 ( feet Plugs (measured) 9873 Effective depth: measured 11 097 feet Junk (measured) Unknown true vertical 9044 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1530 520 Surface 2729' 13-3/8" 2729' 2729' 5380 2670 Intermediate 10480' 9-5/8" 10480' 8888' 6870 4760 Production Liner 1328' 3-1/2" 9827' - 11155' 8346' - 9058' 10160 10530 iCANNS) JUN 2 5 2007 Perforation Depth MD (ft): Below IBP: 10814' - 11070' Perforation Depth TVD (ft): 9030' - 9040' 5-1/2", 17# 13Cr80 / L-80 9890' Tubing Size (size, grade, and measured depth): 9-5/8" x 5-1/2" Baker 'S-3' packer _.·.··.··_1..... 9668' Packers and SSSV (type and measured depth): 9-5/8" x 5-1/2" Baker 'SB-3' packer 9807' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily AveraQe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG DGINJ DWINJ o 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 Paul Chan, 564-5254 N/A Printed Name Terrie Hubble Title Technical Assistant Signature ~.A 1\; () ~ 0(07 alp !l Prepared By Name/Number: Phone 564-4628 Date 'D7rerrie Hubble, 564-4628 n R I h 11\1 L1 , RBDMS 8FL JUN ~ 2 20D7 Submit Original Only Form 10-404 Revised 04/2006 Digital Wellfile . Page 1 of 1 . Well: 06-03 Well Events for SurfaceWell - 06-03 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS3 -> 06 -> 06-03 Date Range: 11/Apr/2007 to 29/Apr/2007 Data Source(s): AWGRS Events Source Well Date AwGß$ 06-03A 04/29/2007 AWGRS 06-03A 04/28/2007 AWGRS 06-03A 04/28/2007 AwGRS 06-03A 04/28/2007 AwGRs 06-03A 04/27/2007 AWGRS 06-03A 04/26/2007 AwGRs 06-03A 04/25/2007 AWGRS 06-03A 04/24/2007 AWGRS 06-03A 04/21/2007 AwGRS 06-03A 04/20/2007 AWGRS 06-03A 04/11/2007 Description T/I/O=0/vac/75. Temp=SI. Bleed WHPs to 0 psi (pre rig). Integral on IA. TBG, IA & OA FL near surface. Bled OA to 20 psi in 30 min, fluid @ surface, 51 OA. Continued OA bleed. Bled OA to 0 psi in 15 min, OAP increased to 12 psi in 15 min.. Bled OA to 0+ psi in 15 min, OAP increased to 15 psi in 15 min. Bled OAP to 0+ psi in 1.5 hr, OAP increased to 12 psi in 15 min. Final WHPs 0/vac/15. JET CUT TUBING 7317' SLM, 10' ABOVE JUNK CATCHER, CUT WITH 4.15" JET POWER CUTTER. WELL SHUT IN. ***JOB COMPLETE*** T/I/O=0+/vac/75. Temp=SI. WHPs (pre-rig). Integral on IA. Companion valve w/integral. No AL line. SET BPV / PRE RIG T/I/O=400/200/100 3rd and final CIRC OUT, CMIT TxlA PASSED to 3500 psi, MIT OA PASSED to 2000 psi. [Pre RWO] Pumped 5 bbls neat meoh, 304 bbls 2% KCL down tubing taking returns up the IA to Well 06-02 flowline, Pumped 3 bbls meth spear, 150 bbls of 120* diesel down IA taking returns up tubing to Well 06-02 flowline. U-TUBE Tx IA to freeze protect. Pumped 9.2 bbls diesel to CMIT TBG x IA to 3500 psi, PASSED Loss 80 psi 1st 15 min, loss 40 psi 2nd 15 min. Pump 1.3 bbls Diesel to MIT OA to 2000 psi. PASSED Loss 100 psi 1st 15 min, loss 50 psi 2nd 15 min. Bled well FWHP's =0/0/0 Note: Circed well thru POGLM @ 3805'-3840' elm T/I/O=560/560/50 Temp= 5/1 2nd time Circ-Out (RWO Prep) Pumped down TBG taking returns out IA to flowline of well 06-02, 5 bbls. meth spear followed by 291 bbls. 120* 2% KCL caped with 10 bbls. meth for freeze protect TBG, Pumped 5 bbls. meth down IA to freeze protect lA, Freeze protect skid and hardline to well 06-02, Final WHP's 370/370/0 Note: Circing thru POGLM @ 3805'-3840' elm ***Job in progress*** Circ-out (Prep RWO) Pumped 5 bbls meth spear followed by 58 bbls 2% kcl & found ice plug in flowline on previous WSR. Veco re rigged hardline to take returns up IA & down flowline of 06-02. Finished pumping 290 bbls 2% kcl, freeze protected tbg w/ 5 bbls meth, freeze protected IA with 3 bbls meth, freeze protected hardline with 3 bbls meth & 5 bbls diesel. FWHP's=950/950/950 Complete w/ 1st circ thru holes in tbg @ 3805-3840' elm. Notified Well Support to refill UR for 2nd circ 24 hrs from now. T/I/O= 300/600/100 Circ-Out Pumped 5 bbls meth down tbg taking returns upn IA to flowline. Pumped 50 bbls 2% kcl tbg/IA/flowline all pressured up to 1700 psi. Called DSO to open IGV & choke. Pressure dropped to 1500 psi. pumped 8 more bbls & pressured up to 1700 psi again. Contacted DSO and determined there must be an ice plug in flow line. Contact PE. Veco to re-rig hardline to 06-02 flow line. ****Continue on next day WSR**** ** CONT FROM 4-20-07 WSR** PULLED BTM ANCHOR FROM WFD PATCH @ 3815' SLM. DUMP BAILED 20' OF SLUGGITS ON TOP OF IBP @ 9882'SLM . SET 5.5" JUNK CATCHER (118" OAL, 4.51 OD) ON AVA POGLM @ 7327'SLM . ***WELL LEFT 5/1, SSV DUMPED*** ***WELL 5/1 ON ARRIVAL *** {pre rwo} PULLED TOP SECTION OF WFD PATCH FROM 3780' SLM. ** CONT ONTO 4-21-07 WSR** T/IA/OA= 51 100/500/0 PPPOT-T(PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T(PASS) RU bled tool onto tubing head adapter test void, 0 psi on void. Pressured to 5000 psi for a 30 minute test. 4900/ 15 min, 4900/ 30 min. Bled THA void to 0 psi RD test equipment re installed Alemite cap. Cycled all LDS all moved free with no broke or bent pins PPPOT-IC (PASS) RU bled tool onto IC test void, 200 psi on void, bled to 0 psi. Pressured to 3000 psi for 30 minute test. 2800/ 15 min, 2800/ 30 min. Bled IC test void to 0 psi, RD test equipment re installed Alemite cap. Cycled all LDS, all moved with the gland nuts could not break them free this can be fixed during RWO. http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 6/6/2007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-03A 06-03A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 4/30/2007 Rig Release: 5/11/2007 Rig Number: Spud Date: 1/2/1976 End: 4/29/2007 12:00 - 13:00 1.00 MOB P PRE Prepare to Move Rig. 13:00 - 14:00 1.00 MOB N WAIT PRE Wait on Endicott Well Tender to Terminate ESD 14:00 - 14:30 0.50 MOB P PRE Jack up Rig and Pull off Well End 2-08. 14:30 - 16:30 2.00 MOB P PRE N/D BOP Components. 16:30 - 18:00 1.50 MOB P PRE Position Rig and Lay Down Derrick. 18:00 - 19:00 1.00 MOB P PRE RlU Booster Wheels to Rig. 19:00 - 20:30 1.50 MOB P PRE Repair Booster Wheel Assembly. 20:30 - 00:00 3.50 MOB P PRE Move Rig off MPI, Enroute to DS. 6-03 4/30/2007 00:00 - 18:30 18.50 MOB P PRE AT Midnight Rig on MPI, Moving onto Ice Road, Enroute to DS. #6-03.18:30 Pulled onto D.S. 06-03 18:30 - 21 :00 2.50 MOB P PRE Steam and Remove Booster Tires. Move in a Portable Bleed Tank and Bleed Off ONPressure. 25 psi on OA, Bleed to 0 Psi, Pressure built to 10 psi in 15 minutes. 21 :00 - 22:00 1.00 MOB P PRE PJSM, Prepare for and Raise Derrick. 22:00 - 00:00 2.00 MOB P PRE Rig Up Drill Floor, Bridle Down, RlU Top Drive. Drill Site Maintenance Installing a VR plug in One of the OA valves and Moving IA Valve to Other Side of the Production Tree to Accomodate MIRU. 5/1/2007 00:00 - 02:00 2.00 MOB P PRE Continue to RlU Drill Floor. 02:00 - 06:30 4.50 MOB P PRE Continue to Work on BOPs in Shop. N/U BOPs on Rig as they Come Availible. Lay Out Herculite and Rig Mats Around Well 06-03. 0/ A Pressure Bleed Off to 0 psi, Shut in for 15 minutes Pressure Increased to 10 psi. 06:30 - 08:30 2.00 MOB P PRE PJSM Position Rig to Spot Over Well, Waiting for Authorization to Move onto Well. O/A Building Pressure 10 psi in 15 minutes. 08:30 - 09:30 1.00 MOB P PRE Spot Rig Over Well and Shim to Level. 09:30 - 11 :00 1.50 MOB P PRE Spot Slop Tank, Install Double Annulus Valve, RlU Circulating Lines, Spot #2 Pump Room. 11 :00 - 12:00 1.00 MOB P PRE Take on 8.5ppg Sea Water into Pits 3 and 4. Continue to RlU. 12:00 - 12:30 0.50 MOB P PRE Pressure Test Surface Circulating Lines to 3,500 psi. Mix 40 bbl Hi-Vis, Safe-Surf 0 Sweep. 12:30 - 14:00 1.50 CLEAN P DECOMP Pump 40 bbl Sweep Followed by 120 deg Sea Water, At 8 bpm with 560 psi, Monitor Wellbore. 14:00 - 15:00 1.00 CLEAN P DECOMP Blow Down Surface Lines, Set TWC, Test From Below to 1,000 psi, B/D RID Test Equipment. 15:00 - 16:00 1.00 CLEAN P DECOMP Bleed Down SSSV Control Lines to 0 Psi. 16:00 - 17:00 1.00 WHSUR P DECOMP N/D Production Tree and Adapter Flange. 17:00 - 17:30 0.50 WHSUR P DECOMP Check Hanger Threads M/U XO to Hanger 9.5 Turns to Make Up Hanger Threads in Good Condition. Install Blanking Sub. 17:30 - 19:30 2.00 BOPSU P DECOMP Nipple Up BOPE, Install Turnbuckles, Install Flow Line. 19:30 - 20:30 1.00 BOPSU P DECOMP RlU BOP Test Equipment. 20:30 - 00:00 3.50 BOPSU P DECOMP Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Jeff Jones. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Annular Preventer, Choke HCR, Kill HCR, Upper IBOP. Test #2- Manual Choke, Manual Kill, Lower IBOP. Test #3- Choke Valves 1, 12, 13, 14 Test #4- VBRs w/4" Donut Test Joint. 5/2/2007 00:00 - 02:00 2.00 BOPSU P DECOMP Continue Testing BOPE. Test #5-VBRs on 5.5" Donut Test Joint. Test #6- Choke Valves 9,11, Blind Rams. Printed: 5/14/2007 10:50: 11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-03A 06-03A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 4/30/2007 Rig Release: 5/11/2007 Rig Number: Spud Date: 1/2/1976 End: Test #7- Choke Valves 5,8,10,TIW Valve. Test #8- Choke Valve 4,6,7, Dart Valve. Test #9- Choke Valve 2 Test #10-Choke Valve 3 Accumulater Test- 2,900 psi Starting Pressure, 1,900 psi After Actuation, First 200 psi in 16 seconds, Full Pressure in 1 Minute 9 Seconds. 5 Nitrogen Bottles at 2,100 psi. 02:00 - 03:00 1.00 BOPSU P DECOMP RID BID BOP Test Equipment Pull Blanking Plug, M/U Landing Jt and Floor Safety Valve 03:00 - 04:00 1.00 WHSUR P DECOMP RlU DSM Lubricator and Pull BPV. RID DSM. 04:00 - 06:00 2.00 PULL P DECOMP Drain BOP Stack, Repair Two LDS and Terminate Control Lines, P/U Landing Jt, Engage Tubing. BOLDS Pull Tubing Hanger to Rig Floor, Tubing Hanger Unseated at 225,000# Up Weight, Broke over at 160,000#, String Weight 146,000#. UD Landing Joint and Tubing Hanger. RlU to Circulate. 06:00 - 07:30 1.50 PULL P DECOMP CBU at 11 bpm w/1050 psi, Monitor Well Bore, RID Circulating Lines. 07:30 - 10:00 2.50 PULL P DECOMP Pull and UD 5.5",17#, L-80, Tubing fl7,322'. 10:00 - 10:30 0.50 PULL P DECOMP UD SSSV RID Camco Control Line Spool Unit. Recovered 32 Out Of 33 SS Control Line Bands. 10:30 - 15:00 4.50 PULL P DECOMP Continue to UD 5.5" Tubing, 179 Joints Total, and Cut Joint lenght= 11.10". Tubing Condition Good, Pin End Has Some Pitting and Corrosion, Jt #95 has Four Perf Holes in it at 3,964', 15:00 - 16:00 1.00 PULL P DECOMP RID Tubing Handling Equipment, Set Wear Ring, Clear and Clean Rig Floor, 16:00 - 18:00 2.00 FISH P DECOMP PIU M/U Outside Cutter Assembly, BHA Consists of 8.5" Shoe, Outside Cutter, 3- jts Wash Pipe, Washover Boot Basket, Pump Out Sub, XO, 9-6 1/4" Drill Collars, XO, XO, BHA Lenght=384.13' . 18:00 - 00:00 6.00 FISH P DECOMP P/U Drill Pipe From Pipe Shed 1x1 and RIH. 5/3/2007 00:00 - 00:30 0.50 FISH P DECOMP Continue to RIH P/U 4" HT-38 Drillpipe from Pipe Shed. From 6,446' to 7,304'. 00:30 - 03:00 2.50 FISH P DECOMP Obtain Parameters: Up Weight=150,000#, Down Weight=135,000#, Rotating Weight=145,OOO#, 2,000 ft-Ibs Free Torque, 4 bpm with 240 psi. Tag Tubing Stub at 7,304', Dress off Stub w/0-1 ,000 wob, with 30 rpm 2-4,000 ft-Ibs Torque, 2 bpm w/90 psi. Continue to RIH to 7,389'. PIU and Locate Tubing Collar and Cut Tubing at 7,375' wlSame Parameters. 03:00 - 04:00 1.00 FISH P DECOMP CBU at 9.5 bpm with 1,540 psi. Monitor Well Bore, Pump 15 bbl Dry Job. 04:00 - 06:30 2.50 FISH P DECOMP POOH fl7,389' to t/384'. 06:30 - 08:30 2.00 FISH P DECOMP Stand Back 3 stds 6 1/4" Drill Collars, UD Fish and Cutter BHA, Total Lenght of Fish=74.57'. 08:30 - 09:00 0.50 PULL DECOMP Clear and Clean Rig Floor. 09:00 - 09:30 0.50 PULL P DECOMP Nipple Down Flow Riser, Nipple Up Shooting Flange to Top of Annular Preventer. 09:30 - 12:00 2.50 PULL P DECOMP RlU SWS E-Line wlFull Pressure Control Equipment. 10' Lubricator Extension, Pump In Sub, Wire Line BOPs, and Pack Off. 12:00 - 13:30 1.50 PULL P DECOMP Attempt to Test SWS Pressure Control Equipment, Pack Off Printed: 5/14/2007 10:50:11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-03A 06-03A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 4/30/2007 Rig Release: 5/11/2007 Rig Number: Spud Date: 1/2/1976 End: 513/2007 12:00 - 13:30 1.50 PULL P DECOMP Leaking, Changed Pack off Rubber and Tested Equipment to 1,000 psi. 13:30 - 15:30 2.00 PULL P DECOMP RIH wlPower Jet Cutter and Collar Locator, Collar Locater Failed at +- 7,000' POOH to Repair. 15:30 - 18:00 2.50 PULL N DFAL DECOMP Trouble Shoot and Repair Electrical Problem, Rewire Shooting Assembly and Re-Arm Jet Cutter. 18:00 - 20:30 2.50 PULL P DECOMP RIH wlPower Jet Cutter amd Collar Locator Positioned Cutter Head, Confirmed Depth and Correlated Logs, Cut Pipe at 9,780'. Closed in OA Valve for 1 hr, Pressure Built 5.5 psi. Opened OA and Continue to Bleed to Slop Tank. 20:30 - 21 :30 1.00 PULL P DECOMP RID E-Line Equipment. 21 :30 - 22:00 0.50 PULL P DECOMP RID Shooting Flange and Nipple Up Flow Riser. 22:00 - 23:30 1.50 PULL P DECOMP M/U Over Shot Assembly. BHA Consists of: Cut Lip Guide, Over Shot Bowl, Top Extension,Top Sub, Bumper Sub,Oil Jar, Pump Out Sub, XO, 9-6 1/4" Drill Collars, XO, XO. BHA Lenght=309.32' . 23:30 - 00:00 0.50 PULL P DECOMP RIH to 1,267'. 5/4/2007 00:00 - 01 :00 1.00 PULL P DECOMP Continue to RIH f/1,267' tJ7,370'. BHA Consists of: Cut Lip Guide, Over Shot Bowl, Top Extension,Top Sub, Bumper Sub,OiI Jar, Pump Out Sub, XO, 9-6 1/4" Drill Collars, XO, XO. BHA Lenght=309.32'. 01 :00 - 02:00 1.00 PULL P DECOMP Obtain Parameters: Up Weight=150,OOO#, Down Weight=135,OOO#, Rotating Weight=145,000#, Continue to To RIH to Tag TOF @ 7,379', Swallowed 5'. Attempt to Pull Free, jar 3X Staged up to a Maximum Over Pull 150,000# Over. Attempt to Circulate, Pressured up to 1,500 psi Shut Pump Down Pressure Held Solid at 1,500 psi. No Returns. Released Over Shot. Discussed Options with ODE Decision Made to Re-cut With Power Jet Cutter. 02:00 - 02:30 0.50 PULL P DECOMP Monitor Well, Pump 15 bbl Dry Job, BID Top Drive. 02:30 - 04:30 2.00 PULL P DECOMP POOH f/7,379' To Drill Collars. 04:30 - 05:00 0.50 PULL P DECOMP Stand Back 6 1/4" Drill Collars, UD Over Shot BHA. 05:00 - 05:30 0.50 PULL P DECOMP Clear and Clean Rig Floor. 05:30 - 06:00 0.50 PULL P DECOMP NID Flow Riser, NIU Shooting Flange to Top of Annular Preventer, for Wireline Operations 06:00 - 08:30 2.50 PULL P DECOMP RlU SWS wlFull Pressure Control Equipment. 10' Lubricator Extension, Pump In Sub, Wire Line BOPs, and Pack Off. Pressure Tested Pressure Control Equipment to 1,000 psi. PIU Power Jet Cutter. 