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209-046
• • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~o - ~ ~- ~ Well History File Identifier Or anizin Gone Two-sided III II'IIIIIIII IIIII ^ Rescan Needed III IIIIII II II IIIIII 9- 9 c ~ ^ RESC N DIGITAL DATA Color Items: ^ Diskettes, No. ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES BY: ~ Maria ~ Date: Project Proofing BY: Maria Date: ~ ~ ~ /s~ Scanning Preparation _~ x 30 = + ~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: ~ /s/ Production Scannin II I II III) I I III I I III 9- Stage 1 Page Count from Scanned File: ~ (Count does include cov sheet) Pa a Count Matches Number in Scannin Preparation: YES NO g 9 BY: Maria Date: ~ ~ ~ f v /s~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: v I ~ ~ _ _ lsl ReScanned BY: Maria Date: /s/ Comments about this file: a~a,,.~.e~wen uuiiimuimiu 10!6/2005 Well History File Cover Page.doc • OF 17.4. THE STATE Alaska Oil and Gas A S ®nservat>l ®n Commission GOVERNOR SEAN PARNELL • 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS" Main: 907.279.1433 Fax: 907.276.7542 John Egbejimba a q Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18 -02B Sundry Number: 313 -035 Dear Mr. Egbejimba: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, 12- 4(diPit- - A Cathy P oerster Chair DATED this 7 of February, 2013. Encl. SCANNED MAR 14 2013 5 • STATE OF ALASKA • * : ALASKA OIL AND GAS CONSERVATION COMMISSION V4 JAN 2 4 2013 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 AOGCC 1. Type of Request: ❑ Abandon ® Plug for Redrill • ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 209 -046 . 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 20762 -02 -00 . 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? pBU 18-026 Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior 10. Field / Pool(s): ,/ G' , ADL 028307 ' ` 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) 11251' , 8854' • 11203' 8849' 11184' None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 2614' 13 -3/8" 2614' 2614' 4930 2670 Intermediate 8960' 9 -5/8" 8960' 7208' 6870 4760 Production Liner 1714' 7" 8781' - 10495' 7087 - 8647' 8160 7020 Liner 931' 3 - 1/2" x 3 - 3/16" x 2 - 7/8" 10315' - 11246' 8473' - 8853' 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Squeezed Perfs Squeezed Perfs 4 -1/2" 12.6# L -80 10444' Packers and SSSV Type: 7" x 4 -1/2" BKR SABL -3 Packer Packers and SSSV 10398' / 8554' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ■ ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation May 1, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Takahiro Kosaka, 564 -5994 Printed Name: John Title: Engineering Team Leader Email: Takahiro.Kosakaabp.com Signature , t,f • ` (-'2 Phone: 564 - 5859 Date: 1/23/i3 � Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 77-035 Sundry Number: 9 r ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: RBDMS FEB 0 7 2013 r 130 p fr 5 f fo 35-0 / s l Spacing Exception Required? ❑ Yes ❑ No Subsequent Form Required: 1 - 41) -7- APPROVED BY Ap�, By: .7 " ' COMMISSIONER THE COMMISSI D te: g5 — 7- 1 3 itt F�rr� v / 1 Approve app i valid for 12 months from th e d ate of fe,r L l • • 0 b P GP Well Name: 18 -02B Well Type: Producer Current Status: Shut -In Request: P &A - Well Prep f /Rotary Sidetrack MIT -IA - passed to 3000 psi (03/05/11) MIT -T - pass to 3000 psi w/TTP at 9655' MD (09/04/11) Well History: 18 -02B was completed as a CTD sidetrack in August -2009. The well has significant documented losses after CTD crossed a fault. A further SCMT revealed that no cement was present behind • the liner uphole of the fault. The well was POP in this configuration, but quickly gassed out. Remedial CT cement squeeze jobs were executed in May -2010, October -2010, and Novenber -2010. All 3 were unsuccessful in restoring the well as competitive. the 3rd CT job actually lost a fish, that was subsequentially recovered. The well was GL POP via ASRC in conjunction with a CT cleanout after the 3rd squeeze, but no flow was ever established. After failing MIT -IA's in 40-2011, an LDL found a leak at the 9 -5/8" x 7" tie -back liner hanger. Reason for P &A/RST: 18 -02B is a non - operable producer that doesn't flow. Several remediations were attempted to get the well competitive