08:30 - 12:30 4.00 PULL P DECOMP RIH w/Power Jet Cutter and CCL t/9,873' CCL Indicates Previous Cut was Good. Discuss Options with ODE. POOH to 8,900' and Cut Tubing. POOH to Surface wI E-Line. 12:30 - 13:00 0.50 PULL P DECOMP RID SWS E-Line and Pressure Control Equipment. 13:00 - 14:00 1.00 PULL P DECOMP RID Shooting Flange and Nipple Up Flow Riser. 14:00 - 14:30 0.50 PULL P DECOMP P/U and RIH with Over Shot Assembly. BHA Consists of: Cut Lip Guide, Over Shot Bowl, Top Extension,Top Sub, Bumper Sub, Oil Jar, Pump Out Sub, XO, 9-6 1/4" Drill Collars, XO, XO. BHA Lenght=309.32'. 14:30 - 16:00 1.50 PULL P DECOMP RIH with Drill Pipe to 7,295'. 16:00 - 16:30 0.50 PULL P DECOMP Obtain Parameters: Up Weight=150,000#, Down Weight=135,000#, Rotating Weight-145,000#, Latch Fish Picked up Additional 22,000# on Weight Indicator. 16:30 - 18:00 1.50 PULL P DECOMP CBU At 10 bpm, On Bottoms Up Observed Gas and Crude at Printed: 5/14/2007 10:50:11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-03A 06-03A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 4/30/2007 Rig Release: 5/11/2007 Rig Number: Spud Date: 1/2/1976 End: 5/4/2007 16:30 - 18:00 1.50 PULL P DEcaMP Flow Nipple, Took Crude Returns to Slop Tank Approx 47 bbls, Returns Contained Fiberous Material and Possibly Maraseal or Cement. Circulated Well Bore Clean, Flow Check, Well Bore Stable. 18:00 - 20:00 2.00 PULL P DEcaMP POOH 20:00 - 20:30 0.50 PULL P DECOMP Stand Back Drill Collars, UD Overshot with 1 jt of 5.5" Tubing. 20:30 - 22:00 1.50 PULL P DECOMP RlU to Lay Down 5.5' Tubing, UD 36 jts = 1,478.20'. And 1-Cut jt Lenght = 21.27'. Outside of Tubing Coated in Fiberous Material that Looks Like Cement, Light Scaling, Pin Ends of Tubing Showing Some Corrosion. 22:00 - 23:00 1.00 PULL P DECOMP RID Tubing Handling Equipment, Break Out jt of Tubing From Overshot. 23:00 - 00:00 1.00 PULL P DECOMP RlU to PIU Wash Pipe, and M/U Outside Cutter. 5/5/2007 00:00 - 01 :30 1.50 PULL P DECOMP M/U Outside Cutter Wash Pipe Assembly, BHA Consists of: Wash Over Shoe, Outside Cutter, 10-Joints Wash Pipe, Wash Over Junk Basket, Pump Out Sub, XO, 9-Drill Collars, XO, XO. BHA Lenght=602.99' 01 :30 - 05:30 4.00 PULL P DECOMP RIH with Drill Pipe. Tripping in Slowly Due to Pipe Overflowing with Wash Pipe in BHA. 05:30 - 07:00 1.50 PULL P DECOMP PIU 36 jts of 4" Ht-38 Drill Pipe from Pipe Shed. 07:00 - 08:00 1.00 PULL P DECOMP Slip and Cut 80' Drilling Line and Service Rig. 08:00 - 08:30 0.50 PULL P DECOMP Obtain Parameters: Up Weight= 175,000#, Down Weight= 150,000#, Rotating Weight= 164,000#, 30 rpm, 4,000 ft-Ibs Free Torque, 08:30 - 10:30 2.00 PULL P DECOMP Contiue to RIH P/U Drill Pipe from Pipe Shed. Tag Top of Fish at 8,874'. Wash Over Tubing to 9,080' Unable to Wash any Deeper. 10:30 - 12:30 2.00 PULL P DECOMP Pick Up Slowly to Locate Tubing Collar to Make Cut. Cut Pipe at 9,057', with 30 rpm, 20 bpm w/150 psi. 12:30 - 13:30 1.00 PULL P DECOMP Pump 20 bbl Hi-Vis Sweep, 12 bpm, 2,650 psi. At Bottoms Up Observed Gas and Oil Cut Returns, Overboarded 58 bbl of Fluid and the 20 bbl Sweep. 13:30 - 16:00 2.50 PULL P DECOMP Monitor Well, Blow Down Top Drive, POOH. 16:00 - 17:00 1.00 PULL P DECOMP Stand Back Drill Collars, Clean Out Junk Basket, Recovered 2.5 Gallons of Maraseal, Stand Back 1 Stand of Wash Pipe UD One jt Wash Pipe. 17:00 - 17:30 0.50 PULL P DECOMP PJSM on Stripping Out Tubing From Wash Pipe. RlU to Lay Down Tubing. 17:30 - 18:30 1.00 PULL P DECOMP M/U and Spear Tubing in Wash Pipe. Lay Down Tubing. Total Lenght of Recovered Tubing = 183.56'. Tubing Cut Not Complete, Parted Cut with 80,000# over String Weight. 18:30 - 19:00 0.50 PULL P DECOMP RID Tubing Handling Equipment. 19:00 - 19:30 0.50 PULL P DECOMP POOH w/Wash Pipe, UD Wash Pipe Shoe and Cutter Assembly. 19:30 - 21:00 1.50 PULL P DECOMP M/U Wash Over Assembly, BHA Consists of: Wash Over Shoe, 10 Jts Wash Pipe, Wash Over Junk Basket, Bumper Sub, Oil Jar, Pump Out Sub, XO, 9-6 1/4" Drill Collars, XO, XO, BHA Lenght = 620.22'. 21 :00 - 00:00 3.00 PULL P DECOMP RIH With Wash Over Assembly to 5,120'. 5/6/2007 00:00 - 00:30 0.50 PULL P DECaMP RIH with Wash Over Shoe and Wash Pipe Assembly, f/5,120' to 5,968', wID rill Pipe From Derrick. 00:30 - 01 :00 0.50 PULL P DECOMP PIU 21Joints of Drill Pipe flPipe Shed, POOH Stand Back 7 Stands of 4" HT-38 DP, For Wash Over Operations. Printed: 5/14/2007 10:50:11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-03A 06-03A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 4/30/2007 Rig Release: 5/11/2007 Rig Number: Spud Date: 1/2/1976 End: 5/6/2007 01 :00 - 02:00 1.00 PULL P DECOMP Continue to RIH f/5,968' to 9,047'. 02:00 - 02:30 0.50 PULL P DECOMP Obtain Parameters: Up Weight=175,000#, Down Weight=156,000#, Rotating Weight=168,000#, 30 rpm, 3,000 ft-Ibs Free Torque, 6.5 bpm, 660 psi. 02:30 - 07:00 4.50 PULL P DECOMP Tagged Top of Fish at 9,057' Washed Down and Tagged Top of Fill at 9,080'. Cleaned Out Fill w/70 rpm, 6,000 ft-Ibs Torque, 5,000# wob, 6.5 bpm and 820 psi, Increase Pump Pressure to 11 bpm, and 1,900 psi. Washed to 9,368' and NO-GO on Wash Pipe. 07:00 - 08:00 1.00 PULL P DECOMP Pump Hi-Vis Sweep, CBU at 14 bpm and 3.470 psi, Moderate Sand Returns on B/U. 08:00 - 08:30 0.50 PULL P DECOMP Monitor Well, BID Top Drive, Pump Dry Job. 08:30 - 12:30 4.00 PULL P DECOMP POOH to BHA at 620'. 12:30 - 13:30 1.00 PULL P DECOMP Stand Back 6 1/4" Drill Collars, Stand Back Wash Pipe Assembly. Wash Pipe Shoe, Cutting Structure 80% Gone. Clean Junk Basket, Recovered Two Sliced Pieces of Tubing Wall, One piece 10" x 4" and the Other 6"x4" , Approx 60# Of Metal Debris. 13:30 - 14:00 0.50 PULL P DECOMP M/U Outside Cutter Assembly, BHA Consist of: Cut Lip Guild, Outside Cutter, 10 jts Wash Pipe, Washover Boot Basket, Pump Out Sub, XO, 9 - 6 1/4" Drill Collars,XO, XO. BHA Lenght=601.79'. 14:00 - 14:30 0.50 PULL P DECOMP Service Top Drive, Blocks, Iron Rough Neck, and Draworks. 14:30 - 15:30 1.00 PULL P DECOMP RIH wlCutter BHA to 602'. 15:30 - 18:30 3.00 PULL P DECOMP RIH With Drill Pipe to 9,028'. To Just Above Tubing Fish at 9,057' 18:30 - 20:00 1.50 PULL P DECOMP Obtain Parameters: Up Weight= 176,000#, Down Weight= 152,000#, Rotating Weight= 165,000#, 30 rpm, 3,500 Ft-Ibs of Free Torque, Locate Collar and Cut Tubing at 9,334'. 20:00 - 21 :00 1.00 PULL P DECOMP Circulate Bottoms Up at 12 bpm w/2,450 psi, Slight Gas Cut Returns on B/U. 21 :00 - 00:00 3.00 PULL P DECOMP POOH to 1,500' 5/7/2007 00:00 - 00:30 0.50 PULL P DECOMP Continue to POOH wlWash Pipe Outside Cutter BHA f/1 ,500'. 00:30 - 01 :00 0.50 PULL P DECOMP Stand Back Drill Collars, Lay Down Junk Basket. No Recovery 01 :00 - 01 :30 0.50 PULL P DECOMP P/U Spear to Fish Tubing Out of Wash Pipe. Latch Fish and Pull 32' of Tubing. Tubing Showed Signs of Wash Pipe Shoe Cutting into Tubing and Cut Tubing Connection After First Jt. 01 :30 - 02:30 1.00 PULL P DECOMP P/U 1jt DP and M/U Spear to Retrieve Tubing In Wash Pipe. Latched and Retrieved Remainder of Tubing. UD Spear Assembly. A Total of Three Joints of Tubing Sliced through Tubing Wall. 02:30 - 03:00 0.50 PULL P DECOMP RlU Tubing Handling Equipment. POOH w/Remainder of Tubing and UD Same. Total Lenght of Fish = 277.76', 6-Full Joints and 1-Cut Joint. 03:00 - 03:30 0.50 PULL P DECOMP RID Tubing Handling Equipment. Double Stack Tongs, Elevators, False Table, and Slips. 03:30 - 04:00 0.50 PULL P DECOMP Stand Back Wash Pipe In Derrick. 04:00 - 05:00 1.00 PULL P DECOMP M/U Wash Over Assembly, BHA Consists of: Wash Over Shoe, 10 Jts Wash Pipe, Wash Over Junk Basket, Bumper Sub, Oil Jar, Pump Out Sub, XO, 9-6 1/4" Drill Collars, XO, XO, BHA Lenght = 619.59'. 05:00 - 09:30 4.50 PULL P DECOMP RIH w/4" HT-38 Drill Pipe to 9,330'. 09:30 - 10:00 0.50 PULL P DECOMP Obtain Parameters: Up Weight=180,000#, Down Printed: 5/14/2007 10:50: 11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-03A 06-03A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 4/30/2007 Rig Release: 5/11/2007 Rig Number: Spud Date: 1/2/1976 End: 5/7/2007 09:30 - 10:00 0.50 PULL P DECOMP Weight=156,OOO#, 7 bpm w1760 psi, 10:00 - 10:30 0.50 PULL P DECOMP Continue RIH, Tagged Fish at 9,335' Swallow Fish and Slack Off With Out Pumping to 9,647'. 10:30 - 12:00 1.50 PULL P DECOMP Circulate Bottoms Up, 12 bpm w/2,700 psi. On BIU Returns Contained Sand and Scale, Slightly Gas Cut. Monitor Well. 12:00 - 14:30 2.50 PULL P DECOMP POOH to BHA. 14:30 - 15:30 1.00 PULL P DECOMP Stand Back Drill Collars, Clean Junk Basket, Recovered 2 gallons of Metal Cuttings. Stand Back Wash Pipe, Wash Pipe Shoe Condition Like New. 15:30 - 16:00 0.50 PULL P DECOMP Service Top Drive and Blocks. 16:00 - 17:00 1.00 PULL P DECOMP Wait on Orders From Anchorage, Held Rig Evacuation Drill. 17:00 - 17:30 0.50 PULL P DECOMP M/U Over Shot Assembly, BHA Consist of: Cut Lip Guide, Over Shot Bowl, Top Extension, Top Sub, Bumper Sub, Oil Jar, Pump Out Sub, XO, 9 - 6 1/4" Drill Collars, XO, XO. BHA Lengh 309.32'. 17:30 - 20:00 2.50 PULL P DECOMP RIH to Top of Fish at 9,335'. 20:00 - 20:30 0.50 PULL P DECOMP Obtain Parameters: Up Weight=180,OOO#, Down Weight=165,000#, Rotating Weight=165,000#, 20 rpm, Torque= 1,500 to 2,000 ft-Ibs, 3 bpm, 185 psi on Pump. Slacked Off and Latched Fish at 9,335', Picked up 10,000# on Weight Indicator. Tubing Free From Wireline Power Jet Cut at 9,780'. 20:30 - 23:00 2.50 PULL P DECOMP CBU at 12 bpm w/2550 psi, on Bottoms Up Slight Gas Cut, Heavy Sand Returns. Pumped 20 bbl Hi-Vis Sweep. Heavy Sand and Cement and Gel Returns with Sweep. Continue to Circulate to Clean Well Bore. 23:00 - 00:00 1.00 PULL P DECOMP Monitor Well, Blow Down Top Drive, POOH to 8,575'. 5/8/2007 00:00 - 02:30 2.50 PULL P DECOMP Continue to POOH from 8,575' with Overshot Grapple BHA and remainder of TBG Fish. Stand back 4" HT-38 Drill Pipe in Derrick. 02:30 - 03:00 0.50 PULL P DECOMP POOH with BHA #8. Stand back 3 Stands of Drill Collars in Derrick. 03:00 - 03:30 0.50 PULL P DECOMP RIU Double Stack Tongs, Change Elevators and Slips to Handle Tubing. 03:30 - 06:00 2.50 PULL P DECOMP Lay Down 9 full Joints of 5-1/2" Tubing and Two cut Joints. Total Lenght= 420.65'. Tubing had what appeared to be Cement and Gel on the 9 Joints layed down. Break out and lay down Spear, Overshot and Washpipe. 06:00 - 06:30 0.50 PULL P DECOMP Clear and Clean Rig Floor. 06:30 - 08:00 1 .50 CLEAN P DECOMP Pick up Dress Off BHA Assembly (BHA #9) consisting of 5-1/2" Dressing Mill, (2) Washpipe Extentions, Washover Boot Basket, Double Pin Sub, (2) Boot Baskets, 9-5/8" CSG Scraper, Bit Sub, Bumper Sub, Jars, Pump Out Sub, X/O Sub, (3) Stands 6-1/4" Drill Collars from Derrick, X/O Subs to HT-38 Drill Pipe. Total Length of BHA #9= 336.83' 08:00 - 12:00 4.00 CLEAN P DECOMP RIH with Dress Off Assembly on 4" HT-38 Drill Pipe from Derrick to 7036'. 12:00 - 13:00 1.00 CLEAN P DECOMP Slip and Cut Drill Line. 13:00 - 13:30 0.50 CLEAN P DECOMP Continue RIH with Dress Off Assembly on 4" HT-38 Drill Pipe from Derrick from 7036' to 9338'. 13:30 - 14:30 1.00 CLEAN P DECOMP Pick up HES Storm Packer and RIH with 1 Stand of Drill Pipe from Derrick to 9434'. Set HES Storm Packer. Test Storm Printed: 5/14/2007 10:50: 11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-03A 06-03A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 4/30/2007 Rig Release: 5/11/2007 Rig Number: Spud Date: 1/2/1976 End: 5/8/2007 13:30 - 14:30 1.00 CLEAN P DECOMP Packer to 1000 psi. Hold test for 15 Minutes. Good Test. 14:30 - 16:00 1.50 CLEAN P DECOMP Pull Wear Ring and Set Test Plug. RlU BOP Testing Equipment. 16:00 - 20:00 4.00 CLEAN P DECOMP Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was held for 5 Minutes. AOGCC witness of Test was waived by Bob Noble. Test was witnessed by the Doyon Toolpusher and BPX WSL. Test #1- Annular Preventer, HCR Kill, and HCR Choke Test #2- Manual Kill, Manual Choke, and Lower IBOP Test #3- Choke Valves 1,12,13, and 14 Test #4- Pipe Rams with 4" Test Joint Test #5- Choke Valves 9, 11, and Blind Rams Test #6- Choke Valves 5,8, and 10 Test #7- Choke Valves 7,6,4, and TIW Valve Test #8- Choke Valve 2 Test #9- Choke Valve 3 Accumulater Test- 2,900 psi Starting Pressure, 1,850 psi after first actuation. First 200 psi Recovery in 20 seconds. Full Pressure in 1 Minute and 12 Seconds. 5 Nitrogen Bottles at 2,000 psi. 20:00 - 00:00 4.00 CLEAN N RREP DECOMP Change out Dart Valve, Saver Sub, and Upper IBOP. 5/9/2007 00:00 - 01 :30 1.50 CLEAN P DECOMP Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was held for 5 Minutes. AOGCC witness of Test was waived by Bob Noble. Test was witnessed by the Doyon Toolpusher and BPX WSL. Test #10- Pipe Rams with 5-1/2" Test Joint and Upper IBOP Test #11- Dart Valve Accumulater Test- 2900 psi Starting Pressure, 1,850 psi after actuation. First 200 psi Recovery in 20 Seconds. Full Pressure in 1 Minute and 12 Seconds. 5 Nitrogen Bottles at 2,200 psi. 01 :30 - 02:00 0.50 CLEAN P DECOMP RID BOP Testing Equipment, Pull Test Plug, Drain Stack and Blow Down Lines. 02:00 - 06:00 4.00 WHSUR P DECOMP PIU Pack Off Running Tool and "J" into Pack Off. De-energize Pack Off with left hand Torque. BOLDS. Pull Pack Off free at 20,000Ibs. Install new 9 5/8" Pack Off. Test Pack Off to 5,000 psi for 30 minutes as per FMC procedure. Good Test. Replace all Lock Down Screws and Packing in FMC 13 5/8" 5M Gen I Tubing Spool. 06:00 - 06:30 0.50 WHSUR P DECOMP PIU HES 9 5/8" RTTS retrieval tool and release RTTS. UD RTTS retrieval tool and RTTS. 06:30 - 07:00 0.50 CLEAN P DECOMP RIH to 9,740'. Establish Parameters, Up Weight 190,000#, Down Weight 157,000#, Rotating Weight 175,000#, Rotating Torque 5,000 ftllbs at 60 rpm, 920 psi pump pressure at 7 bpm. 07:00 - 08:30 1.50 CLEAN P DECOMP Wash down and tag Tubing Stub at 9,756'. Dress Tubing Stub to 9,757'. Rotate over Tubing Stub 3 times. Slide over Tubing Stub 2 times without rotating or pumping, no problems getting over Tubing Stub. Rotate and Reciprocate 9 5/8" Casing Scraper across packer setting area at 9,665'. Make 6 passes 70 rpm and pumping 7bpm with 920 psi. 08:30 - 10:30 2.00 CLEAN P DECOMP RlU to reverse circulate. Pump 40 bbl High-Vis sweep, displace well with 720 bbls of clean 120 degree 8.5 ppg seawater. 10 bpm with 2,400 psi pump pressure. Printed: 5/1412007 10:50:11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-03A 06-03A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 4/30/2007 Rig Release: 5/11/2007 Rig Number: Spud Date: 1/2/1976 End: 519/2007 10:30 - 11 :00 0.50 CLEAN P DECOMP RID reverse circulating head. Break circulation conventionally. 