before it was non - operable. All failed. There are no further wellwork • options on this well, and a RWO is uneconomic. The proposed rig sidetrack will access a 60 acre block in the 1A sands with a 20' NLOC to the north of DS -18. Other Requests: None. Scope Planned Sundry Work: As currently planned, the P &A of the 18 -02B well and the well work in • preparation for the 18 -02C rotary sidetrack will be as follows: 1. As pre -rig work; a. Set bridge plug at -10314' MD. b. Punch tubing at - 10310' MD. c. Place a -1800' cement plug on both sides of the tubing from -10310' MD (est. TOC at 8500'). d. Cut tubing at -3650' MD. 2. With the drilling rig on the well; a. Pull 4 -1/2" tubing from -3650' MD. b. Clean -out the well to the top of the tubing stub. c. Set a 9 -5/8" bridge plug at -3500' MD and test. d. Run 9 -5/8" Whipstock and set on the bridge plug. e. Change -out tubing spool and 9 -5/8" pack -off. MASP: 2276 psi @ 8294' TVDss (7.2 ppg pore pressure at TSGR with 0.1 psi /ft gas gradient) Estimated Pre -Rig Start Date: 5/1/2013 lot Of f sry /H�' -1 ii-Ocho`, oy , f1�ra�l {�� ir ` s ll k/41 46 �e� CC(/41(t° u/ell hv1C /10- it i ' .yfrov'c/ rec*ver, 1t (�j1 71Q4 18 -02C Sundry Application 1 1/23/2013 • • Pre -riq prep work: 1. MIT -T to 3000 psi. MIT -IA to 3500 psi. MIT -OA to 2000 psi. 2. Set a cast iron bridge plug on top of the existing 4 -1/2" Liner Top Packer at 10315' MD. 3. Perform a tubing punch at -10310' MD just above the cast iron bridge plug to allow fluid circulation to the IA at that depth and circulate the well to clean seawater on both sides of the tubing. 4. Place -1800' cement plug from the tubing punch on both sides of the tubing above the cast iron bridge plug ( -70 bbls of 15.8 ppg G cement. Est. TOC at 8500' MD.) 5. PT cement to 2500 psi. 6. D &T cement / drift for jet cut on tubing. 7. Jet cut 4 -1/2" tubing at -3650' MD and freeze protect both sides of the tubing with diesel to 2000' MD. 8. CMIT -TXIA to 3500 psi. 9. PPPOT -T and IC. Function LDS. Drill out and replace stuck LDS. 10. Set BPV and test. Rio Work: 1. MI /RU / confirm barriers. 2. Nipple down tree. Nipple up BOPE and test to 250 _psi low /3500 psi high. 3. RU and pull the 4 -1/2" tubing from the pre -rig jet cut at -3650' MD. 4. PU 8 -1/2" clean -out assembly and RIH to clean -out 9 -5/8" casing to top tubing stub. 5. Set 9 -5/8" EZSV at -3500' MD as required to avoid cutting a casing collar while milling the window. 6. _ Pressure test the EZSV to 3500 psi for 30 minutes and chart. 7. RIH with 9 -5/8 " Whipstock assembly and 8 -1/2" window milling assembly to the top of the EZSV. Orient and set the whipstock. 8. Hang the milling BHA on a storm packer and change -out the tubing spool and the 9 -5/8" pack -off. Attachments: Existing Well Schematic Proposed Pre Rig Well Schematic Drilling Engineer: Takahiro Kosaka (907) 564 -5994 Production Engineer: Noelle McBridge (907) 564 -4619 Geologist: Doug Stoner (907) 564 -5652 18 -02C Sundry Application 2 1/23/2013 TREE= 5118'MaEVOY • S• WELL ANGLE > 70° @ 10650'. * ** VIELLHEAD= MCEVOY ACTUATOR= AXELSON INITIAL WELLBORE & 18-02A NOT SHOWN -O BELOW WHIPSTOCK * ** KB. ELEV = 46' BF ELEV = I I KOP = _3100' v Ma Angle = 84° n 11205' 20.OGM OR —.I _80 J Datum M3= 11179' 91.5 # H-40, I 2201' 4- 112" CAMCO TROP -4A TRSV, D = 3.812' _ _ _ LOCKED OUT (06/04/09) OatumTVD= �� D = 19 -124 0 113 -3/8" CSG, 72#, L-80 BT &C, D = 12.34T H 2614' GAS L.FT MANDRELS ST M) TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 2.3" @ 10343' 1 2973 2972 7 WIG DMY RK 0 11/30/11 MILLED OUT ALUMINUM BUSHING IN 2 6148 5388 50 MMG DMY RK 0 11/30/11 DEPLOYMENT SLEEVE 3 8637 6990 48 MIVG DMY RK 0 04/11/95 4 8748 7064 48 MMG DM1' FE 0 _06/22/09 17" BKR TIEBACK SLV, D= 6.375" H 8781' 1 Li h 8789' 1- 19 -5/8' X 7' BKR LT LTP w / LNR HGR, D = 6.188' 1 1 9-5/8" CSG, 47 #, L -80, D = 8.681" H 8960' } — H 9-5/8' IILLOIJT WPDOW (18 -02A) 8960' - 9010' I f 10315' H4 -1/2" BKR KB LIP, D = 2.360" 10333' H3.70" DEPLOY MF3YT SLV, U = 2.972" I 13 -1/2" TBG, 92#, L-80 STL, .0087 bpf, ID= 2.992° H 10384' I I 10384' H3-1/2" X 3 -3/16" XO, D = 2.786' PERFORATION SUMMARY I REF LOG: Ma/ ON 08/17/09 103 ' Hr x 4-1/7 BKR SABL-3 PKR D = 3.875' 1 S ANGLE AT TOP PERE: 81° @ 10920' Note: Refer to Roduction DB for historical perf data ' 10432' 1 -14-1/7 I-ES