11 :00 - 12:00 1.00 CLEAN P DECOMP Test 9 5/8" Casing to 3,500 psi for 30 minutes. Good Test. 12:00 - 17:30 5.50 CLEAN P DECOMP POOH laying down 4" HT-38 DP to 2,234' 17:30 - 18:30 1.00 CLEAN P DECOMP RlU and test 9 5/8" Casing and 9 5/8" FO's at 2,234' to 1,500 psi for 15 minutes. Good Test. 18:30 - 20:00 1.50 CLEAN P DECOMP POOH laying down 4" HT-38 DP from 2,234' to 336' 20:00 - 22:00 2.00 CLEAN P DECOMP UD Dress Off Assembly. Positive indication that mill was on Tubing Stub. 22:00 - 22:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor, Pull Wear Bushing. 22:30 - 23:30 1.00 RUNCO RUNCMP RlU compensator, tubing tongs, torque turn and handling equipment for running 5 1/2" tubing. 23:30 - 00:00 0.50 RUNCMP Hold PJSM with all personnel and P/U 9 5/8" x 5 1/2" Unique Overshot assembly. 5/10/2007 00:00 - 13:30 13.50 RUNCMP Run 51/2", 17#, 13Cr80 Vam Top HC Tubing to 9,739' using compensator and Torque Turning all connections. BakerLok all connections below packer. Use Jet Lube Seal Guard pipe dope, Average M/U torque of 6,580 ftllbs. 13:30 - 14:00 RUNCMP Establish Parameters, Up Weight 195,000#, Down Weight 148,000#. Tag top of tubing stub at 9,759'. Slide over tubing stub, observed overshot pins shear out at 5,000# weight. No-Go on tubing stub. P/U and verify tag on tubing stub. Space out to land 3' off of tubing stub. Swallowed 6' of tubing stub. Ran a total of 237 joints of 5.5" tubing. 14:00 - 15:00 1.00 RUNCMP M/U 13.625" x 5.5" FMC tubing hanger and landing joint. Land tubing hanger. 15:00 - 16:00 1.00 RUNCMP Run in Lock Down Screws. Torque to 425 ftllbs as per FMC procedure. 16:00 - 20:30 4.50 RUNCMP RlU and reverse in 230 bbls of 140 degree 8.5 ppg seawater followed by 430 bbls of 120 degree 8.5 ppg seawater with corrosion inhibitor. 270 psi at 3 bpm. 20:30 - 22:30 RUNCMP Drop 1 7/8" Ball and Rod. Pressure up tubing to 3,500 psi to set packer and test tubing for 30 minutes. Good test. Bleed tubing pressure to 1,500 psi. Pressure up on 5.5" x 9.625" annulus to 3,500 psi for 30 minutes. Good test. Bleed off tubing pressure at 600 psi DCR valve sheared. Pump through DCR valve both ways at 3 bpm with 200 psi pump pressure. 22:30 - 23:00 0.50 WHSUR P RUNCMP Install FMC type IS BPV and test from below to 1,000 psi for 10 minutes. Good test. BPV was installed by FMC service tech. 23:00 - 00:00 1.00 WHSUR P RUNCMP Blow down and unhook lines. Pump out BOP stack. Nipple down Flow Riser. 5/11/2007 00:00 - 01 :00 1.00 WHSUR P RUNCMP N/D BOPE and stand back on pedestal. 01 :00 - 03:00 2.00 WHSUR P RUNCMP N/U Adaptor flange, Test neck seals to 5,000 psi for 30 minutes. Good test. 03:00 - 04:00 1.00 WHSUR P RUNCMP N/U 6" Cameron 5M Tree. 04:00 - 05:00 1.00 WHSUR P RUNCMP RlU DSM Lubricator. Pull BPV and install Tree Test Plug. 05:00 - 06:00 1.00 WHSUR P RUNCMP RlU and test tree to 5,000 psi for 30 minutes. Good test. 06:00 - 06:30 0.50 WHSUR P RUNCMP RlU DSM Lubricator. Pull Tree Test Plug. 06:30 - 07:30 1.00 WHSUR P RUNCMP PJSM with all personnel involved. RlU Little Red Services and pressure test lines to 3,000 psi. 07:30 - 09:00 1.50 WHSUR P RUNCMP Pump 135 bbls of 90 degree diesel freeze protect down IA taking returns out the tubing. 425 psi pump pressure at 2.2 bpm. 09:00 - 10:30 1.50 WHSUR P RUNCMP RlU Lines and U-Tube diesel freeze protect between tubing Printed: 5/14/2007 10:50:11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-03A 06-03A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 4/30/2007 Rig Release: 5/11/2007 Rig Number: Spud Date: 1/2/1976 End: 5/11/2007 09:00 - 10:30 10:30 - 11 :00 1.50 WHSUR P 0.50 WHSUR P 11 :00 - 12:00 1.00 WHSUR P RUNCMP and IA. RUNCMP Set FMC type ISA BPV and test from below to 1,000 psi. Good test. RUNCMP RID lines. Remove double annulus valve and secure tree. Rig released at 12:00 hrs. Printed: 5/14/2007 10:50:11 AM .. " 1REE= FM:: WELLH~D= FM:: GEN 1 AClUA TOR = AX 8.. SON KB. 8..BI = 60' BF. 8..EV = ? KOP= 2900' Max Angle = 91 @ 10909' Datum I\Æ) = 10445' Datum lVD = 8800' SS 06-03A I SAF.TES: FROM DRLG - DRAFT 13-318" CSG, 72#, M\I-80, D = 12.347" 5-1/2"lBG, 17#, 13CR80, ,0232 bpf, D =4.892" 9762' TOPOF3-1/2" LNR- CT, ID=2.992" 5-1/2"TBG-FC, 17#, L-80, .0232 bpf,lD =4.892" H 9890' 9-5/8" CSG, 47#, M\I-80, ID = 8.681" PERFORATION SUM\IIARY REF LOG: BI-CSON01/29176 ANGLEA TTOP ÆRF: 86 @ 10814' I\bte: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10814-10854 C 01/23/01 2-1/8" 4 10854-11070 C 10/07/95 DATE 1976 10/07/95 09/30/03 09/06/04 09/15/04 05/18/06 REV BY COM\ll8'JTS ORIGINAL COM PLETION LAST WORKOVER JLVTLH GL V C/O JLJlTLP RJLL POGLM @ 3809' lMN'TLP ASH - IBP RUBBERS RLM'TLH PA TCH w /FDGLM SET" 05/13/06) DATE 06117/06 08103106 05111/07 06101/07 REV BY COM\llENTS DAVIfLH MN ID&PATCHCORRECIDNS RLMiPJC SET" BKR IBP 9873' IPAG DRLG DRAFT CORRECTIONS CJN/PAG GLV C/O (05/29/07) . 2093' ST MD lVD 4 3272 3261 3 6510 5752 2 8099 6941 1 9556 8119 9637' 9668' 9702' 9762' 9807' 9822' 9828' 9890' 9861' 5-1/2" I-ESX NIP, ID= 4.562" GAS LFT M<\NDRELS ŒV ìYÆ VLV LATCH 18 M\IIG DOME RK 44 M\IIG SO RK 39 M\IIG DMY RK 33 M\IIG DMY RK PORT [)/\ TE 16 OS/29/07 20 OS/29/07 o 05/11/07 o 05/11/07 5-1/2" I-ESX NIP, ID= 4,562" 9-518" X 5-1/2" BAKERS-3 A<R 5-1/2" HES X NP, ID = 4,562" UI\IQl.E M<\CHINE OVERSHOT 9-5/8" X 5-1/2" BAKER SB-3 PKR 5-1/2" PBR DEPLOY SUB WIG FN, ID= 3.0" 5-1/2" X 3-1/2" XO, ID = 2.992" 1-11/16" BKR IBP (08/03/06) 5-1/2" 011S XN NIP (B8-IIND CT), ID -4.455" 5-1/2" TUBING TAIL (BEHNDCT) HELMDTTLOGGED09/02187 I 9-5/8" WINDOW 3-1/2" DAVIS LYNCH FLOAT SHOE 3-1/2" LNR- CT, 9,3#, L-80 FLRS, ,0072 bpf, ID= 2,992" FRLDHOE BAY UNIT WELL: 06-03A PERMIT No: '1951520 AA No: 50-029-20186-01 SEC 1, nON, 14E, 3566.4'FEL& 886.86'Ff\JL BP Exploration (Alas ka) nc oranp. 1. Operations Performed: Abandon 0 RepairWellŒ Pluç Perforations 0 Stimulate 0 Otherl!JSecure Well Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved Program 0 Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œl ExploratoryD 195-152 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-20186-01-00 7. KB Elevation (ft): 9. Well Name and Number: 60.00 06-03A 8. Property Designation: 10. Field/Pool(s): ADL-028311 Prudhoe Bay Field 1 Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11155 feet true vertical 9005.0 feet Plugs (measured) 1-11/16" BKR IBP @ 9873 (08/03/2006) Effective Depth measured 11097 feet Junk (measured) IBP Rubbers (09/15/2004) true vertical 8991.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 30 - 110 30.0 - 110.0 SURFACE 2701 13-3/8" 72# MN-80 29 - 2730 29.0 - 2730.0 4930 2670 PRODUCTION 10452 9-5/8" 47# MN-80 & 28 - 10480 28.0 - 8888.3 6870 4760 500-95 8150 5090 LINER 1327 3-1/2" 9.3# L-80 9828 - 11155 8347.0 - 9057.7 10160 10530 Perforation depth: SCANNED SEP 2 Ü 2DOB Measured depth: 10814-10854,10854-11070 True vertical depth: 8979-9032,9032-8988 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 @ 27 - 9890 Packers & SSSV (type & measured depth): 5-1/2" Patch @ 3805 - 3840 5-1/2" Baker SB-3 Packer @ 9807 12. Stimulation or cement squeeze summary: RBDMS BFt. SEP Intervals treated (measured): .. 8 2006 J Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubinç Pressure Prior to well operation: 51 0 0 --- -- Subsequent to operation: 51 0 0 720 250 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development 00 ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr ~ /I Title Petroleum Engineer Signature A~_. ."f~~j/ ~ Phone 564-5174 Date 9/11/06 D ~ . ~ Form 10-404 Revised 4/2004 V \\\ U I PJ/\ L. f.f( 9) /~cG STATE OF ALASKA . SEP 1 4 2006 ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA 1~~ Gas Cons. Commission A h . RECEIVED . . 06-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/03/2006 T/I/O=470/990/150. Temp. SI. WHP'S. (post bleed secure). TP increased 220 psi overnight. lAP increased 270 psi overnight. OAP increased 90 psi overnight. 09/02/2006 T/I/O=1000/1280/60 Temp=SI Bleed WHPs < 300 psi (Eval Secure). Well is natural producer. IA FL @ 126', TBG FL near surface. Bled lAP from 1280 psi to 700 psi in 4 hours (gas and fluid). For the next 2 hours the lAP would not bleed down past 700 psi (40 bbls returned to gas buster tank #0-27). TBG pressure tracked the lAP, then decreased below the lAP from 1000 psi to 220 psi in 6 hours. Monitor for 30 minutes. TBG pressure increased 30 psi and the lAP increased 20 psi. Final WHPs=250/720/60 08/06/2006 MIT OA TO 3000 PASSED Pumped 4 bbls crude to reach test pressure OA lost 200 psi in first 15 min bumped up pressure to 3000 OA lost 120 psi in first 15 min and 30 psi in second 15 min for a good test bleed off pressure rig down FWHP=1520/1800/175 08/05/2006 T/l/O=1650/1960/150 MIT TBG TO 3000 Pumped 6 bbs to reach test pressure IA tracked up with tbg failed first test on second attempt tbg and IA passed CMIT to 3000 psi. 08/04/2006 CMIT TxlA, PASS (Eval TxlA comm) Pumped 50 bbls down TBG while bleeding gas off lA, CMIT TxlA 3000 psi, Loss of 60/20 psi 1 st 15 min. Loss of 2010 psi 2nd 13 min. PASS. Bled WHP's. Final WHP's=2050/2200/200 08/03/2006 LOG CORRELATED TO TUBING TALLY. IBP SET DEPTH 9873 FT. CCL SET DEPTH 9855.8 FT, CCL TO ME WAS 17.2FT. 1.69" BAKER OIL TOOL RETRIEVABLE PLUG. 200# DOWN JAR TO EQUALIZE AND 5520# UP JAR TO RELEASE. oVERALL LENGTH OF PLUG 8.17FT AND 1.188" FISHING NECK. NEED 1 1/2 PULLING TOOL. 2 SEALING ELEMENTS AND 1 STIFFENER RING. SUPPLIED CORRELATION LOG WAS OFF DEPTH, DATED 22 JUNE 2004. 08/03/2006 T/I/O=2175/2120/180 Load tubing I Load IA (Eval TxlA comm.) - Load IA wi 245 bbls crude, Load tubing wi 180 bbls crude Standby for E-Line to set IBP, pump 97 bbls to Pressure up TBG & IA to 3000 psi, CMIT TxlA ***PASS*** Loss of 160/0 first 15min, loss of 010 psi 2nd 15 min. Bleed down TxlA, 08/02/2006 ***WELL S/I ON ARRIVAL *** (DRIFT FOR IBP) DRIFT WI 1.875" STEM & 1.5" CENTRALIZER TO 10,000' SLM (TARGET DEPTH @ 9840') NO OBSTRUCTIONS ***WELL LEFT S/I*** 07/31/2006 TIIIO = 2180121101200. Temp = SI. T & IA FLs (pre IBP). Tubing FL @ 7620' (below sta #1). IA FL @ 7225' (above sta #1). 07/24/2006 T/I/O=2250/2270/200 Temp=SI TIFL FAILED (Eval high lAP, DSO call in, 07/23). Well was shut in upon arrival and is a natural producer. InitiallA FL @ 7342' St# 2 (322 bls). Bled lAP to production from 2270 psi to 1600 psi in 3 hours. lAP will not bleed down. Shut in and monitor for 1 hour. lAP increased 350 psi to 1950 psi. TBGP & OAP remained unchanged. IA FL unchanged during lAP bleed and post monitor. ** An anomaly kept showing up @ 6020'** Final WHPs=2250/1950/200 07/17/2006 TestEvent --- BOPD: 817 BWPD: 211 MCFPD: 22,435 AL Rate: Page 1 . . 06-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/16/2006 T/I/O=1800/260/200. Temp=SI. WHP's Post-TIFL (Post-GL Straddle). TBGP decreased 70 psi, & the OAP decreased 10 psi overnight. 05/15/2006 T/I/O=60/240/180 Temp=SI Cold TIFL PASSED (post-GL straddle). TBG FL @ surface. IA FL @ 516'. Stacked out TBG with AIL from Well# 4 to 1920 psi in 120 minutes (warm gas). While stacking out the TBG the lAP increased 20 psi to 260 psi and the OAP increased 30 psi to 210 psi. IA FL dropped 12' to 504' post TBG stack out. Monitor for 1 hour. TBGP decreased 50 psi while the lAP & OAP remained unchanged. IA FL remained unchanged post monitor. **Note called valve crew to service swab valve as grease port started leaking gas. (leak repaired, completed)**. Final WHPs=1870/260/210. 05/13/2006 SET 5.5" WEATHERFORD ECLIPSE PATCH AT 3805' - 3840'. TIE-IN LOG IS SLB LDL DATED 22-JUN-04. RIGGED UP. 05/13/2006 SET PATCH FROM 3805'-3840' AS PER PROGRAM.TIED INTO SLB LDL LOG DATED 6- 22-04. USED GR/CCL TO CORRELATE FIRST RUN. TIED DEPTH BACK TO SSSV. SLACKED OFF 200 POUNDS TO CONFIRM SET OF EACH PACKER. ** Job complete 05/03/2006 T/I/O=80/290/170. Temp=SI. T, IA & OA FL's for E-line (pre-patch). T FL @ 50' «2 bbls). IA FL @ 500' (22 bbls). OA FL @ 36' (2 bbls). **Note** IA integral installed. FLUIDS PUMPED BBLS 7 Diesel m PT Surface Equipment 583 Crude 590 TOTAL Page 2 TREE = FMC WB..LHEAD = FMC GEN 1 . ACTUATOR = AXELSON KB. B..EV = 60' BF. B..EV = ? KOP = 2900' Max Angle = 91 @ 10909' Datum MD = 10445' Datum lVD = 8800' SS 113-3/8" CSG, 72#, MN-80, ID = 12.347" I Minimum ID = 1.992" @ 3824' 5-1/2" WFD GL STRADDLE w/2-3/8" McMURRAY GLM TOPOF 3-1/2" LNR- CT, ID = 2.992" I 9828' 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" H 9890' I 9-5/8" CSG, 47#, MN-80, ID = 8.681" I PERFORA TION SUMMARY REF LOG: BHCS ON 01/29/76 ANGLE AT TOP PERF: 86 @ 10814' Note: Refer to Produetion DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2" 4 10814 - 10854 C 01/23/01 2-1/8" 4 10854-11070 C 10107/95 DATE 1976 10/07/95 09/30103 09/06/04 09/15/04 05/18/06 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER JU/TLH GL V C/O JLJ/TLP PULL POGLM @ 3809' TMNlTLP FISH - IBP RUBBERS RUvVTLH PATCH w lPOGLM SET (05/13/06) 06-03A S OTE5: AVA & WFD POGlMSIN WELL. CTD HORIZONTAL SIDETRACK . 2215' -15-1/2" CAMCO BAL-O SSSV NIP, ID = 4.562" I 3805'-3840' ELM 5-1/2" WFD GL STRADDLE, ID = 1.992" (05/13/06) GAS LIFT MANDRELS DEV TYÆ VLV LATCH 30 POGLM DMY BK 42 POGLM DMY BK ST MD lVD 2 3824 3765 1 7342 6363 PORT DATE o 05/13106 o 09/26/03 -1AVA POGLM (02/25/93?), ID = 2.34" I 9807' -- 9-5/8" X 5-1/2" BAKER SB-3 PKR I --i 5-1 12" PBR DEA...OY SUB WIG FN, 10 = 3.0" --i 5-112" X 3-1/2" XO, ID = 2.992" I 9890' 9861' -15-1/2" TUBING TAIL (BEHIND CT) I H B..MD TT LOGGED 09/02/87 I -- IBP RUBBERS 09/15/04 3-1/2" DAVIS LYNCH FLOAT SHOE 3-1/2" LNR - CT, 9.3#, L-80 FLRS, .0072 bpf, ID = 2.992" -1 11155' I DA TE REV BY COMMENTS 06/17106 DAVITLH MIN ID & PATCH CORRECTIONS 08/03/06 RLMlPJC SET BKR IBP@ 9873' PRUDHOE BA Y UNIT WB..L: 06-03A PERMIT No: '1951520 API No: 50-029-20186-01 SEC 1, T10N, 14E, 3566.4' FB.. & 886.86' FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4789' FNL, 1138' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 987' FNL, 4289' FEL, Sec. 1, T10N, R14E, UM At effective depth At total depth 887' FNL, 3566' FEL, Sec. 1, T10N, R14E, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic__ Service__ (asp's 685845, 5941084) (asp's 687877, 5944939) (asp's 688595, 5945056) 6. Datum elevation (DF or KB feet) RKB 60 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-03A 9. Permit number / approval number 195-152 10. APl number 50-029-201 86-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11155 feet 9058 feet Effective depth: measured 1 1090 feet true vertical 9043 feet Casing Length Size Conductor 80' 20" Surface 2670' 13-3/8" Production 10420' 9-5/8" Liner 1328' 3-1/2" Plugs (measured) Junk (measured) Tagged PBTD on 12/14/2000 @ 11090' MD. Cemented Measured Depth True vertical Depth 275 sx PF II 80' 80' 53oo sx AS 2730' 2730' 1600 Sx Class G & 115 SxAS 1 0480' 8888' 14 bbls LARC 11155' 9058' Perforation depth: measured 10814'-10854'; 10854'-11070'. true vertical 9030' - 9032'; 9032' - 9040.' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 9890' MD. Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SB-3 PACKER @ 9807' MD. 5-1/2" CAMCO BAL-O SSSV @ 2215' MD. FEB 0 200! Alaska 0il & Gas Cops. Comrnissio~ Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation(I~17~2001) Subsequent to operation(1/£4/2001) OiI-Bbl 989 1178 Representative Daily Average Production or Iniection Data Gas-Mcr Water-Bbl 20026 317 21364 356 Casing Pressure Tubing Pressure 407 506 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations .__X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. %~-?~,, -('~/~,d'~- Title: DS 6 Surveillance Engineer Signed Deidre Taylor Date JanuaW 30, 2001 Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 06-03A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 12/14/2000: 1/18/2001- 1/23/2001. RIH & loaded well w/1% KCL Water. RIH w/GR/CCL/CNL & logged well to PBTD @ 11090' CTM. RIH w/dummy gun & drifted to 10700' SLM (HAW). MIRU CTE. PT'd equip to 3500 psi. Made 2 CTE conveyed perforating gun runs & shot 40' of add perforations located @: 10814'-10854' MD (Zone 2A) Reference Log: BHCS 1/29/1976. Used 2" carriers & all shots @ 4 SPF, 60° phasing, random orientation, & shot underbalanced press. POOH w/guns - ASF. RD CTE. Placed well BOL & obtained a representative well test. FEB 0 001 Alaska ()ii & ('Sas ('.;ohs. Commission ~nchorage Page I ON OR BEFORE 03 ,00 C:~Om-XM~-DOC D I::! I I.__1__ I IM !~ S I::: i::! ~/II- I~ cl WELL LOG TRANSMITTAL To: State of Alaska June 03, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 06-03A AK-MW-50089 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted magnetic tape with LIS listing. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALA,~,.A OIL AND GAS CONSERVATION COMM~,~..'ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~] GAS [--~ SUSPENDED E] ABANDONED E~ SERVICE E~ 2 Name of Operator 7 Pe~ber~ 5 '~" ARCO Alaska, Inc 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20186-01 4 Location of well at surface ~ . . ........ ~ ....... ~' 9 Unit or Lease Name 489' FSL, 1139' FEL, Sec2, T10N, R14E, UM. : ' ' :~ ~ ' '_/O - ~7~ ~-~ '~ ~'? -'-.~. "i" ,~;~ ' -- PRUDHOE BAY UNIT AtTop Producing Interval .¢ ~-; 10 Well Number 987' FNL, 990' FWL, Sec 1, T10N, R14E, UM. ~ ~:':!~i:~; ~! . ! 6-03A At Total Depth ? ~~ ~,._,:! ~. - 11 Field and Pool 813' FNL, 3575' FEL, Sec 1, T10N, R14E, UM. (revised) PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL 60' RKBI ADL 28311 12 Date9/28/9Spuddeds. 13 Date T.D.10/5/9Reacheds. 14 Date10/7/9C°mP'5. ' Susp. or Aband. 15 WaterN/ADepth, if offshorefeet MSL 16 No. of Completions1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 11155' MD/9005'TVD 11097' MD/8991'TVD YES ~ NO I~l 2215' feetMD 1900' (approx) 22 Type Electric or Other Logs Run GR, MWD Survey. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'TFOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94 # H-40 Surf 80' 32" 275 Sx PF II 13-3/8" 72 # MN-80 Surf 2729' 17-1/2" 5300 Sx AS 9-5/8" 47 # MN-80 & Surf 10480' 12-1/4" 1600 Sx G & 115 Sx AS S00-95 3-1/2" 9.3# L-80 9827' 11155' 4-1/2" 14 bbls Latex Cmt 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) 5.5" Tbg 9890' 9807' 10854 - 11070' M D; 8979 - 8988' TVD @ 4 spf, Zone 2. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 10/17/95. F owing. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 11/6/95. 5.7 TEST PERIOD ¢ - 9855 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY-APl (corr) Press 248 24-HOUR RATE 15 1 39 1370 672 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Notes: i-'~~. '"*" ~' ¢ * 6-03A Coil Tubing Sidetrack Drilling operations summary attached. *This 10-407 submitted as directed per 10-401 approved 9/26/95 (issued Permit #95-152). FEB 0 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10106' 8562' N/A Base Sadlerochit 10733' 9086' 31. LIST OF ATrACHMENTS Summary of 6-03A Coil Tubing Sidetrack Drilling operations. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed//~ C' ~ Title EnqineeringSupervisor Date I''{~[1~'~'" INSTRUCTIONS jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". General: This form is designed for submitting a complete and correct well completion repod and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- ,~ ', , ~ ~ , ;, ,~J .... Form 10-407 6-03A DESCRIPTION OF WORK COMPLETED COIL TUBING SIDETRACK DRILLING & POGLM INSTALLATIONS 9/27/95: MU & RIH w/4.55" milling BHA to mill out the 4.455" XN Nipple at 9848' MD. Milled nipple, but could not get through; POOH w/BHA. MU & RIH w/milling BHA & completed milling nipple. RIH to tag top of cement at 10441' MD. Circulated biozan & drilled pilot hole through cement plug to 10445' MD. 9/28/95: Drilled pilot hole to 10481' MD. POOH w/BHA. MU & RIH w/window milling BHA. started milling window through the 9-5/8" casing at 10480' MD. Oriented & 9/29/95: Milled window from 10480' to 10485.5' MD, then continued drilling formation to 10492' MD. Jetted CCH w/Hi-Vis biozan. 9/30/95: MU & RIH w/drilling BHA. Drilled 4.5" hole to 10503' MD & displaced well to FIo-Pro. Drilled build section to 10635' MD. POOH w/BHA. 1 0/1/95: MU & RIH w/drilling BHA. Drilled to 10640' MD. Backreamed to 10600' MD; orienter quit. POOH w/BHA. MU & RIH w/drilling BHA. Drilled build to 10704' MD. I 0/2/9 5: Completed drilling build section to 10845' MD, then POOH w/BHA. MU & RIH w/drilling BHA. Drilled horizontal section from 10845' to 10915' MD. POOH w/BHA; found hole in CT. I 0/3/95: RDMO CTU. MIRU CTEU. RIH & logged passes w/CBT/GRFFCC from 10900' to 10500' MD. I 0/4/95: POOH w/logging tools. RDMO CTEU. MIRU CTU w/new coil. MU & RIH w/drilling BHA to 10915' MD. Short tripped to 10500' MD, then RIH & resumed drilling to 11035' MD. 1 015 19 5: Drilled to TD at 11155' MD. liner at 11155' MD. POOH w/BHA. MU & RIH w/3.5" blank liner assembly. Set down I 0/6/95: Pumped 14 bbls of 15.8 ppg Latex Cement to set the liner at 9827' - 11155' MD. Displaced cement w/biozan. Landed liner wiper plug on target, released from TOL, and POOH circulating Seawater. RIH w/nozzle & jetted liner w/Seawater to landing collar at 11087' MD. POOH w/nozzle & WOO. I 0/7/95: WOC. RIH w/perforating guns & circulated well to Crude from 10845' MD to underbalance for perforating. Shot 216' of initial perforations in Zone 2 at 10854 - 11070' MD. POOH w/perf guns. RIH w/nozzle to 9800' MD & displaced well to Crude. POOH. ND BOP & NU tree. RDMO. I 0/1 8/95: Ran AVA DWP POGLM & set in the 5-1/2" tubing at 7329' - 7357' MD (seal to seal), then ran & set a second AVA DWP POGLM at 3809' - 3824' MD (seal to seal). POOH. Rigged down. Placed the well on production & obtained valid welltests. 540 - 720 BWPD, & 1100 - 1500 Mscf/D. Latest welltests show 120 - 140 BOPD, CUSTOMER: ARCO AREA: NS-ARCO ~ell Name: DS06-03 Plane Of Vert Section Distance Units used Grid Convergence 80.00 ft -1.410 Computation Method: 1 (Minimum Curvature) Height Of TVD Origin Above Field Datum Dogleg Base Length Used 100 Magnetic Declination 28.310 0.00 MD Inc Dir TVd Vsec ~Lal~ D~e/p~ Build Turn Dleg Tool 10480.0 33.07 43.29 8837.8 2832.2 4001.3 2170.3 0.0 0.0 0.0 10521.0 44.47 46.70- 8869.7 2853.2 4019.3 2188.5 27.8 8.3 28.3 10552.0 49.54 49.30 8890.9 2872.5 4034.5 2205.4 16.4 8.4 17.5 10583.0 54.55 52.00 8909.9 2893.8 4050.0 2224.3 16.2 8.7 17.6 10614.0 59.50 54.60 8926.8 2917.~ 4065.5 2245.1 16.0 8.4 17.4 10647.0 65.04 57.30 8942.2 2943.7 4081.8 2269.3 16.8 8.2 18.3 10675.0 71.20 60.80 8952.6 2967.9 4095.2 2291.6 22.0 12.5 24.9 10705.0 75.50 64.40 8961.2 2995.3 4108.4 2317.1 14.3 12.0 18.4 10738.0 79.01 68.80 8968.5 3026.6 4121.1 2346.7 10.6 13.3 16.8 10771.0 82.62 75.20 8973.7 3058.9 4131.2 2377.6 10.9 19.4 22.0 10804.0 85.43 82.10 8977.2 3091.7 4137.6 2409.8 8.5 20.9 22.5 10846.0 88.70 90.60 8979.3 3133.3 4140.3 2451.6 7.8 20.2 21.7 10877.0 90.10 92.80 8979.7 3163.7 4139.4 2482.6 4.5 7.1 8.4 10909.0 90.80 99.70 8979.4 3194.4 4135.9 2514.4 2.2 21.6 21.7 10923.0 90.10 101.80 8979°3 3207.4 4133.3 2528.1 -5.0 15.0 15.8 10939.0 88.50 103.20 8979.5 3222.2 4129.8 2543.7 -10.0 8.7 13.3 10958.0 87.80 104.40 8980.1 3239.6 4125.3 2562.2 -3.7 6.3 7.3 10971.0 87.50 106.90 8980.6 3251.3 4121.8 2574.7 -2.3 19.2 19.4 11002.0 86.80 110.90 8982.2 3278.4 4111.8 2604.0 -2.3 12.9 13.1 11033.0 85.80 115.30 8984.2 3304.3 4099.6 2632.4 -3.2 14.2 14.5 11059.0 83.60 117.30 8986.6 3325.2 4088.2 2655.6 -8.5 7.7 11.4 11075.0 81.90 117.40 8988.6 3337.8 4080.9 2669.7 -10.6 0.6 10.6 11098.0 79.60 117.30 8992.3 3355.8 4070.4 2689.9 -10.0 -0.4 10.0 11139.0 74.44 115.70 9001.5 3387.9 4052.6 2725.6 -12.6 -3.9 13.1 ~/11151.0 72.90 115.23 9004.9 3397.3 4047.7 2736.0 -12.8 -3.9 13.4 S' .RY-SUN DRILLING SERVICES ~,..//,7-'//~ , PAGE ~..~C~ ~RA.~;~- ~s ~ ~CO A~S~ INC. DATE OF SURVEY: 100 ~ ~' ~' [~,~. MWD SURVEY 500292018601 JOB ~BER: AK-MW-50089 NORTH SLOPE BOROUGH i~sk30~{ & ~r,5 ~ons, gor~m~ss~o{~ KELLY BUSHING ELEV. = 60.00 FT. COMPUTATION DATE: 12/18/:95 A~0ho~aB~ OPE~TOR: ~CO ALAS~ INC TRUE SUB-SEA MEASD VERTICAL ~ERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10480.00 8873.50 8813.50 33 4 N 44.70 E .00 3946.60N 2268.20E 2832.85 10520.79 8905.25 8845.25 44 28 N 48.13 E 28.43 3964.11N 2286.73E 2853.79 10551.67 8926.31 8866.31 49 32 N 50.73 E 17.53 3978.77N 2303.89E 2872.96 10583.54 8945.90 8885.90 54 32 N 53.43 E 17.08 3994.19N 2323.72E 2894.86 10613.94 8962.45 8902.45 59 30 N 56.03 E 17.79 4008.90N 2344.54E 2917.65 10646~69 8977.68 8917.68 65 2 N 58.76 E 18.45 4024.50N 2368.96.E 2944.13 10675.52 8988.43 8928.43 71 11 N 62.27 E 24.14 4037.64N 2392.24E 2969.11 10704.59 8996.76 8936.76 75 30 N 65.79 E 18.82 4049.82N 2417.27E 2995.68 10738.49 9004.24 8944.24 79 0 N 70.18 E 16.33 4062.20N 2447.91E 3027.83 10771.62 9009.53 8949.53 82 37 N 76.69 E 22.25 4071.51N 2479.24E 3060.20 10803.27 9012.83 8952.83 85 25 N 83.54 E 23.28 4076.91N 2510.23E 3091.65 10846.00 9015.03 8955.03 88 40 S 87.97 E 21.25 4078.55N 2552.83E 3134.01 10877.00 9015.27 8955.27 90 26 S 84.57 E 12.35 4076.53N 2583.76E 3164.29 10909.04 9014.92 8954.92 90 47 S 78.88 E 17.79 4071.92N 2615.45E 3194.94 10923.19 9014.82 8954.82 90 5 S 76.77 E 15.71 4068.94N 2629.28E 3208.16 10938.84 9015.01 8955.01 88 30 S 75.36 E 13.58 4065.17N 2644.46E 3222.61 10957.64 9015.61 8955.61 87 48 S 74.13 E 7.53 4060.23N 2662.59E 3239.80 10970.54 9016.14 8956.14 87 32 S 71.67 E 19.16 4056.44N 2674.91E 3251.41 11001.42 9017.65 8957.65 86 50 S 67.63 E 13.26 4045.72N 2703.82E 3278.39 11032.07 9019.60 8959.60 85 52 S 63.23 E 14.67 4033.00N 2731.63E 3303.99 11059.17 9022.09 8962.09 83 34 S 61.30 E 11.03 4020.44N 2755.51E 3325.73 11074.84 9024.07 8964.07 81 54 S 61.13 E 10.71 4012.96N 2769.13E 3338.08 11097.62 9027.73 8967.73 79 37 S 61.30 E 10.04 4002.14N 2788.84E 3355.94 11139.27 9037.07 8977.07 74 26 S 62.88 E 13.00 3983.14N 2824.69E 3388.55 11155.00 9041.29 8981.29 74 26 S 62.88 E .13 3976.23N 2838.17E 3400.85 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4885.25 FEET AT NORTH 35 DEG. 31 MIN. EAST AT MD = 11155 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 81.40 DEG. TIED INTO EASTMAN WHIPSTOCK GYRO SURVEY AT 10480' INTERPOLATED DEPTH 11155' RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC. PBU/6-3A 500292018601 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/18/95 DATE OF SURVEY: 100595 JOB NUMBER: AK-MW-50089 KELLY BUSHING ELEV. = 60.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10480.00 8873.50 8813.50 11155.00 9041.29 8981.29 3946.60 N 2268.20 E 1606.50 3976.23 N 2838.17 E 2113.71 507.21 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. RY-SUI~ DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC. PBU/6-3A 500292018601 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/18/95 DATE OF SURVEY: 100595 JOB NUMBER: AK-MW-50089 KELLY BUSHING ELEV. = 60.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10480.00 8873.50 10609.41 8960.00 11155.00 9041.29 8813.50 3946.60 N 2268.20 E 1606.50 8900.00 4006.71 N 2341.42 E 1649.41 42.91 8981.29 3976.23 N 2838.17 E 2113.71 464.30 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 0 F! I I--I_ I I~1G S E I:! ~./I I:: G S AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 RFC IVED Re: S~vey Data 2-3A, 6-3A December 19, 1995 Dear Mr. Grant, Enclosed are two hard copies of the above mentioned file(s). Well 2-3A MWD survey, tie in point 10,700', window point 10,815', interpolated depth 12,180' Well 6-3A MWD survey, tied into Eastman Whipstock gyro survey at 10,480', interpolated depth 11,155'. Please call me at 563-3256 if you have any questions or concerns. Regards, Sandra Lufldn Dept. Specialist Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9882 Company: 11/15/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 6-3A ~) ~ ) ~"Z.- DUAL BURSTTDT-P 951 029 I 1 D.S. 11-3 ~", ~7l RST 951021 I 1 D.S. 15-36~:]~ '~?_.. DUAL BURSTTDT-P 951023 I I .. S I G N DATE: Please~'~urn one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Well Job # NO. 9899 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay I 1/21/95 Floppy Log Description Date BL RF Sepia DIR MWD Disk D.S. 6-3A ?')~. ~'~- 95348 DUAL BURST.TDT-P MONITOR 951029 1 O.S. 2-13A -~ ?-//~' DUAL BURSTTDT-P 951030 1 1 D.S. 15-5A ~"'3~. DUAL BURST TDT-P 951031 I 1 O.S. 15-8A ~ ?~"l ~('1 DUAL BURST TDT-P 9511 02 I 1 1:).S. 15-9A (~---I 7~ DUAL BURST TDT-P 951107 1 1 ~.S. 15-38 ~ ~.~.._//lc~ DUAL BURST TDT-P BORAX 9 51 1 0 6 I I , D.S. 15-38 / / ,v ! 95359 ' DUAL BURST TDT-P/PROD PROFILE 951104 1 \ I SIGNE Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A~I'N: Sherrie NO. 9880 Company: 11/14/95 BP Exploration Attn: Petrotechnical Data Center 900 E Benson Blvd (MB 3-3) Field: Prudhoe Bay LIS Well Job # Log Description Date BL RR Sepia RF Sepia . Mylar Tape D.S. 2-15 ~-'-,/~ GR/CCL 951017 2 1 D.S. 6-03A~,~"' | ',<~"~ POGLM SETI'ING RECORD 9 51 01 8 2 1 D.S. 7-6~;;~ ~{~ '--71~/I ~-~ PROD PROFILE 951015 2 1 D.S. 13-8' BAKER INFAT BRIDGE PLUG REC 9 S 1 01 5 2 1 D.S. 17-12 ~, 'L.( -52. ~,~ PROD PROFILE 951016 2 1 D.S. 17-14 <~ L/ ] f ! DEFr 951016 2 1 D.S. 17-14 0 / ~ t.~ ~ PROD PROFILE WITH DEFT 95101 6 2 I SIGNED: ~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RFCEIVED NOV 17 1995 Alaska 0il &. ~as Cons, Commission Anchorage GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9793 Company: 10/10/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk / D.S. 6-3A (~'I.~'"'Z-- 95332 CBTSONIC ~'~:~"2-- O ~-_-.,~/(~~' 951003 1 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. TONY KtVOWLE$, GOVERNOR ALASKA OILANDGAS CONSERVATION COM311SSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 26, 1995 Mark Ireland, Engineering Supervisor ARCO Alaska Inc P O Box 100360 Anchorage,-AK 99510-0360 Re:" Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit 6-03A ARCO Alaska lnc 9,,~'152 489'FSL, 1139'FEL, Sec 02, T10N, R14E, UM 717'FNL, 3626'FEL, Sec 01, T10N, R14E, UM Dear Mr. Ireland: 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 ali 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 North 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 OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill g Redrill X lb. Type of Well Exploratory__ Stratigraphic Test Development Oil Re-Entry__ Deepen _ Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 60' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28311 Prudhoe Ba¥/Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.O25) 489' FSL, 1139' FEL, Sec 2, T10N, R14E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 987' FNL, 990' FWL, Sec 1, T10N, R14E, UM. 6-03A #U-630610 At total depth 9. Appro)dmate spud date Amount (Proposed) 717' FNL, 3626' FEL, Sec 1, T10N, R14E, UM. September, 1995 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and property line No Close Approach 2 5 60 11070' M D / 8985' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff de~h 10480' MD Maximum hole angle 88° Maximum surface 3000 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD 'I'VD (include stage data) 4-1/2' 3-1/2" 9.3 L80 FL4S 1230' 9830' 8336' 11100' 8985 25bbls 19. TOpresentbe completedwell conditionf°r Reddll,summaryRe-entry, and Deepen Operations._[;i. L. ...'-~ ,""-, 1: '''~- Total depth: measured 10890 feet Plugs(measured) true vertical 9235 feet c.' i.) Effective depth: measured 10624 feet Junk (measured) true vertical 8994 feet t~i~$~ U[[ ~ Gas CO,tlS. O01~lJ~j~,[orl Anchorage Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 2 0" 275 Sx PF II I 0 9' 1 0 9' ,,~ Surface 2700' 1 3-3/8" 5300 Sx AS 2729' 2729' Production 10842' 9-5/8" 1600SxCIG & 115SxAS 10871' 9219' Perforation depth: measured 10580 - 10690'; 10625 - 10635'; 10644 - 10659' true vertical 8959 - 8967'; 8995 - 9003'; 9Oll - 9024' 20. Attachments Filing fee ~x Property plat __ BOP Sketch ~ Diverter Sketch_ Drilling program ~ Drilling fluid program ~ Time vs depth plot_ 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 Signe~~-~.~~ Titlle Engineering Supervisor Date ~ J~ ~--/~'" Commission Use Only it~u~...b~r I APl number I Appr idate I See cover letter for Perm 1~'~' 50- 0~,-~, "~[~'O1 °C~a' '~.~-.~, ?~'~ other requirements Conditions of approval Samples required __Y e s ~ N o Mud log required ~ Y e s ~ N o Hydrogen suede measures ~ Y e s ~ N o Directional survey required ~Yes Required working pressure for BOP'E ~2M; ~ 3 M' __ 5M- __ 1 0--M' __ I 5 M X 3500 psi forCTU Other: Original Signed By by order of ~"/ *pproved by. David W. Johnston Commissioner the commission Date : ~ ~?¢'" ~n '""/ Form 10-401 Rev. 7-24-89 ~ Submit,in triplica DS 6-3A CT Sidetrack and Completion Intended Procedure Objective' Plugback existing wellbore. Directionally drill a high angle twin well t¥om the existing wellbore. Complete with 3-1/2" cemented liner. Intended Procedure: Cement squeeze the current perforations and plugback the.~existing completion to ~ 10435' md. Mill v, fndow in 9-5/8" casing at -10480' md. Build angle to 88° at 22°/100, to TD. · Directionally drill twin well to access Zone 2 reserves. · Run open hole logs. · Run and cement 3-1/2" liner to TD. · Perforate selected intervals. · Return well to production. ~ia~ka 0t! & Gas Cons. Commission Anchorage September 14, 1995 9-5/8" SB-3 Pkr. 5-1/2" XN nipple 4.455" ID NoGo 5-1/2" Tubing tail DS 6-3A PROPOSED CTD COMPLETION 9807' q877' 9890' ZZ15' 3808' 5-1/2" Tubing 5-1/2" Camco BaI-O SSSV Nipple (4. S62" ID) POGLM's 5-1/2" GS FN on top of liner ~ +_9850' Window Cut in 9-5/8" casing with CT, ~ 10480- 10487' 4-1/2" Open hole 3-1/2" FL4S liner Odginai perforations cement sqz'd. TD @ ± 11100' 9-5/8" Casing Shoe @ C T Drilling Wellhead Detail ~ CT Injector Head ~ Stuffing Box (Pack-Offl, 10,000 psi Working Pressure I' '1 I I 4-1/16' ID CT BOP Stack 10,000 psi Workina Pressure Flanged F~e Res~tant Kelly Hose To Dual ChokeMam/old \ / / Manual VaNe HCR 2' Pump-In ; Blind Rams or Com0ination Cutter/Blinds .~ Cutters or Combination Cutter/Blinds ~~..*:[ Slip rarns ~-~= Pipe rams Drilling spool 7-1/16', 5M by 4ol/16', 10M Annu~a~ BOP (Hydril),7-1/16' ID 5.,300 psi working pressure ,.~" ~-P 2 'Z 1995 Aitgm'ne nt Guide Ram Type Dual Gate BOPE~ Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams Gas 6or~s, Oomrnissior~ Anchorage Manual Valves (3-1/2' Valves) 9' from GL to top o! MV Manual Master Val, 0.4Ea' ($.S'~ ger 9-5/8' Annulus 13-3/8" Annulus h Fire Resistant Kelly Hose to Flange by Hamme~ Up 1/4 Turn Valve on DS Hardlme 10' from Tree Shop J,60~4O J Pump Room Pipe rack Ext, r-CO Dowell Drilling Equipment Tra ilar Preferred Major Equipment Layout for CT Drilling in DS 6-3A Ext. '3~c~on I-TI(IN-K14~ Scale 1 inch: 150 ft 8600 $$~?.8 89OO 8974.2 9O5O Existing Well '\ 2832.2 , Planned Sidetra. ck \ ',. ';., ~.o 1 D122.17'/1~ Tf 42,79' ~i~° MD 1048O -. ";."~. 6~* 2 Hold angl~ and clirecticn ~ ~'~ 7~° 85' MD 10760 ~.0~ 305~6 T~g~ T~ SEP 2 Z 1995 Alaska Oil & Gas Cons. Commission Anchorage Tgt 1 Tgt 2 i . 3 I"D 898&0 TVD .'vD 110'5) Verti~ Section Scale 1 inch; 150 fl: PLANE OF VERT SECTn N80.00E DRTLEX-C:.:qSZER, ~. ' . P. 3.-'4 Dri!ex Sys~em~, !nc. Cuzzcmer : ARCO Alaska Well : DS 06-03 ST ~ocazzo.. : S~L: ?63' FNL & 3932 : Section 1-T10N-R14E : North Slope Borough, No !nZe=polation FEL Alaska Pa~e 1 of Date Sept, 14, 1995 Filenarae : 0603ST Hei~h~ of Area Datum above Customer Datum 0.00 f= Height of Well Datum aJ2ove Area Datum 0.00 ft All TVDs are relative to the Well Datum Level M.DEgTH /kNGLE DIR C\L TVD V/S ft de9 de~ ft ft fU ft 10%80.00 33.07 N43.29:E 0.0C ~837.83 2832.18 4001.29 10500.00 36.43 N48.36~E 20.00 S854.26 2841.62 4009.21 1053~.00 41.8L ~4.59~E 30.00 8877.~4 2858.25 4020.94 10560.00 47.4~ ~ N59.61:E 30.00 8898.89 2877.66 4032.33 10~90.00 53.28 N63.77eE 30,00 8918.02 2899.~9 4043~2~ ft 2170.3zA 2178.52 2193.35 2211.05 2231.39 D'LEG °/100 0.00 22.18 22.18 22,17 22.18 10620.00 59.24 ~67.35~E 30.00 893~.68 2923.74 4053,~4 !0~0.00 65.28 N?0.~0~E 30.00 $948.64 2949.78 4063.06 10680.00 71.38 N73.36~E 30.00 8959.72 2977.37 4071.69 !C7'0.00 77.S2 N76.02oE 30.00 8967.76 ~006.13 4079.31 107%0.00 83,68 ~78.~6:E 30.00 ~972,66 3035.68 4085.81 2254.10 2278.86 230~ .36 2333.22 2362.07 22.17 22.17 22.17 22.18 22.17 10760.98 88.00 NS0.29:E 20.98 8974.18 3056.60 4089.65 !0770,00 88.00 NS0.29e~ 9,02 8974.50 3065.61 4091.17 108DC.00 88.00 N80.29~ 30.0~ 8975.54 3095.60 4095.23 10830.00 88.00 NS0.29oE 30.00 8976.~9 3125.58 4101.28 L0850.00 88.00 NS0.29~E 30.00 8977.64 315~.56 4106.34 2382.64 2391.52 2421.08 2450 _63 2480.18 22.18 0.00 0.00 0.00 0,00 !08~0.00 88.00 N80.29~E 30.00 8978.68 3185.54 4111.40 10920.00 $8.D0 N80.29°]~ 30.0C 8979.73 3215.52 4116.45 !09-~0,00 88.00 .5180 . 290]~ 30.00 ~980.78 3245.50 4121,51 "0980.00 88.00 NS0.29~E 30.0O -a981.83 3275.48 4126.57 i!~I0.00 88.00 NS0.29~E 30.0~ 8982.87 3305.46 4131.62 2509.73 2539.29 2568.84 2598.39 2627.94 0.00 0.00 0.00 0.00 0.00 110'443.00 88.00 NS0.29"E 30.00 8983.92 3335.45 4136.68 11070.00 88.00 N8O.29~E 30.0~ 8984.97 3365.43 4141.74 i1070.~5 88.00 N80.29~E 0,9= 8985.00 ~366.38 4141.90 2657.49 2687.05 2687,98 0.00 0.00 0.00 Orig'-n of Bo~om F. ole Closure ARRA C~,NTRE Botu=m Hole Closure 4938 ft 33.~° ~i deDuhs are Sub- £ea Sur~ys ~o Grid 3Iorth Drilex Systems, inc. · ~us~omer : ARCC Alaska Nell : DS 06-03 ST Location : SILL: 763' P~L & 3932' : SecCion 1-T!0N-R!4E : North Slope ~orough, No interpolation FEL Alaska Pape ' of 1 Date Sept. 14, 1995 Pilenam~ : 63ST AS? Eeigh= of Area Datum above Custo~r Datum 0.00 ft Eeight of Well Datum above A=ea Da=tm 0.00 ft A~I TVDs are rela~iv~ Co the Well Datum Level M. DEPTH ~LE DI~ TVD V/S ASP (x) ASP (Y) 10480.00 33 . 07 ~;43.29°E 8837.8 2832 . 2 688015.6 5945085.5 10500.00 36.43 N48.36~E 8854.3 284]. 6 688023.8 5945093.5 i0530~00 41.81 N54.59oE 8877.5 2858,2 688038.6 ~945105.0 10560.00 47.4~ .~59.6lee 8898.9 2877.7 688056.4 594~116.5 10590.00 ~3.28 N63 . 77"E 8918,0 2899.6 688C76.7 5945127.5 10620.00 59.24 N67.35°E 8934.7 2923,7 688099.4 5945137.5 10650.00 65.28 NU0.500E 8948.6 2949.8 688124.2 5945147.0 10680.00 7!.38 AF73.360E 8959.7 2977.4 688150.7 5945156,0 10710.00 77.52 N76.02°E ~967.8 3006,1 688178.5 5945163.5 10740,00 ~3,68 ~78.56°E 8972.7 ~035.7 688207.4 ~945170.0 10760,98 88,00 NS0.2]"E 8974.2 3056,6 688227.9 5945173.5 10770.00 88.00 NS0.29~E 8974,5 3065.6 688236.8 5945175.5 10800.00 88.~0 NSO.29~E 897~.5 3095.6 688266.% 5945180.5 10830.00 88.00 NS0.29~E 8976.6 3125.6 688295,9 594S185.5 10860.00 88.00 N80.29"E 8977,6 3155,6 688325.5 5945190.5 10890.00 $8.00 NS0.29~E 8978,7 3185.6 688355.1 5945195.5 10920.00 88.00 ~80.29~E 8979.7 3215.5 ~88384.6 5945200.5 10950.00 85.00 NS0,29~E 8980.8 3245.5 688414.L 594520S.5 10980.00 88.00 NS0.29~E 8981,8 327N.5 688443.7 5945210.5 110~0.00 8B.00 NS0.29~E 8982.9 3305.4 688473.3 5945215.5 !I04~.00 88.00 NS0.29~E 898~.9 3335.5 688502.8 5945221.0 11070,00 88.00 NS0.29~E 8985.0 3365.5 688532.4 5945226.0 11070.97 8~.00 ~80,29~E 8985.0 3366.4 ~88533.3 5945226.0 D'LEG °/100 0.00 22.18 22.17 22.18 22,17 22.!7 22.17 22.18 22.17 22.18 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 Orip±n of Bo~uom Hole Closure AREA CENTRE Bo=~om Hole Closure %5984964 f= 6,6':' Ail depths are Sub-Sea Surveys to Grid North Abska Oil & Gas Cons. Corr~mission ^ncb~rage ..... STATE OF ALASKA ALASKA O.__ AND GAS CONSERVATION COIV, .SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend Operation shutdown Alter casing Repair well Plugging X ,. Change approved program Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 489' FSL, 1139' FEL, Sec. 2, T10N, R14E, UM. At top of productive interval 987' FNL, 990' FWL, Sec. 1, T10N, R14E, UM. At effective depth 970' FNL, 1255' FWL, Sec. 1, T10N, R14E, UM. At total depth 690'FNL, 1295' FWL, Sec. 1, T10N, R14E, UM. Vadance 5. Type of Well Development Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate Perlorate Othe'r .. , 6. Datum of elevation(DF or KB) 60 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-3 9. Permit number 75-73 10. APl number 50 - 029-20186 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10890 feet 9235 feet Plugs(measured) Tagged Fill @ 10624' MD (2/21/95) Effective depth' measured 10624 feet true vertical 8994 feet Junk(measured) DUPLICATE Casing Length Size Cemented Measured depth Conductor 80' 20" 275 Sx PF II 109' Surface 2700' 13-3/8" 5300 Sx AS 2729' Production 10842' 9-5/8" 1600 Sx CIG & 115 Sx AS 10871' True vertical depth 109' 2729' 9219' Perforation depth: measured 10580 -10590'; 10625 -10635'; 10644 - 10659' true vertical 8959' - 8967'; 8995 - 9003'; 9011 - 9024' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9890' MD. Alaska Oil & Gas Cons. Co~rniss[on Anchorage Packers and SSSV (type and measured depth) Baker SB-3 Packer @ 9807' MD; 5-1/2" Camco BaI-O SSSV @ 2215' MD. 13. Attachments Description summary of proposal x.L Detailed operations program w BOP sketch , 14. Estimated date for commencing operation August, 1995 16. If proposal was verbally approved Oil x Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~,~~ ~ Title Engineering Supervisor ~,v,) FOR COMMISSION LI.~E ONLY Conditions of approval: Notify/(2dmmission so repre;,s.entative may witness Plug integrity ,./ BOP Test v- Location clearance Mechanical Integrity Test .. 15. Status of well classification as: Gas Approved by order of the Commissioner Suspended . Date IApproval No. (:~,~-_,_ Subsequent form required 10- ~t '-'~approved Copy _ F~turned ~ David W. Johnston L;Omrd~smoner - Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST COMPANY .i PROGRAM: exp [] der [] redrll~ aery [] ADMINISTRATION INIT CLASS~ UNIT# ON/OFF SHORE ~.~ ENGINEERING 1. Permit fee attached .................. Y N 2. Lease number appropriate ................ Y N 3. Unique well name and number .............. Y N 4. Well located in a defined pool ............ Y N 5. Well located proper distance from drlg unit boundary. Y N 6. Well located proper distance from other wells ..... Y N ' 7. Sufficient acreage available in drilling unit ..... Y N 8. If deviated, is wellbore plat included ........ Y N 9. Operator only affected party. Y N 10. Operator has appropriate bond in force. Y N 11. Permit can be issued without conservation order .... Y N 12. Permit can be issued without administrative approval..I.Y N 13. Can permit be approved before 15-day wait..~ N 14. Conductor string provided ................ y N'~ ~] p~.~. 15. Surface casing protects all known USDWs ......... Y ~ .... 16. CMT vol adequate to circulate on conductor & surf csg.. Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved.~ N 22. Adequate wellbore separation proposed .......... Y~ N 23. If diverter required, is it adequate .......... .~---~ 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate ............ ~ ........ ~ N 26. BOPE press rating adequate; test to ~~ pstg. Y~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~---_N,-/~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/ 32. Seismic analysis Qf shallow gas zones .......... 33. Seabed condition survey (if off-shore) ....... 34. Contact name/phone for weekly progress reports . ./.. Y N [exploratory only] GEOLOGY,. ENGINEERING: CO~MMISSION: TAB C~mments/Instructions: HOW4o - A:%FORMS%cheklist 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. Tape Subfile 2 is type: TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NIIMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 6649.00 B. JAHN MOONEY/HUPP D.S. 6-03A F?