XN NP WILLED D = 3.80' (05/22/09) 1 SIZE SW ENTH2VAL Opn/Sqz DATE r 6 10920 - 10925 S 11/11/10 r 6 11050 -11140 S 05/07/10 2" 6 11165 - 11185 S 05/07/10 / \-- 10444' H4-1/2" WLEG, ID= 3.958" 10440' Hamm LOGO 04/18/951 4 -1/2" TBG, 12.6#, L -80 NSCT, .0152 bpf, D = 3.958" H 10444' 7' !ALLOW VWMNDOW (18 -02B) 10495' - 10502' I WHFSTOCK (08/15/09) H 10490' 17" LNR, 29#, L -80 NSCC, .0371 bpf, D = 6.184" H 10495 10865' —13 -3/16" X 2 -7/8' XO, D = 2.380" 1 IRA PP TAG (08/15/09) H 10498' 11184' — 2 -7/8' HES FASDRLL 13 -3/16' LNR, 6.2#, L -80 TO, .0076 bpf, D = 2.80" H 10865' 1-- ILL® & PUSHED TO BTM (11/14/10) ICEMBYT SHEATH, D = 2.3' H 10865' - 10895' • I FBTD J — I 11203' 4 ` 4 ' 12 -7/8' LNR, 6.16#, L -80 STL, .0058 bpf, D = 2.441" H 11246' DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY LINT' 08/04/82 PKR 176 INITIAL COM PLETION 05/26/12 PJC MISC/ KB ELEVATION CORRECT1 WELL 18-02B 04/10195 N2ES SIDETRACK (18 -02A) 08/16/12 PJC DRAWING CORRECTIONS PERMT No: 8 2090460 09/18/03 AS/WLP RENAME 18.028 TO 18-02A AR No: 50-029-20762-02 08/19/09 NORDIC 1 CTD SIDETRACK (18 -02B) SEC 24, T11 N, R14E , 1300' FTL & 131' FEL 11/08/11 MSS/ PJC GLV CIO (10 /17/11) 12/11/11 TJAVTAD GLV CO (11/30/11) Bp Exploration (Alaska) TREE= 5_1/8 "Mc VOY OY •18 -02B Pre -Rig • {(UELLFEAD= MC�V ACTUATOR= AXELSON , KB. _ELEV 46' _= _ BF. aEV = _ KOP Max Angle = 84° @11205' 20" CONDUCTOR —80 DratumND 11179' 91.5 # H 2201' — 4 1/2 "CAMCOTRDP 4ATRSV,O= 3.812" Letum TVD = 8800 SS = 19-124" O LOCKED OUT (06 /04/09) 113 -3/8" CSG, 72 #, L -80 BT &C, ID = 12.347" H 2614' GAS LIFT MANDRELS P 1�nned KO P 3500 ' ST ND TVD DEV TYPE VLV LATCH FORT DATE 1 2973 2972 7 WIG DMY RK 0 11/30/11 Je t C ut -3650 ' 2 6148 5388 50 MMG DMY RK 0 11/30/11 TO C -85001- 3 8637 6990 48 MMG DMY RK 0 04/11/95 4 8748 7064 48 WIG DMY RK 0 06/22/09 I7" BKR TEBACK SLV, D = 6.375" 8781' I 8789' HI 9 -5/8" X 7" BKR LT LTP w / LNR HGR, D = 6.188" 8792 'Leak detected by LDL 4/132012 19 - 5/8" CSG, 47 #, L - 80, D = 8.681" 8960' 9 MLLOUT WIDOW (18 - 02A) 8960' - 9010' E st TO C assume 37 bblii Annulis 9200-9587' Tubsng Punch 10310' Castlmn Bilge Plug 10314' 10315' —14-1 /2" BKR KB LTP, ID = 2.360" II IP 10333' H 3.70" DEPLOYMENT SLV, ID = 2.972" imm 3-1/2" TBG, 9.2#, L -80 STL, .0087 bpf, ID = 2.992" — 10384' 10384' — 3 -1/2" X 3 -3/16" XO, 0 = 2.786" B Z7 10398' — j 7" X4-1/2" BKR SABL -3 PKR, D = 3.875" 10432' — 14 - 1/2" I-ES XN MF NLLED ID = 3.80" (05/22/09) 10444' — - 1/2" MEG, L = 3.958" 4 -1/2" TBG, 12.6#, L -80 NSCT, _0152 bpf, ID = 3.958" H 10444' 10440' H 13_M3 TT LOGGED 04/18/95 7" MILLOUT WINDOW (18 -02B) 10495 - 10502' I W-IFSTOCK (08 /15/09) —I 10490' 17" LNR, 29#, L -80 NSCC, .0371 bpf, ID = 6.184" — 10495' 1 10865' H3-3/16" X 2 -7/8" XO, 0 = 2.380" I RA PIP TAG (08/15/09) -- I 10498' 3 -3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.80" 10865' 11184' — 2 -7/8" HES FASDRLL MILLED & PUSHED PERFORATION SUMMARY TO BTM (11/14/10) REF LOG: MGM_ ON 08/17/09 ANGLE AT TOP PE2F: 81 ° @ 10920' CEM3'IT SHEATH, ID = 2.3" — I 10865' - 10895' Nate: Refer to Production DB for historical pert data SIZE SPF NTHNAL Opn /Sqz DATE /• � '4 •�1�1IP • 2" 6 10920- 10925 S 11/11/10 • PBTD I— 11203' ,♦4 2" 6 11050 - 11140 S 05/07/10 2" 6 11165 - 11185 S 05/07/10 2 -7/8" LNR, 6.16#, L -80 STL, .0058 bpf, D = 2.441" I-I 11246' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/04/82 PKR 176 INTIAL COMPLETION 05/26/12 PJC MSC/ KB ELEVATION CORRECTI WELL: 18 -02B 04/10/95 N2ES SIDETRACK (18 -02A) 08/16/12 PJC DRAWING CORRECTIONS PERMIT No: '090460 09/18/03 ASM/LP RENAME 18 -02B TO 18-02A API No: 50- 029 - 20762 -02 08/19 /09 NORDIC 1 CTD SIDETRACK (18 -02B) _ SEC 24, T11 N, R14E, 1300' FR_ & 131' FEL 11/08/11 MSS/ PJC GLV CiO (10/17/11) 12/11/11 TJI -VTAD GLV C/O (11/30/11) BP Exploration (Alaska) P LFEAD = 5-1/8" MCEVOY • 1 8-02C • ACTUATOR= AXELSON PROPOSAL KB. ELEV = 46' BF. a.EV = KOP= 3100' Max Angle = @ 20" CONDUCTOR 0 -2500' 4 -1/2" X NIP ID= 3.813" Datum 91.5 # H 40, Datum TVD = 8800' SS D = 19 -124" 13 -3/8" CSG, 72 #, L -80 BT&C, D = 12.347" H 2614' 1 - 4 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 9 -5/8" x 7" Liner Hanger /Packer -3350' $ 3 2 1 Whipstock set in 9 -5/8" CSG 47# L -80 ID= 8.681" -3500' 9 -5/8" Millout Window (18 -02C) -3500' - Minimum ID = 3.725" @ HES XN NIP TOC -9270' 10649' 4 -1/2" X NIP ID= 3.813" •''• 10684' 7" x 4 -1/2" TNT Packer N'' 10719' 4 -1/2" X NIP ID= 3.813" TPUT 10770' 10822' 10820' 4 -1/2" XN NIP ID= 3.725" 4 -1/2" TBG 12.6# 13Cr VT ID= 3.958" 10834' 7" x 5" Liner Hanger /Packer 10834' ►. • * - 1st joint below Hanger RA tag • 7" LNR 26# L -80 VAMTOP HC ID= 6.276" 10984' PERFORATION SUMMARY REF LOG: ANGLE AT TOPPERF: ° @' Note: Refer to P oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ • xa • • -1000' from PBTD RA tag • • • 4 -1/2" LNR 12.6# 13Cr VT ID= 3.958" 14689' 4 �► DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/04/82 PKR 176 INITIAL COMPLETION WELL: 18-02C 04/10/95 N2ES SIDETRACK (18 -02A) PERMIT No: 09/18/03 AS/WLP RENAME 18 TO 18 API No: 50 029 - 20762 4 08/19/09 NORDIC 1 CTD SIDETRACK (18 - 02B) SEC 24, T11N, R14E, 1300' FNL & 131' FEL 10/12/12 MSE/ PJC PROPOSED ST (18-02C) wp#4 BP Exploration (Alaska) Ft0 K BEL NI= TOP OF ROTARY TABLE C/L WELL 32' DIA. PIPE SEAL MELDED TO THE BOTTOM OF THE TL0N1308 30 -3/B' *PER CIA. TRIPLE NFLATABLE RUBBER SEAL WELL - it BOTTOM OF ROTARY BEAM E i' �_- u .� J 1 . • � _ —_� I BELL NIPPLE: ____L___ _ DIA UPPER, 18 DIA LOWER • I --___:I___. , 4,12171 � g -- _ _ 3' CASING FILL OUTLET (QTY OF 2) — __ l II 13 5 /B' SM BOTTOM UTE FLANGE � 19 16' KEMPER SEAL -O -GRIP II �' a (1 EA.) 3' DIA. STD, OUTLET I ' (1 EA.) 2" DIA. STD. OUTLET 11.1111 DUTCH LOCK DOWN FLANGE �� ANNULAR BOP: y_ 1/2e -- SHAFFER LOT 13 5/8' -5M II ' - � �!"�_ `�' I 13 - 5/8' 58 STUDDED TOP 11' 711/18' - I ! 1E +. r t = - 1a 13 -5/8' SM FLANGED BOTT • , � " RAM TYPE BOP: _ SHAFFER LXT DOUBLE BOP 13 5/8' -Sib 48.45' (DERRICK TAPE) �II �L .. r —_ I 5/8 CELLAR DECK PLATFORM I I II � . = - e r 47 - 1/2• �� . ---- - - - - -- - -._. -- _ _ _ I 13 13 5/8' -S ib NGED BOTTOM * 411 116 W /(2) 14 ' UL2 MSTUDDED OPERATOR, TOP UPPER CAVITY �� � � r - - - - .._.._.._.. M I AND (2) 14' PSLK W/BSTR OPERATOR LOWER CAVITY DRILLING CROSS: I I I 1 13 5/8' -5M FLANGED TOP y : 13 5/8 " -5M FLANGED BOTTOM CHOKE LINE: - "" -�" - "" I�,{I,Ii " -- I I""' Ti •- ••-•-- W (2) 3 7 /8' -Sib SIDE OUTLETS 3 -1/8" 58 FLANGED MANUAL GATE VALVE - III II ' I I I f KILL LINE: 3 -1/8' SM FLANGED HYDRAULIC GATE VALVE 3 -1 /B' 5M FLEX HOSE 21' - 10 1/2" I I iii 1 I I , III 2 -1/16' 5M FLEX HOSE 21 - 4' I I III I 1 1 I I 2 -1/16' 5M X 3-1/8" al D.S.A. T.O.S. CELLAR I I I III I III I I 3 -1/8" 5M FLANGED MANUAL GATE VALVE III II I I I I l I 3 -1/8' 5M FLANGED HYDRAULIC GATE VALVE III III I I I I 1 III RAM TYPE BOP: III SHAFFER LXT SINGLE 13 5 /B' SM IiI I 7 I I, I I 13 5/8 " -SM STUDDED TOP III I ; E I I �,�` I I 1 13 5/8'- 5M FLANGED BOTTOM ill � _ - (; FLANGED W /(2 14' UL2 OPERATOR II ] MATIMG I' III • NIPPLE UP: SPACER SPOOL 13 5/8" 5M FLANGE TOP / 13 5/8" 5M FLANGED BOTTOM CELLAR AND WELL HEAD CONFIGURATION- SPACER SPOOL ARE FOR REFERENCE ONLY & ARE Y -D'— 13 5/8' 5M FLANGE TOP DEPENDENT ON OPERATOR'S 13 5/8" 5M FLANGED BOTTOM REQUIREMENTS / DOUBLE STUDDED ADAPTER 13 5/8" 5M FLANGED TOP 11" 5M FLANGED BOTTOM CASING SPOOL ASSEMBLY 11' 5M FLANGED TOP 11' 5M FLANGED BOTTOM CASING HEAD ASSEMBLY 11' 58 FLANGED TOP CONFIDENTIAL AND PROPRIETARY NOTICE TIM NO. DATE REVISIONS BY WPM AND " document and �° information rmanolo'io � d and contained ber°" °' p PARKERTECNNOLO6Y ' INC. N pracum o N Porker Tesh Inc. and «e makd maintdY in Q . confidence ed H' by Porker Technology, Inc. a. afdldlompYe Receipt of " document and the IA. person and data companion contained herein conelitutes the manned of 1 the person « entity receiving DRAWN BY IhM m eomant to maintain same in confidence. Receipt or a. O RIG 272 750K AADU po.aaeal n of IA. document does not convey my license or right to A CHECKED BY reproduce or to mmufanW me, e, or ..R, In .bole or In part, my M B U IS object or wild. described in tide document. Reproamwn. A pp s 13 5/ SM SHAFFER BOP STACK FLY died".«°, w ores of Od. 0.0000l « any of Ne M«moUm of ® 6/24/12 ADDED 360 INFLATABLE RUBBER SEAL KER MS MS M. QU.KAH NIPPLE UP ON 7 SA CASING d contained herein .KhNN epeolIl written authorization of Pwkw ,, 6/21/12 REVISE RAM LAYOUT NOTES / Technology, Mc. M strictly forbidden. KER MB MO 1/1 1' 0 ® 07/31/12 ISSUED FOR USE 677E JJa ME MO 0](31 /12 ORAW6FC NP. 272E -01 -05-502 I e I SHEET 1 m 1 Page l of l Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve l j D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 Variance Needed for Weekly BOP test. Page 1 of 3 Regg, James B (DOA) ( 1) 7t0 04( From: AK, D &C Wells CT Scheduler [AKDCWellsCTScheduler @bp.com] Sent: Wednesday, January 19, 2011 6:55 AM To: Regg, James B (DOA) �( 1 Cc: AK, D &C Well Services Operations Team Lead Subject: RE: PBU 18 -02B PTD 2090460 Stuck Pipe Recovered Jim, PBU 18 -02 coiled tubing recovery operations are complete and the BOPE is off the well. I will update the North Slope Inspector this morning. Thank -you for your understanding in this matter, Arvell Bass 5faittiNED FEB (¢ 2.011 From: AK, D &C Wells CT Scheduler Sent: Tuesday, January 18, 2011 12:09 AM To: 'Regg, James B (DOA)' Cc: AK, D &C Well Services Operations Team Lead Subject: RE: PBU 18 -02B PTD 2090460 2nd Extension Needed for Weekly BOP test Jim, The chemical cut operation was completed today and we were able to circulate the hole indicating the tubing cut was successful. The pipe is now reconnected at surface. Unfortunately high winds and phase conditions have prevented us from removing some scaffolding which is necessary for the final connection to the well and pulling the coiled tubing out of the well. The pipe rams were closed and tested (against the packed off coiled tubing x production tubing annulus) prior to the chemical cut and remained closed. The well is stable with kill weight fluid, no losses to the formation, and is freeze protected. The scaffold crew is on location and as soon as weather allows we plan to remove the scaffold, connect to the well, and 1 retrieve the pipe. I did speak with the North Slope Inspector today to inform him of our progress at that time. Please consider this a request for an additional extension. Kind regards, Arvell Bass (907) 659 -5542 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, January 14, 2011 2:11 PM To: AK, D &C Wells CT Scheduler Cc: DOA AOGCC Prudhoe Bay Subject: RE: PBU 18 -02B PTD 2090460 Extension Needed for Weekly BOP test I appreciate your update. The request to extent BOPE test waiver is approved. Contact an Inspector at 659 -2714 (office) or 659 -3607 (pager) if there is any change in operation or well status through Monday. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 1/19/2011 Variance Needed for Weekly BOP test. • Page 2 of 3 From: AK, D &C Wells CT Scheduler [ mailto :AKDCWeIIsCTScheduler @bp.com] Sent: Friday, January 14, 2011 5:56 AM To: Regg, James B (DOA) Cc: AK, D &C Well Services Operations Team Lead; Harris, Robert M; Sevcik, Chuck J (Orbis) Subject: PBU 18 -02B PTD 2090460 Extension Needed for Weekly BOP test Jim, We are requesting an extension to the waiver for testing the BOPE on well PBU 18 -02B PTD 2090460. The coiled tubing remains stuck. We still have injectivity down the coil to the perfs, and there are no changes to the well status. No operations to free the pipe have been conducted due to management of the incident at PS 1. There is still some uncertainty to when the pipe recovery operation can begin. My best guess is that we may start as early as Sunday 1/16/11. I will update the North Slope Inspector today. Kind Regards, Arvell Bass (907) 659 -5542 (907) 602 -2483 cel From: AK, D &C Wells CT Scheduler Sent: Tuesday, January 11, 2011 6:42 PM To: 'Regg, James B (DOA)' Cc: AK, D &C Well Services Operations Team Lead; Harris, Robert M; Sevcik, Chuck J (Orbis) Subject: RE: Variance for Weekly BOP test Jim, The sequence of events leading up to the stuck pipe incident on 18 -02 are as follows: Coiled tubing was ran in the well to reperforate following a cement squeeze. The initial run into the well was a depth correlation run that encountered an obstruction in the 4 -1/2" tubing. A motor and mill was ran and chased what appeared to be debris to near bottom when circulation was lost. Open perforations exist due to a composite bridge plug being set prior to the cement squeeze and then being milled up after the cementing operation . Upon losing circulation the tools were pulled out of the hole and became stuck at the top of the 3-1/2" liner. The jars would not function and an attempt to pump down the well indicated that the tubing x coiled tubing annulus was packed off. A disconnect ball was pumped to actuate the hydraulic disconnect. The hydraulic disconnect