~( 500292018601 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 29-MAY-96 MWD RUN 3 B. JAHN MOONEY MWD RUN 4 B. JAHN GOODR I CH MWD RUN 6 JOB NUMBER: 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 WORTHINGTON MOONEY MWD RUN 7 WORTHINGTON GOODRICH MWD RUN 8 2 I0N 14E 489 1139 OPEN HOLE CASING WORTHINGTON HUPP/BASS 60.00 M (]ROF LMED DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2730.0 9.625 10871.0 5.500 9890.0 4.500 11155.0 MWD - GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. ALL GAMMA RAY DATA WAS DOWNHOLE RECORDED USING THE NATURAL GAMMA PROBE (NGP/SGRD) WHICH UTILIZES A SCINTILLATION DETECTOR. MWD RUNS 2 & 3 WERE MILL RUNS, DIRECTIONAL WITH GAMMA RAY (NGP/SGRD). MWD RUNS 4, 6, 7, & 8 WERE DIRECTIONAL WITH GAMMA RAY (NGP/SGRD). NO DATA IS INCLUDED FROM MWD RUN 5. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 10411.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) (CET log, SWS) EQUIVALENT UNSHIFTED DEPTH MERGE TOP MERGE BASE 10441.0 10481.0 10481.0 10496.0 10496.0 10636.0 10636.0 10845.0 10845.0 10915.0 10915.0 11155.0 all bit runs merged. STOP DEPTH 11133.0 BASELINE DEPTH GR 10508.0 10508.0 10513.0 10513.5 10514 . 5 10515 . 0 10527.5 10531.5 10557.0 10556.5 10558.0 10558.0 10604.0 10607.5 10615.0 10622.0 10624.5 10631.0 10631.5 10634.0 10648.0 10652.5 10652.5 10655.0 10655.5 10657.0 10668.0 10668.0 10673.0 10673.5 10674 . 5 10676 . 5 10677.5 10681.5 10687.5 10689.5 10736.5 10737.0 10739.5 10739.5 10743 . 5 10744 . 5 10750.5 10750.5 10755 . 0 10754 . 5 10758.0 10758.5 10836.0 10836.0 10842 . 0 10844 . 0 10844 . 0 10846 . 5 10853.0 10854.5 10867.5 10868.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MMD 2 MWD 3 MWD 4 MWD 6 MWD 7 MWD 8 $ REMARKS: MERGED PASS. ROP WAS SHIFTED WITH GR. CN WN FN COUN STAT / ? ? SHI FT. OUT $ : ARCO ALASKA INC. : D.S. 6-03A : 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: 18 Tape File Start Depth = 11158.000000 Tape File End Depth = 10408.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4504 datums Tape Subfile: 2 139 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 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 GR 10411.0 $ 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 10453.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP 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. 28-SEP-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10481.0 10441.0 10481.0 0 .0 .0 TOOL NUMBER NGP 168 4.550 9890.0 BIOZAN/SEAWATER .00 .0 .0 0 .0 .000 .0 .000 162.7 .000 .0 .000 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 6-03A : 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 TIP 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: Tape File Start Depth = 10480.000000 Tape File End Depth = 10408.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 436 datums Tape Subfile: 3 Minimum record length: Maximum record length: 65 records... 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NI3MBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10452.0 $ 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 10469.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP 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) : MI/D PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCUIJ~TING TEMPERATURE: MI/D FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 3. 30-SEP-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10496.0 10481.0 10496.0 0 .0 .0 TOOL NUMBER NGP 168 4.550 9890.0 BIOZAN/SEAWATER .00 .0 .0 0 .0 .000 .0 .000 162.7 .000 .0 .000 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 6-03A : 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 NEWD 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: Tape File Start Depth = 10500.000000 Tape File End Depth = 10450.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 4 4808 datums 65 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 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 GR 10460.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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 10607.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP 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 4. 01-0CT-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10636.0 10496.0 10636.0 0 33.1 59.5 TOOL NUMBER NGP 39 4.500 9890.0 FLO- PRO 8.80 60.0 9.4 42000 6.8 .000 .000 .000 .000 .0 145.9 .0 .0 .00 .000 .0 0 CN WN FN COLIN STAT : ARCO ALASKA INC. : D.S. 6-03A : 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: Tape File Start Depth = 10640.000000 Tape File End Depth = 10455.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1550 datums Tape Subfile: 5 68 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape 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: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10600.0 $ 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 10811.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP 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 6. 02-OCT-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 10845.0 10640.0 10845.0 0 65.0 82.6 TOOL NUMBER NGP 168 4.500 9890.0 FLO - PRO 8.80 67.0 9.6 41000 6.2 .000 .000 .000 .000 .0 141.6 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 6-03A : 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: Tape File Start Depth = 10850.000000 Tape File End Depth = 10595.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6342 datums Tape Subfile: 6 70 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10811.0 $ 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 10889.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP 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) : MI/D 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 7. 03-OCT-95 MSC 1.32 DEP 2. 042 / NGP 5.74 MEMORY 10915.0 10845.0 10915.0 0 88.7 90.4 TOOL NUMBER NGP 168 4.500 9890.0 FLO- PRO 8.80 67.0 9.2 40000 6.2 .000 .000 .000 .000 .0 141.6 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA INC. D.S. 6-03A 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 2 ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 10920.000000 Tape File End Depth = 10810.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2214 datums Tape Subfile: 7 66 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10906.0 $ 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 11134.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP 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): FK/D 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 8. 05-0CT-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 11155.0 10915.0 11155.0 0 72.9 90.8 TOOL NUMBER NGP 168 4.500 9890.0 FLO-PRO 8.80 64.0 10.0 41000 5.8 .000 .000 .000 .000 .0 141.6 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 6-03A : 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: 7 Tape File Start Depth = 11158.000000 Tape File End Depth = 10905.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7864 datums Tape Subfile: 8 70 records... Minimum record length: 42 bytes Maximum record length: 1014 bytes Tape Subfile 9 is type: LIS 96/ 5/29 01 **** REEL TRAILER **** 96/ 5/30 O1 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 30 MAY 96 3:02a Elapsed execution time = 1.48 seconds. SYSTEM RETURN CODE = 0 ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 6-3A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292018601 REFERENCE NO : 95348 Date II g/al J ~ . LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 95/11/19 ORIGIN : FLIC REEL NAME : 95348 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, DS 6-3A, PRUDHOE BAY, 50-029-20186-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 95/11/19 ORIGIN : FLIC TAPE NAME : 95348 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, DS 6-3A, PRUDHOE BAY, 50-029-20186-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 6-3A API NUMBER: 500292018601 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 19-NOV-95 JOB NUMBER: 95348 LOGGING ENGINEER: D. WARNER OPERATOR WITNESS: S. WYSOCKI SURFACE LOCATION SECTION: 2 TOWNSHIP: 1ON RANGE: 14E FNL: FSL: 489 FEL: 1139 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 61.00 DERRICK FLOOR: GROUND LEVEL: 28.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (Fl) WEIGHT (LB/FI) ............. .... ......... 9.625 10480.0 3.500 11155.0 9.30 5.500 9890.0 17.00 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUHBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 10868.0 10861.0 10845.0 10843.0 10839.5 10835.5 10816.5 10802.5 10774.5 10751.0 10749.0 10748.0 10733.5 10727.5 10704.5 10689.0 10672.5 10669.5 10666.5 10655.0 10653.0 10646.0 10641.5 10632.0 10629.5 10628.5 10624.0 10613.0 1O597.0 10594.0 10580.0 10555.0 10533.0 10530.5 10525.0 10512.5 10506.0 10501.5 10484.0 10473.5 100.0 $ REMARKS: CBT GR 1 1 04-0CT-95 SCHLUMBERGER WELL SERVICES --EQUIVALENT UNSHIFTED DEPTH GRCH SIGM 10869.5 10869.5 10861.5 10861.5 10847.0 10847.0 10844.0 10844.5 10841.0 10841.5 10836.0 10836.0 10817.0 10817.0 10803.0 10803.0 10775.5 10775.5 10753.5 10750.5 1O750.5 10734.5 10734.5 10729.0 10729.0 10705.5 10705.5 10690.0 10689.5 10674.0 10674.0 10671.5 10667.0 10668.5 10658.0 10658.0 10654.5 10654.0 10646.5 10643.5 10643.5 10634.5 10634.5 10631.0 10631.0 10624.5 10614.5 10614.5 10599.0 10599.0 10595.5 10595.5 10582.0 10582.0 10556.5 10557.0 10534.0 10534.0 10532.0 10532.0 10526.5 10526.5 10514.0 10515.0 10507.5 10506.5 10503.0 10485.0 10485.0 10475.5 101.0 102.0 THE DEPTH CORRECTIONS SHOWN ABOVE REFLECT CASED HOLE PAGE: LIS Tape Verification Listing 19-NOV-1995 14:08 Schlumberger Alaska Computing Center TDTP PASS #1 GAMMA RAY SHIFTED TO OPENHOLE (BASE) GAMMA RAY FROM SCHLUMBERGER CBT TOOL, AND TDTP PASS #1 SIGH SHIFTED TO OPENHOLE (BASE) GAMMA RAY FROM SCHLUMBERGER CBT TOOL. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGH SHIFTS. ALL DATA HAVE A 1.5' BLOCKSHIFT APPLIED FROH TD TO 10868' BECAUSE THE BASE GR. CBT ONLY GOES AS DEEP AS 10873'. $ **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREHENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11051.5 10467.0 TDTP 11076.5 10468.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP $ REMARKS: THIS FILE CONTAINS TDTP PASS #1 DATA. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA LIS Tal~e Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 PAGE: 4 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 6-3A Well Name APIN 500292018601 API Serial Number FL 0489 FSL & 1139 FEL Field Location SECT 2 Section TOWN 1ON Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation WITN S. WYSOCKI Witness Name SON 100227 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 61. Above Permanent Datum EKB FT 61. Elevation of Kelly Bushing ECL FT 28. Elevation of Ground Level TDD FT 11090. Total Depth - Driller BLI FT 11075. Bottom Log Interval TLI FT 10465. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI SBHF SBHN SIGC SIBH TRAT LC01 SDSI BACK FBAC TCAN TCAF TCND TCFD TSCN · TSCF INND INFD GRCH TDT Porosity Borehole Sigma - far detector Borehole Sigma - Near detector Sigma Correction Corrected Borehole Sigma Ration Total Near to Far counts Local Computation 1 Standard deviation of Sigma Background Count Rates - Near Detector Background Count Rate - Far Detector Tota! counts analyzed near detector (TDTP) Total counts analyzed far detector (TDTP) Total capture counts - Near detector Total capture Counts - far dectector Total Selected Counts - Near Detector Total Selected Counts - Far Detector Inelastic count rate - near detector Inelastic count rate - far detector Gamma Ray in Casing LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 DEFI TENS Surface Tension CCL CCL Amplitude GR Gamma Ray in Casing PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ..... ..... I 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** 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 100227 O0 000 O0 0 i i i 4 68 0000000000 SIGM TDTP CU 100227 O0 000 O0 0 1 1 i 4 68 0000000000 TPHI TDTP PU-S 100227 O0 000 O0 0 I I 1 SBHF TDTP CU 100227 O0 000 O0 0 1 1 1 SBHN TDTP CU 100227 O0 000 O0 0 I 1 1 SIGC TDTP CU 100227 O0 000 O0 0 I 1 1 SIBH TDTP CU 100227 O0 000 O0 0 I 1 1 TRAT TDTP 100227 O0 000 O0 0 1 1 1 LC01 TDTP 100227 O0 000 O0 0 i I 1 SDSI TDTP CU 100227 O0 000 O0 0 i 1 1 BACK TDTP CPS 100227 O0 000 O0 0 i 1 1 FBAC TDTP CPS 100227 O0 000 O0 0 i 1 1 TCAN TDTP CPS 100227 O0 000 O0 0 i 1 1 TCAF TDTP CPS 100227 O0 000 O0 0 I 1 1 TCND TDTP CPS 100227 O0 000 O0 0 1 1 1 TCFD TDTP CPS 100227 O0 000 O0 0 I I I 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 PAGE: ~ o~e~ ~ ~o~ ~y~ c~^ss ~o~ ~u~ s^~ ~ co~ (H~X) ~ScN ~ c~s ~ooz~7 oo 0oo O0 o~ ~ ~ ---2 ..... ~ .... 6666666666' ~sc~ ~ c~s ~oo~ oo ooo oo o ~ ~ ~ ~ ~s oooooooooo INND TDTP CPS 100227 O0 000 O0 0 1 1 I 4 68 0000000000 INFD TDTP CPS 100227 O0 000 O0 0 i 1 1 4 68 0000000000 GRCH TDTP GAPI 100227 O0 000 O0 0 I 1 1 4 68 0000000000 TENS TDTP LB 100227 O0 000 O0 0 I I 1 4 68 O000OO0000 CCL ~OT~ V ZOO~7 O0 OOO O0 0 ~ Z Z 4 ~8 OOO000000O ~ CB~ ~^P~ ZO0~7 O0 000 O0 0 ~ ~ Z 4 ~8 0000000000 ....................................................................................... ** DATA ** DEPT. 11076.500 SIGM.TDTP 15.146 TPHI.TDTP 28.407 SBHF.TDTP SBHN.TDTP 58.524 SIGC.TDTP 0.421 SIBH.TDTP 128.073 TRAT.TDTP LCO1.TDTP 0.000 SDSI.TDTP 0.157 BACK. TDTP 62.348 FBAC.TDTP TCAN.TDTP 70071.234 TCAF.TDTP 28708.430 TCND.TDTP 29983.090 TCFD.TDTP TSCN.TDTP 11010.273 TSCF.TDTP 4510.947 INND.TDTP 2170.445 INFD.TDTP GRCH.TDTP -999.250 TENS.TDTP 10.000 CCL.TDTP 0.000 GR.CBT DEPT. 10418.000 SIGM.TDTP -999.250 TPHI.TDTP -999.250 SBHF.TDTP SBHN.TDTP -999.250 SIGC.TDTP -999.250 SIBH.TDTP -999.250 TRAT.TDTP LCO1.TDTP -999.250 SDSI.TDTP -999.250 BACK.TDTP -999.250 FBAC.TDTP TCAN.TDTP -999.250 TCAF.TDTP -999.250 TCND.TDTP -999.250 TCFD.TDTP TSCN.TDTP -999.250 TSCF.TDTP -999.250 INND.TDTP -999.250 INFD.TDTP GRCH.TDTP -999.250 TENS.TDTP -999.250 CCL.TDTP -999.250 GR.CBT 33.061 1.919 24.408 9732.295 338.698 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 19.281 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11053.0 10463.5 TDTP 11074.5 10465.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 888.0 88889.0 11069.5 11069.0 11059.0 11059.0 11051.0 11051.5 11035.5 11035.0 11032.0 11033.0 11020.5 11021.0 11014.5 11014.5 11005.0 11005.5 10998.5 10999.0 10990.5 10990.0 10986.5 10986.5 10985.5 10985.0 10974.0 10974.0 10963.5 10964.0 10952.5 10953.5 10947.0 10949.5 10937.5 10938.0 10928.0 10928.0 10921.5 10921.5 10921.0 10921.0 10915.5 10915.5 10909.5 10910.5 10898.0 10898.0 10888.0 10887.5 10882.5 10883.5 10871.0 10871.0 10869.0 10869.5 10860.0 10861.5 10853.0 10852.5 10844.0 10844.0 10843.0 10843.5 10841.0 10841.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10836.5 10835.0 10827.0 10827.5 10818.5 10819.5 10817.0 10816.0 10807.0 10806.5 10800.0 10800.0 10799.5 10790.5 10790.5 10781.5 10781.0 10773.5 10773.5 10764.5 10764.5 10762.5 10763.0 10759.0 10758.5 10757.0 10758.0 10750.0 10750.0 10749.0 10750.0 10745.0 10745.0 10743.0 10743.0 10739.5 10739.0 10736.0 10735.5 10734.5 10734.5 10732.0 10732.5 10719.0 10719.5 10713.0 10712.5 10711.0 10711.0 10700.0 10699.5 10693.0 10693.0 10689.5 10689.0 10674.0 10674.0 10667.0 10667.0 10663.0 10663.0 10660.5 10661.5 10654.5 10654.5 10651.0 10650.5 10648.0 10647.0 10643.0 10644.0 10630.5 10631.0 10628.5 10630.0 10625.5 10624.5 10618.5 10619.0 10618.0 10617.5 10614.5 10614.5 10614.0 10614.5 10611.5 10612.0 10608.5 10607.5 10601.5 10602.0 10599.5 10599.5 10593.5 10594.0 10582.0 10582.0 10575.5 10575.5 10565.0 10565.0 10564.5 10565.5 10556.0 10556.0 10555.5 10556.5 10534.0 10534.0 10533.0 10533.5 19-NOV-1995 14:08 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 10527.0 10527.0 10520.5 10521.5 10516.5 10517.0 10514.5 10514.5 10508.5 10508.0 10507.5 10507.5 10503.0 10504.0 10502.5 10500.5 10500.5 10497.5 10495.5 10491.0 10491.0 10486.0 10485.0 10478.0 10478.5 10476.0 10474.5 10475.5 10475.5 100.0 98.5 100.0 $ REHARKS: THIS FILE CONTAINS TDTP PASS #2 DATA. THIS DATA HAS BEEN DEPTH CORRECTED GAMMA RAY TO GAMMA RAY AND SIGH TO SIGM WITH TDTP PASS #1. $ LIS FORMAT DATA PAGE: 9 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name PRUDHOE BAY Field Name FN WN DS 6-3A Well Name APIN 500292018601 API Serial Number FL 0489 FSL & 1139 FEL Field Location SECT 2 Section TOWN 1ON Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation WITN S. WYSOCKI Witness Name SON 100227 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 61. Above Permanent Datum EKB FT 61. Elevation of Kelly Bushing EGL FT 28. Elevation of Ground Level TDD FT 11090. Total Depth - Driller BLI FT 11075. Bottom Log Interval TLI FT 10465. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts LC01 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Tota! counts analyzed near detector.(TDTP) TCAF Total counts analyzed far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector GRCH Gamma Ray in Casing TENS Surface Tension CCL C£L Amplitude PAGE: 10 i 66 2 66 3 73 4 66 5 66 6 73 7 65 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 0 0 92 1 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 I LIS Tape Verification Listing Schlumoerger Alaska Computing Center 19-NOV-1995 14:08 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) _ O0 000 O0 0 2 i I SIGM TDTP CU 100227 4 68 0000000000 TPHI TDTP PU-S 100227 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 100227 O0 000 O0 0 2 i 1 4 68 0000000000 SBHN TDTP CU 100227 O0 000 O0 0 2 i I 4 68 0000000000 SIGC TDTP CU 100227 O0 000 O0 0 2 I I 4 68 0000000000 SIBH TDTP CU 100227 O0 000 O0 0 2 I I 4 68 0000000000 TRAT TDTP 100227 O0 000 O0 0 2 i I 4 68 0000000000 LC01 TDTP 100227 O0 000 O0 0 2 i 1 4 68 0000000000 SDSI TDTP CU 100227 O0 000 O0 0 2 I i 4 68 0000000000 BACK TDTP CPS 100227 O0 000 O0 0 2 I 1 4 68 0000000000 FBAC TDTP CPS 100227 O0 000 O0 0 2 i 1 4 68 0000000000 TCAN TDTP CPS 100227 O0 000 O0 0 2 I 1 4 68 0000000000 TCAF TDTP CPS 100227 O0 000 O0 0 2 I I 4 68 0000000000 TCND TDTP CPS 100227 O0 000 O0 0 2 i i 4 68 0000000000 TCFD TDTP CPS 100227 O0 000 O0 0 2 1 i 4 68 0000000000 TSCN TDTP CPS 100227 O0 000 O0 0 2 i I 4 68 0000000000 TSCF TDTP CPS 100227 O0 000 O0 0 2 I i 4 68 0000000000 INND TDTP CPS 100227 O0 000 O0 0 2 I i 4 68 0000000000 INFD TDTP CPS 100227 O0 000 O0 0 2 1 I 4 68 0000000000 GRCH TDTP GAPI 100227 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 100227 O0 000 O0 0 2 i 1 4 68 0000000000 CCL TDTP V 100227 O0 000 O0 0 2 i 1 4 68 0000000000 11 ** DATA ** DEPT. 11074.500 SIGM.TDTP 15.503 TPHI.TDTP 25.506 SBHF.TDTP SBHN.TDTP 52.339 SIGC.TDTP 0.572 SIBH.TDTP 100.495 TRAT.TDTP LCO1.TDTP 0.000 SDSI.TDTP 0.204 BACK.TDTP 186.506 FBAC.TDTP TCAN.TDTP 53201.000 TCAF.TDTP 22606.086 TCND.TDTP 28394.418 TCFD.TDTP TSCN.TDTP 10104.289 TSCF.TDTP 4293.499 INND.TDTP 2328.125 INFD.TDTP GRCH.TDTP -999.250 TENS.TDTP 10.000 CCL.TDTP 0.000 DEPT. 10463.500 SIGM.TDTP -999.250 TPHI.TDTP -999.250 SBHF.TDTP SBHN.TDTP -999.250 SIGC.TDTP -999.250 SIBH.TDTP -999.250 TRAT.TDTP LCO1.TDTP -999.250 SDSI.TDTP -999.250 BACK.TDTP -999.250 FBAC.TDTP TCAN.TDTP -999.250 TCAF.TDTP -999.250 TCND.TDTP -999.250 TCFD.TDTP TSCN.TDTP -999.250 TSCF.TDTP -999.250 INND.TDTP -999.250 INFD.TDTP GRCH.TDTP 18.125 TENS.TDTP -999.250 CCL.TDTP -999.250 34.655 1.834 39.629 9479.900 358.195 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumoerger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 19-NOV-1995 14:08 PAGE: 12 FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11050.0 10466.0 TDTP 11073.5 10466.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88888.0 11071.0 11069.5 11051.5 11051.5 11041.0 11041.0 11037.0 11036.0 11025.0 11025.0 11021.0 11021.0 11015.5 11015.0 11005.5 11005.5 11002.5 11002.5 10999.5 10999.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10989.0 10988.5 10987.5 10987.0 10978.5 10979.5 10962.5 10964.0 10949.5 10949.5 10939.5 10941.0 10922.0 10921.5 10921.5 10922.0 10915.5 10913.0 10898.5 10900.0 10897.5 10883.5 10883.0 10883.0 10884.0 10876.0 10874.5 10867.0 10866.5 10857.5 10857.0 10854.0 10854.0 10844.0 10843.5 10841.5 10841.0 10839.5 10838.0 10803.0 10803.0 10800.5 10799.5 10791.5 10790.5 10789.5 10788.0 10774.5 10773,5 10764.5 10764.5 10763.0 10762.5 10751.0 10750.5 10750.5 10750.5 10746.0 10745.5 10740.0 10739.5 10739.0 10738.5 10735.5 10734.5 10716.5 10715.5 10713.5 10712.5 10712.0 10711.0 10707.0 10705.5 10700.0 10698.5 10692.0 10691.0 10687.0 10685.5 10674.5 10674.0 10667.0 10666.5 10655.5 10654.5 10648.0 10646.5 10645.0 10645.0 10643.5 10643.0 10633.5 10634.0 10633.0 10633.5 10631.5 10631.0 10628.0 10627.5 10626.0 10624.5 10623.5 10622.5 10615.5 10614.5 10613.0 10612.5 10602.0 10602.0 10601.0 10599.0 19-NOV-1995 14:08 PAGE: 13 LIS Tape Verification Listing Schlumoerger Alaska Computing Center 19-NOV-1995 14:08 10586.0 10585.5 10578.0 10577.5 10557.0 10556.0 10556.5 10556.0 10534.0 10533.5 10527.0 10526.5 10514.5 10514.0 10513.5 10513.5 10508.5 10508.0 10507.0 10503.5 10502.5 10496.0 10495.5 10494.0 10493.0 10485.5 10485.0 10479.0 10479.0 10476.0 10476.0 10471.5 10471.5 10469.0 10469.0 100.0 100.0 100.0 $ REMARKS: THIS FILE CONTAINS TDTP PASS #3 DATA. THIS DATA HAS BEEN DEPTH CORRECTED GAMMA RAY TO GAMMA RAY AND SIGM TO SIGM WITH TDTP PASS #1. $ LIS FORMAT DATA PAGE: 14 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name Field Name FN WN APIN FL SECT TOWN RANG COUN STAT NATI WITN SON PDAT EPD LMF APD EKB EGL TDD BLI TLI DFT FT FT FT FT FT FT FT PRUDHOE BAY DS 6-3A 500292018601 0489 FSL & 1139 FEL 2 1ON 14E NORTH SLOPE ALASKA USA S. WYSOCKI 100227 MSL O. RKB 61. 61. 28. 11090. 11075. 10465. PRODUCED FLUIDS Well Name API Serial Number Field Location Section Township Range County State or Province Nation Witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Ground Level Total Depth - Driller Bottom Log Interval Top Log Interval Drilling Fluid Type LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 PAGE: 15 TABLE TYPE : CURV DEFI DEPT Depth . SIGH Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts LC01 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector.(TDT?) TCAF Total counts analyzed - far detector (TDTP} TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector GRCH Gamma Ray in Casing TENS Surface Tension CCL eCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE i 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 PAGE: 16 TYPE REPR CODE VALUE 16 66 1 0 66 i ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE ~- PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) OD ooo OD o SIGM TDTP CU 100227 O0 000 O0 0 3 1 i 4 68 0000000000 TPHI TDTP PU-S 100227 O0 000 O0 0 3 i 1 4 68 0000000000 SBHF TDTP CU 100227 O0 000 O0 0 3 I i 4 68 0000000000 SBHN TDTP CU 100227 O0 000 O0 0 3 I i 4 68 0000000000 SIGC TDTP CU 100227 O0 000 O0 0 3 1 I 4 68 0000000000 SIBH TDTP CU 100227 O0 000 O0 0 3 i I 4 68 0000000000 TRAT TDTP 100227 O0 000 O0 0 3 I I 4 68 0000000000 LC01 TDTP 100227 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 100227 O0 000 O0 0 3 i i 4 68 0000000000 BACK TDTP CPS 100227 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS '100227 O0 000 O0 0 3 i i 4 68 0000000000 TCAN TDTP CPS 100227 O0 000 O0 0 3 1 I 4 68 0000000000 TCAF TDTP CPS 100227 O0 000 O0 0 3 i i 4 68 0000000000 TCND TDTP CPS 100227 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 100227 O0 000 O0 0 3 1 I 4 68 0000000000 TSCN TDTP CPS 100227 O0 000 O0 0 3 i 1 4 68 0000000000 TSCF TDTP CPS 100227 O0 000 O0 0 3 i 1 4 68 0000000000 INND TDTP CPS 100227 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 100227 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 100227 O0 000 O0 0 3 i i 4 68 0000000000 TENS TDTP LB 100227 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 100227 O0 000 O0 0 3 I i 4 68 0000000000 ** DATA ** DEPT. 11073.500 SIGM.TDTP 14.059 TPHI.TDTP 28.403 SBHF.TDTP SBHN.TDTP 49.838 SIGC.TDTP 0.443 SIBH.TDTP 94.452 TRAT.TDTP LCO1.TDTP 2.543 SDSI.TDTP 0.159 BACK.TDTP 228.878 FBAC.TDTP TCAN.TDTP 82916.469 TCAF.TDTP 32607.695 TCND.TDTP 30167.129 TCFD.TDTP TSCN.TDTP 12044.592 TSCF.TDTP 4736.651 INND.TDTP 2221.464 INFD.TDTP GRCH.TDTP -999.250 TENS.TDTP 15.000 CCL.TDTP 0.000 DEPT. 10466.000 StGM.TDTP 14.033 TPHI.TDTP 26.599 SBHF.TDTP SBHN.TDTP 54.531 SIGC.TDTP 0.966 SIBH.TDTP 110.106 TRAT.TDTP LCO1.TDTP 2.511 SDSI.TDTP 0.286 BACK.TDTP 228.456 FBAC.TDTP TCAN.TDTP 30337.070 TCAF.TDTP 12080.254 TCND.TDTP 20971.059 TCFD.TDTP TSCN.TDTP 5900.176 TSCF.TDTP 2349.457 INND.TDTP 2236.765 INFD.TDTP GRCH.TDTP 26.438 TENS.TDTP 15.000 CCL.TDTP 0.000 37.963 2.019 42.690 10027.850 343.506 41.348 1.918 40.730 5995.845 299.385 LIS Tape Verification Listing Schlumoerger Alaska Computing Center 19-NOV-1995 14:08 PAGE: 17 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass i 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 TDTP 1, 2, 3, $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF THREE PASSES OF TDTP DATA. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 6-3A Well Name APIN 500292018601 API Serial Number LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 PAGE: 18 TUNI VALU DEFI FL 0489 FSL & 1139 FEL Field Location SECT 2 TOWN 1ON RANG 14E COUN NORTH SLOPE STAT ALASKA NATI USA WITN S. WYSOCKI SON 100227 PDAT MSL EPD FT O. LMF RKB APD FT 61. EKB FT 61. EGL FT 28. TDD FT 11090. BLI FT 11075. TLI FT Section Township Range County State or Province Nation Witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Ground Level Total Depth - Driller Bottom Log Interval 10465. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector.(TDT?) TCAF Total counts analyzed - far detector (TDTP} TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector LC01 Local Computation 1 GRCH Gamma Ray in Casing LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ..... ..... I 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** DEPT FT 100227 O0 000 O0 0 4 i i 4 68 0000000000 SIGM PNAV CU 100227 O0 000 O0 0 4 i I 4 68 0000000000 TPHI PNAV PU-S 100227 O0 000 O0 0 4 i i 4 68 0000000000 SBHF PNAV CU 100227 O0 000 O0 0 4 1 i 4 68 0000000000 SBHN PNAV CU 100227 O0 000 O0 0 4 i 1 4 68 0000000000 SIGC PNAV CU 100227 O0 000 O0 0 4 I i 4 68 0000000000 SIBH PNAV CU 100227 O0 000 O0 0 4 I I 4 68 0000000000 TRAT PNAV 100227 O0 000 O0 0 4 i 1 4 68 0000000000 SDSI PNAV CU 100227 O0 000 O0 0 4 1 I 4 68 0000000000 BACK TDTP CPS 100227 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 100227 O0 000 O0 0 4 I 1 4 68 0000000000 TCAN PNAV CPS 100227 O0 000 O0 0 4 1 I 4 68 0000000000 TCAF PNAV CPS 100227 O0 000 O0 0 4 i 1 4 68 0000000000 TCND PNAV CPS 100227 O0 000 O0 0 4 i 1 4 68 0000000000 TCFD PNAV CPS 100227 O0 000 O0 0 4 1 i 4 68 0000000000 TSCN PNAV CPS 100227 O0 000 O0 0 4 1 I 4 68 0000000000 TSCF PNAV CPS 100227 O0 000 O0 0 4 I i 4 68 0000000000 INND PNAV CPS 100227 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 100227 O0 000 O0 0 4 1 i 4 68 0000000000 LC01 PNAV 100227 O0 000 O0 0 4 I i 4 68 0000000000 GRCH TDTP GAPI 100227 O0 000 O0 0 4 I I 4 68 0000000000 19 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 PAGE: 20 DEPT. 11073.500 SIGM.PNAV 14.544 TPHI.PNA¥ SBHN.PNAV 52.224 SIGC.PNAV 0.492 SIBH.PNAV SDSI.PNAV 0.181 BACK.TDTP 72.379 FBAC.TDTP TCAF. PNAV 27243.090 TCND.PNAV 30025.113 TCFD.PNAV TSCF.PNAV 4566.643 INND.PNAV 2304.437 INFD.PNAU GRCH.TDTP -999.250 DEPT. 10468.000 SIGM.PNAV 13.182 TPHI.PNAV SBHN.PNAV 54.775 SIGC.PNAV 1.055 SIBH.PNAV SDSI.PNAV 0.273 BACK.TDTP 150.989 FBAC.TDTP TCAF. PNAV 11651.793 TCND.PNAV 20681.668 TCFD.PNAV TSCF.PNAV 2337.551 INND.PNAV 2205.547 INFD.PNAV GRCH.TDTP 10.523 ** END OF DATA 28.565 SBHF.PNAV 102.599 TRAT.PNAV 19.917 TCAN.PNAV 9782.109 TSCN.PNAV 350.934 LCO1.PNAV 25.428 SBHF.PNAV 108.632 TRAT. PNAV 26.991 TCAN.PNAV 5817.285 TSCN.PNAV 285.942 LCO1.PNAV 36.833 1.987 68811.516 11527.098 0.848 41.596 1.910 28864.563 5791.027 0.824 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 11085.0 $ pass in separate STOP DEPTH 10466.0 files; raw background pass in last file LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 PAGE: 21 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: ID DRILLE~ (Fl): TD LOGGER(FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 29-0CT-95 CP 42.2 11090.0 10466.0 11085.