appeared to shear /function as designed but did not free the coiled tubing indicating the stuck point to be above the disconnect. Well control is maintained inside the coiled tubing by means of dual flapper check valves in the upper BHA (above the hydraulic disconnect) and we are pumping into the perfs down the coiled tubing. Well control of the coiled tubing x tubing annulus is maintained with a full column of kill weight fluid and the coiled tubing stripper. Thanks for the waiver until Friday although I expect management of the incident with PS 1 will prevent us from recovering the stuck pipe before then. If were able to get off the well before then I'll call the NS Inspector and if not I'll send you a note on Friday. Kind regards, Arvell Bass 659 -5542 602 -2483 Ce1 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, January 11, 2011 4:53 PM 1/19/2011 Variance Needed for Weekly BOP test. Page 3 of 3 To: AK, D &C Wells CT Scheduler Cc: DOA AOGCC Prudhoe Bay Subject: RE: Variance Needed for Weekly BOP test Arvell - Thanks for taking the time to discuss your situation with me this afternoon. I would appreciate you providing a summary of events leading up to sticking coil, what was done to unstick, aand what you are doing now to maintain well control. As stated in our phone conversation, I am granting a waiver from BOPE test until Friday, 1/14. If your situation changes, please contact our North Slope Inspector at 907 - 659 -3607. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Wells CT Scheduler [mailto:AKDCWeIIsCTScheduler @bp.com] Sent: Tuesday, January 11, 2011 12:55 PM To: Regg, James B (DOA) Subject: Variance Needed for Weekly BOP test Dear Jim, Schlumberger CTU #8 (service coil unit) has coiled tubing stuck in the hole on well DS 18 -02. This occurred on Thursday 1/6/11. Under normal circumstances we would have chemical cut the coiled tubing and have been off the well by now but due to PS 1 issue all non - essential work is on hold. The weekly BOP test is due today and we are asking for a waiver to the weekly test with no way to test the BOPE with pipe across the rams. I have notified Jeff Jones. If you need more information please give me a call. Kind Regards, Arvell Bass (907) 659 -5542 office (907) 602 -2483 cel 1/19/2011 Variance Needed for Weekly BOP test Page 1 of 3 Regg, James B (DOA) q z , ` From: Regg, James B (DOA) Sent: Friday, January 14, 2011 2:11 PM To: 'AK, D &C Wells CT Scheduler' Cc: DOA AOGCC Prudhoe Bay Subject: RE: PBU 18 -02B PTD 2090460 Extension Needed for Weekly BOP test I appreciate your update. The request to extent BOPE test waiver is approved. Contact an Inspector at 659 -2714 (office) or 659 -3607 (pager) if there is any change in operation or well status through Monday. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 FEB I 2011 907 - 793 -1236 D From: AK, D &C Wells CT Scheduler [ mailto :AKDCWeIIsCTScheduler @bp.com] Sent: Friday, January 14, 2011 5:56 AM To: Regg, James B (DOA) Cc: AK, D &C Well Services Operations Team Lead; Harris, Robert M; Sevcik, Chuck J (Orbis) Subject: PBU 18 -02B PTD 2090460 Extension Needed for Weekly BOP test Jim, We are requesting an extension to the waiver for testing the BOPE on well PBU 18 -02B PTD 2090460. The coiled tubing remains stuck. We still have injectivity down the coil to the perfs, and there are no changes to the well status. No operations to free the pipe have been conducted due to management of the incident at PS 1. There is still some uncertainty to when the pipe recovery operation can begin. My best guess is that we may start as early as Sunday 1/16/11. 1 will update the North Slope Inspector today. Kind Regards, Arvell Bass (907) 659 -5542 (907) 602 -2483 cel From: AK, D &C Wells CT Scheduler Sent: Tuesday, January 11, 2011 6:42 PM To: 'Regg, James B (DOA)' Cc: AK, D &C Well Services Operations Team Lead; Harris, Robert M; Sevcik, Chuck 3 (Orbis) Subject: RE: Variance for Weekly BOP test Jim, The sequence of events leading up to the stuck pipe incident on 18 -02 are as follows: Coiled tubing was ran in the well to reperforate following a cement squeeze. The initial run into the well was a depth correlation run that encountered an obstruction in the 4 -1/2" tubing. A motor and mill was ran and chased what appeared to be debris to near bottom when circulation was lost. Open perforations exist due to a composite bridge plug being set prior to the cement squeeze and then being milled up after the cementing operation . Upon losing circulation the tools were pulled out of the hole and became stuck at the top of the 3 -1/2" liner. The jars would not function and an attempt to pump down the well indicated that the tubing x coiled tubing annulus was packed off. A disconnect ball was pumped to actuate the hydraulic disconnect. 