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE T ME GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 11150.0 LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEG,): . BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEC): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT)~ BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS)~ 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO CBT OPENHOLE (SWS) DATED 3-0CT-95 LOGGED VIA COILED TUBING $ TOOL NUMBER TUT 21 CGRS PRODUCED FLUIDS THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center # LIS FORMAT DATA 19-NOV-1995 14:08 PAGE: 22 TABLE TYPE : CONS TUNI VALU DEFI CN .................. ~-~[~-i~ ...... Company Name FN PRUDHOE BAY Fi eld Name WN DS 6-3A Well Name APIN 500292018601 API Serial Number FL 0489 FSL & 1139 FEL Field Location SECT 2 Section TOWN 1ON Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation WITN S. WYSOCKI Witness Name SON 100227 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 61. Above Permanent Datum EKB FT 61. Elevation of Kelly Bushing EGL FT 28. Elevation of Ground Level TDD FT 11090. Total Depth - Driller BLI FT 11075. Bottom Log Interval TLI FT 10465. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI SBHF SBHN SIGC SIBH TRAT LC01 SDSI BACK FBAC TCAN TCAF TCND TCFD TSCN TDT Porosity Borehole Sigma - far detector Borehole Sigma - Near detector Sigma Correction Corrected Borehole Sigma Ration Total Near to Far counts Local Computation 1 Standard deviation of Sigma Background Count Rates - Near Detector Background Count Rate - Far Detector Total counts analyzed near detector (TDT?) Total counts analyzed far detector (TDTP) Total capture counts - Near detector Total capture Counts - far dectector Total Selected Counts - Near Detector LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 DEFI TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension GR API-Corrected Gamma Ray CCL CCL Amplitude PAGE: 23 ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE I 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 i ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100227 O0 000 O0 0 5 1 i 4 68 -~~$$~-- SIGM PS1 CU 100227 O0 000 O0 0 5 1 I 4 68 TPHI PS1 PU 100227 O0 000 O0 0 5 1 i 4 68 SBHF PS1 CU 100227 O0 000 O0 0 5 1 i 4 68 SBHN PS1 CU 100227 O0 000 O0 0 5 1 1 4 68 SIGC PS1 CU 100227 O0 000 O0 0 5 1 I 4 68 SIBH PS1 CU 100227 O0 000 O0 0 5 1 I 4 68 TRAT PS1 100227 O0 000 O0 0 5 1 i 4 68 LC01 PS1 100227 O0 000 O0 0 5 i i 4 68 SDSI PS1 CU 100227 O0 000 O0 0 5 1 1 4 68 BACK PS1 CPS 100227 O0 000 O0 0 5 i I 4 68 FBAC PS1 CPS 100227 O0 000 O0 0 5 1 I 4 68 TCAN PS1 CPS 100227 O0 000 O0 0 5 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 PAGE: c ^ss TCAF PS1 CPS 100227 O0 000 O0 0 5 i 1 4 68 0000000000 O0 000 O0 0 5 i 1 4 68 TCND PS1 CPS 100227 0000000000 TCFD PS1 CPS 100227 O0 000 O0 0 5 1 I 4 68 0000000000 TSCN PS1 CPS 100227 O0 000 O0 0 5 i I 4 68 0000000000 TSCF PS1 CPS 100227 O0 000 O0 0 5 i I 4 68 0000000000 INND PS1 CPS 100227 O0 000 O0 0 5 i i 4 68 · 0000000000 INFD PS1 CPS 100227 O0 000 O0 0 5 i 1 4 68 0000000000 TENS PS1 LB 100227 O0 000 O0 0 5 1 i 4 68 0000000000 GR PS1 GAPI 100227 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 100227 O0 000 O0 0 5 i I 4 68 0000000000 24 ** DATA ** DEPT. 11085.000 SIGM.PS1 22.725 TPHI.PSl 0.000 SBHF. PS1 SBNN.PS1 124.974 SIGC.PS1 0.000 SIBH.PS1 190.683 TRAT. PS1 LCO1.PS1 0.000 SDSI.PS1 5.040 BACK.PS1 16.013 FBAC.PS1 TCAN.PS1 0.000 TCAF.PS1 0.000 TCND. PS1 -196.185 TCFD.PS1 TSCN.PS1 0.000 TSCF.PS1 0.000 INND.PS1 -0.544 INFD.PS1 TENS.PS1 10.000 GR. PS1 13.703 CCL. PS1 0.000 DEPT. 10466.000 SIGM.PS1 13.108 TPHI.PS1 25.609 SBHF. PS1 SBHN.PS1 55.615 SIGC.PS1 0.987 SIBH.PS1 111.662 TRAT. PS1 LCO1.PS1 0.000 SDSI.PS1 0.252 BACK.PS1 150.989 FBAC.PS1 TCAN.PS1 28824.578 TCAF. PS1 11649.275 TCND.PS1 20720.332 TCFD.PS1 TSCN.PS1 5815.328 TSCF.PS1 2350.229 INND.PS1 2107.879 INFD.PS1 TENS.PS1 -5.000 GR.PS1 11.109 CCL.PS1 0.000 53.044 0.000 9.913 -123.145 -0.337 41.518 1.915 26.991 5838.188 293.149 ** END OF DATA ** **** FILE TRAILER FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumoerger Alaska Computing Center **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 19-NOV-1995 14:08 PAGE: 25 FILE HEADER FILE NUMBER 6 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 SUMMARY VENDOR TOOL CODE START DEPTH ............ .... $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL ([Tl BOTTOM LOG INTERVA LOGGING SPEED (FPHR~: DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (F7): LOGGERS CASING DEPTH (FT}: BOREHOLE CONDITIONS FLUID TYPE: 'FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEG,): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): STOP DEPTH 10464.5 29-0CT-95 CP 42.2 11090.0 10464.5 11087.5 1800.0 TOOL NUMBER TDT 21 CGRS 11150.0 PRODUCED FLUIDS LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEC): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT)~ BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (~PS)~ 0 FAR COUNT RATE HIGH SCALE (CPSC: 12000 NEAR COUNT RATE LOW SCALE (~PS}~ 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO CBT OPENHOLE (SWS) DATED 3-0CT-95 LOGGED VIA COILED TUBING $ LIS FORMAT DATA THERMAL SANDSTONE 2.65 PAGE: 26 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name Field Name FN PRUDHOE BAY WN DS 6-3A APIN 500292018601 FL 0489 FSL & 1139 FEL SECT 2 TOWN 1ON RANG 14E COUN NORTH SLOPE STAT ALASKA NATI USA WITN S. WYSOCKI SON 100227 PDAT MSL EPD FT O. LMF RKB APD FT 61. EKB FT 61. ECL FT 28. TDD FT 11090. BLI FT 11075. TLI FT 10465. Well Name API Serial Number Field Location Section Township Range County State or Province Nation Witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Ground Level Total Depth - Driller Bottom Log Interval Top Log Interval LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 PAGE: 27 TUNI VALU DEFI DFT PRODUCED FLUIDS Drilling Fluid Type TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts LC01 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed near detector.(TDT?) TCAF Total counts analyzed far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension GR API-Corrected Gamma Ray CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE i 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-NOV-1995 14:08 PAGE: 28 TYPe REPR COO~ ..... ;2~;~- 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100227 O0 000 O0 0 6 1 1 4 68 -6;66666666-- SIGM PS2 CU 100227 O0 000 O0 0 6 1 I 4 68 0000000000 TPHI PS2 PU 100227 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 100227 O0 000 O0 0 6 I I 4 68 0000000000 SBHN PS2 CU 100227 O0 000 O0 0 6 I I 4 68 0000000000 SIGC PS2 CU 100227 O0 000 O0 0 6 i 1 4 68 0000000000 SIBH PS2 CU 100227 O0 000 O0 0 6 I I 4 68 0000000000 TRAT PS2 100227 O0 000 O0 0 6 1 1 4 68 0000000000 LC01 PS2 100227 O0 000 O0 0 6 I I 4 68 0000000000 SDSI PS2 CU 100227 O0 000 O0 0 6 I i 4 68 0000000000 BACK PS2 CPS 100227 O0 000 O0 0 6 I i 4 68 0000000000 FBAC PS2 CPS 100227 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN PS2 CPS 100227 O0 000 O0 0 6 i 1 4 68 0000000000 TCAF PS2 CPS 100227 O0 000 O0 0 6 i 1 4 68 0000000000 TCND PS2 CPS 100227 O0 000 O0 0 6 I 1 4 68 0000000000 TCFD PS2 CPS 100227 O0 000 O0 0 6 I i 4 68 0000000000 TSCN PS2 CPS 100227 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 100227 O0 000 O0 0 6 1 1 4 68 0000000000 INND PS2 CPS 100227 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 100227 O0 000 O0 0 6 I i 4 68 0000000000 TENS PS2 LB 100227 O0 000 O0 0 6 I I 4 68 0000000000 GR PS2 GAPI 100227 O0 000 O0 0 6 i i 4 68 0000000000 CCL PS2 V 100227 O0 000 O0 0 6 I 1 4 68 0000000000 ** DATA ** DEPT. 11087.500 SIGM.PS2 13.108 TPHI.PS2 25.609 SBHF.PS2 SBHN.PS2 55.615 SIGC.PS2 0.987 SIBH.PS2 111.662 TRAT.PS2 LCO1.PS2 0.000 SDSI.PS2 0.252 BACK. PS2 150.989 FBAC.PS2 TCAN.PS2 28824.578 TCAF. PS2 11649.275 TCND.PS2 20720.332 TCFD.PS2 TSCN.PS2 5815.328 TSCF. PS2 2350,229 INND,PS2 2107.879 INFD.PS2 TENS.PS2 10.000 GR.PS2 11.664 CCL.PS2 0.004 DEPT.' 10464.500 SIGM.PS2 13.584 TPHI.PS2 25.354 SBHF. PS2 SBHN.PS2 58.268 SIGC.PS2 1.144 SIBH.PS2 120.832 TRAT.PS2 L¢O1.PS2 0.000 SDSI.PS2 0.330 BACK. PS2 208.016 FBAC.PS2 TCAN.PS2 28523.359 TCAF.PS2 11674.262 TCND,PS2 20859.609 TCFD.PS2 TSCN.PS2 5824.574 TSCF.PS2 2383.927 INND.PS2 2132.250 INFD.PS2 41.518 1.915 26.991 5838.188 293.149 45.136 1.874 37.150 5950.323 299.470 e Verification Listing ,~berger Alaska Computing Center TENS.PS2 10.000 GR. PS2 19-NOV-1995 14:08 17.234 CCL.PS2 0.000 PAGE: 29 END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAHE : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH $ 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): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 10466.0 29-0¢T-95 CP 42.2 11090.0 10466.0 11085.5 1800.0 TOOL NUMBER Verification Listing .aerger Alaska Computing Center 19-NOV-1995 14:08 PAGE: 3O TDTP THERMA DECAY TIME GR GAMMA RAY $ 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 (DEG,): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEC): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TDT 21 CGRS 11150.0 PRODUCED FLUIDS 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): 12000 NEAR COUNT RATE LOW SCALE (CPS)~ 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO CBT OPENHOLE (SWS) DATED 3-0CT-95 LOGGED VIA COILED TUBING $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN PRUDHOE BAY Field Name WN DS 6-3A Well Name APIN 500292018601 API Serial Number FL 0489 FSL & 1139 FEL Field Location i Verification Listing merger Alaska Computing Center 19-NOV-1995 14:08 PAGE: 31 TUNI VALU DEFI ..................... 2 Section SECT TOWN 1ON Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation WITN S. WYSOCKI Witness Name SON 100227 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 61. Above Permanent Datum EKB FT 61. Elevation of Kelly Bushing EGL FT 28. Elevation of Ground Level TDD FT 11090. Total Depth - Driller BLI FT 11075. Bottom Log Interval TLI FT 10465. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts LC01 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed near detector (TDT?) TCAF Total counts analyzed far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension GR API-Corrected Gamma Ray CCL CCL Amplitude Verification Listing .aerger Alaska Computing Center 19-NOV-1995 14:08 PAGE: ** 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 I ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE ~- PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) OEPT FT 100227 O0 000 O0 0 7 1 1 4 68 --~$~$~-- cu oo 000 oo 0 7 0000000000 TPHI PS3 PU 100227 O0 000 O0 0 7 i 1 4 68 0000000000 SBHF PS3 CU 100227 O0 000 O0 0 7 i 1 4 68 0000000000 SBHN PS3 CU 100227 O0 000 O0 0 7 i 1 4 68 0000000000 SIGC PS3 CU 100227 O0 000 O0 0 7 I I 4 68 0000000000 SIBH PS3 CU 100227 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 100227 O0 000 O0 0 7 i 1 4 68 0000000000 L¢01 PS3 100227 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 100227 O0 000 O0 0 7 1 i 4 68 0000000000 BACK PS3 CPS 100227 O0 000 O0 0 7 1 I 4 68 0000000000 FBAC PS3 CPS 100227 O0 000 O0 0 7 1 i 4 68 0000000000 TCAN PS3 CPS 100227 O0 000 O0 0 7 i i 4 68 0000000000 TCAF PS3 CPS 100227 O0 000 O0 0 7 I 1 4 68 0000000000 TCND PS3 CPS 100227 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS3 CPS 100227 O0 000 O0 0 7 I 1 4 68 0000000000 TSCN PS3 CPS 100227 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 100227 O0 000 O0 0 7 I 1 4 68 0000000000 INND PS3 CPS 100227 O0 000 O0 0 7 I 1 4 68 0000000000 INFD PS3 CPS 100227 O0 000 O0 0 7 i 1 4 68 0000000000 TENS PS3 LB 100227 O0 000 O0 0 7 1 i 4 68 0000000000 GR PS3 GAPI 100227 O0 000 O0 0 7 I I 4 68 0000000000 CCL PS3 V 100227 O0 000 O0 0 7 1 I 4 68 0000000000 32 DATA ,ication Listing Alaska Computing Center DEPT. 11085.500 SIGM.PS3 SBHN.PS3 58.268 SIGC.PS3 LCO1.PS3 2.443 SDSI.PS3 TCAN.PS3 28523.359 TCAF.PS3 TSCN.PS3 5824.574 TSCF.PS3 TENS.PS3 15.000 GR.PS3 DEPT. 10466.000 SIGM.PS3 SBHN.PS3 54.531 SIGC.PS3 LCO1.PS3 2.511 SDSI.PS3 TCAN.PS3 30337.070 TCAF.PS3 TSCN.PS3 5900.176 TSCF.PS3 TENS.PS3 15.000 GR. PS3 19-NOV-1995 13.584 1.144 0.330 11674.262 2383.927 17.563 14.033 0.966 0.286 12080.254 2349.457 26.438 14:08 TPHI.PS3 SIBH.PS3 BACK. PS3 TCND.PS3 INND.PS3 CCL.PS3 TPHI.PS3 SIBH.PS3 BACK. PS3 TCND.PS3 INND.PS3 CCL.PS3 25.354 120.832 208.016 20859.609 2132.250 0.008 26.599 110.106 228.456 20971.059 2236.765 0.000 SBHF. PS3 TRAT.PS3 FBAC.PS3 TCFD.PS3 INFD.PS3 SBHF. PS3 TRAT.PS3 FBAC.PS3 TCFD.PS3 INFD.PS3 PAGE: 33 45.136 1.874 37.150 5950.323 299.470 41.348 1.918 40.730 5995.845 299.385 ** END OF DATA ** **** FILE TRAILER **** FILE NAHE : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 95/11/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/11/19 ORIGIN : FLIC TAPE NAME : 95348 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, DS 6-3A, PRUDHOE BAY, 50-029-20186-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/11/19 ORIGIN : FLIC REEL NAME : 95348 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, DS 6-3A, PRUDHOE BAY, 50-029-20186-01 COMPANy NAME gELL NAME FZELD NAME BORoUQH APZ NUMBER REFERENCE NO : ARCO ALASKA ZNC. D.S. 6-3A : PRUDHOE BAy NORTH SLOPE ~-02g-201~6 0 9S332 - I RECEIVED OCT t;~ 199,5 Tape Verification Listing ,chlumberger Alaska Computing Center 9-0CT-1995 ~7:00 · ~* REEL HEADER ~=== SERVICE NAME : CBT DATE : 95/i0/ 9 ORIGIN : FLIC REEL NAME : 95332 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA,PRUDHOE BAY,DS 6-3A,50-029-20186-01 *~** TAPE HEADER SERVICE NAME : CBT DATE : 95/10/ 9 ORIGIN : FLIC TAPE NAME : 95332 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA,PRUDHOE BAY,DS 6-3A,50-029-20186-01 PAGE: *~** FILE HEADER ***~ FILE NAME : CBT .00i SERVICE : FLIC VERSION : 001A10 DATE : 95/10/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 Tape Verification Listing chlumberger Alaska Computing Center SET TYPE - CHAN -~ 9-0CT-1995 17:OO PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 000 00 0 1 ~ ~ 4 68 0000009000 GR CBT GAPI 90 999 09 9 1 ~ 1 4 68 9999999999 DT CBT US/F 99 99~ 00 9 1 1 ~ 4 68 9999909099 DTCO ITP US/F ~6 109 99 9 1 1 [ 4 68 00000999e9 DATA DEPT. 19893.0e0 GR.CBT 41.590 DT.CBT 95.625 DTCO.ITP DEPT. 10899.909 GR.CBT 27.672 DT.CBT 82.0e0 DTCO.ITP DEPT. ~790.900 GR.CBT 28.978 DT.CBT 95.~25 DTCO.ITP DEPT. 196e9.999 GR.CBT 24.994 DT.CBT 99.875 DTCO.ITP DEPT. 19499.090 GR.CBT 28.875 DT.CBT 97.500 DTCO.ITP -999.259 84.527 94.892 9~.~48 91.523 END OF DATA ** **** FILE TRAILER FILE NAME : CBT SERVICE : FLIC VERSION : DATE : 95/~0/ MAX EEC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NAME : CBT DATE : 95/le/ 9 ORIGIN : FLIC TAPE NAME : 95332 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA,PRUDHOE BAY,DS 6-3A,Se-929-20186-O[ Tape Verification Listing .chlumberger Alaska Computing Center 9-0CT-1995 17:00 PAGE: · ~ REEL TRAILER SERVICE NAME : CBT DATE : 95/10/ 9 ORIGIN : FLIC REEL NAME : 95332 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA,PRUDHOE BAY,DS 6-3A~50-029-20186-01