1/14/2011 Variance Needed for Weekly BOP test Page 2 of 3 The hydraulic disconnect appeared to shear /function as designed but did not free the coiled tubing indicating the stuck point to be above the disconnect. Well control is maintained inside the coiled tubing by means of dual flapper check valves in the upper BHA (above the hydraulic disconnect) and we are pumping into the perfs down the coiled tubing. Well control of the coiled tubing x tubing annulus is maintained with a full column of kill weight fluid and the coiled tubing stripper. Thanks for the waiver until Friday although I expect management of the incident with PS 1 will prevent us from recovering the stuck pipe before then. If were able to get off the well before then I'll call the NS Inspector and if not I'll send you a note on Friday. Kind regards, Arvell Bass 659 -5542 602 -2483 Cel From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, January 11, 2011 4:53 PM To: AK, D &C Wells CT Scheduler Cc: DOA AOGCC Prudhoe Bay Subject: RE: Variance Needed for Weekly BOP test Arvell - Thanks for taking the time to discuss your situation with me this afternoon. I would appreciate you providing a summary of events leading up to sticking coil, what was done to unstick, aand what you are doing now to maintain well control. As stated in our phone conversation, I am granting a waiver from BOPE test until Friday, 1/14. If your situation changes, please contact our North Slope Inspector at 907 - 659 -3607. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Wells CT Scheduler [ mailto :AKDCWeIIsCTScheduler @bp.com] Sent: Tuesday, January 11, 2011 12:55 PM To: Regg, James B (DOA) Subject: Variance Needed for Weekly BOP test Dear Jim, Schlumberger CTU #8 (service coil unit) has coiled tubing stuck in the hole on well DS 18 -02. This occurred on Thursday 1/6/11. Under normal circumstances we would have chemical cut the coiled tubing and have been off the well by now but due to PS 1 issue all non - essential work is on hold. The weekly BOP test is due today and we are asking for a waiver to the weekly test with no way to test the BOPE with pipe across the rams. have notified Jeff Jones. If you need more information please give me a call. Kind Regards, 1/14/2011 Variance Needed for Weekly BOP test Page 3 of 3 Arvell Bass (907) 659 -5542 office (907) 602 -2483 cel 1/14/2011 Variance Needed for Weekly BOP test Page 1 of 2 Regg, James B (DOA) • • From: Regg, James B (DOA) 1\11 Sent: Wednesday, January 12, 2011 10:35 AM C7/(/ To: 'AK, D &C Wells CT Scheduler' p� j Subject: RE: Variance for Weekly BOP test ff One correction; well name should be PBU 18 -02B, PTD 2090460 P� Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 EP FEB 01, From: AK, D &C Wells CT Scheduler [ mailto :AKDCWellsCTScheduler @bp.com] Sent: Tuesday, January 11, 2011 6:42 PM To: Regg, James B (DOA) Cc: AK, D &C Well Services Operations Team Lead; Harris, Robert M; Sevcik, Chuck J (Orbis) Subject: RE: Variance for Weekly BOP test Jim, The sequence of events leading up to the stuck pipe incident on 18 -02 are as follows: Coiled tubing was ran in the well to reperforate following a cement squeeze. The initial run into the well was a depth correlation run that encountered an obstruction in the 4 -1/2" tubing. A motor and mill was ran and chased what appeared to be debris to near bottom when circulation was lost. Open perforations exist due to a composite bridge plug being set prior to the cement squeeze and then being milled up after the cementing operation . Upon losing circulation the tools were pulled out of the hole and became stuck at the top of the 3 -1/2" liner. The jars would not function and an attempt to pump down the well indicated that the tubing x coiled tubing annulus was packed off. A disconnect ball was pumped to actuate the hydraulic disconnect. The hydraulic disconnect appeared to shear /function as designed but did not free the coiled tubing indicating the stuck point to be above the disconnect. Well control is maintained inside the coiled tubing by means of dual flapper check valves in the upper BHA (above the hydraulic disconnect) and we are pumping into the perfs down the coiled tubing. Well control of the coiled tubing x tubing annulus is maintained with a full column of kill weight fluid and the coiled tubing stripper. Thanks for the waiver until Friday although I expect management of the incident with PS 1 will prevent us from recovering the stuck pipe before then. If we're able to get off the well before then I'll call the NS Inspector and if not I'll send you a note on Friday. Kind regards, Arvell Bass 659 -5542 602 -2483 Cei From: Regg, James B (DOA) [mailto :jim.regg @alaska.gov] Sent: Tuesday, January 11, 2011 4:53 PM To: AK, D &C Wells CT Scheduler Cc: DOA AOGCC Prudhoe Bay Subject: RE: Variance Needed for Weekly BOP test Arvell - 1/12/2011 Variance Needed for Weekly BOP test Page 2 of 2 Thanks for taking the time to discuss your situation with me this afternoon. I would appreciate you providing a summary of events leading up to sticking coil, what was done to unstick, aand what you are doing now to maintain well control. As stated in our phone conversation, I am granting a waiver from BOPE test until Friday, 1/14. If your situation changes, please contact our North Slope Inspector at 907 - 659 -3607. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Wells CT Scheduler [mailto:AKDCWellsCTScheduler @bp.com] Sent: Tuesday, January 11, 2011 12:55 PM To: Regg, James B (DOA) Subject: Variance Needed for Weekly BOP test Dear Jim, Schlumberger CTU #8 (service coil unit) has coiled tubing stuck in the hole on well DS 18 -02. This occurred on Thursday 1/6/11. Under normal circumstances we would have chemical cut the coiled tubing and have been off the well by now but due to PS 1 issue all non - essential work is on hold. The weekly BOP test is due today and we are asking for a waiver to the weekly test with no way to test the BOPE with pipe across the rams. I have notified Jeff Jones. If you need more information please give me a call. Kind Regards, Arvell Bass (907) 659 -5542 office (907) 602 -2483 cel 1/12/2011 STATE OF ALASKA t ALASK* AND GAS CONSERVATION COMMISSO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Q CEMENT SQUEEZE Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ 209 -0460 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 5 50- 029 - 20762 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028308 / 28307 I PBU 18 -02B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11251 feet Plugs (measured) None feet true vertical 8853.88 feet Junk (measured) None feet Effective Depth measured 11203 feet Packer (measured) 10398 feet true vertical 8849. feet (true vertical) 8554 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H40 SURFACE -80 SURFACE -80 1490 470 Surface 2614' 13 -3/8" 72# L -80 SURFACE - 2614 SURFACE - 2614 5380 2670 Intermediate 8960' 9 -5/8" 47# L -80 SURFACE - 8960 SURFACE - 7208 6870 4760 Production 1714' 7" 29# L -80 8781 - 10495 7087 - 8647 8160 7020 Liner 931' 3- 1/2 "X3- 3/16" L -80 10333 - 11246 8490 - 8853 Liner X2- 7/8 "9.2 6.2 6.16# Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 SURFACE - 10444 SURFACE - 8598 Packers and SSSV (type, measured and true vertical depth) 7" X 4 -1/2" BKR SABL -3 PKR 10398 8554 ; Nb 12. Stimulation or cement squeeze summary: Intervals treated (measured): Alaska Oil &Gas Carts. Commission Treatment descriptions including volumes used and final pressure: Anchorage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil G D Gas LJ WDSPL GSTOR ❑ WINJ ❑ WAG[:] GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na AJLasttu4 Title Data Manager Signat Phone 564 -4091 Date 12/2/2010 D E C O 6 Form 10-404 Revised 10/2010 � �Z �b Submit Original Only 18 -02B 209 -046 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 18-02B 8/18/09 PER 11,050. 11,140. 8,828.81 8,841.71 18 -02B 8/18/09 PER 11,165. 11,185. 8,844.92 8,847.26 18 -02B 5/7/10 SQZ 11,050. 11,185. 8,828.81 8,847.26 18 -02B 5/8/10 SQF 11,050. 11,185. 8,828.81 8,847.26 18 -02B 9/26/10 BPS 10,950. 11,185. 8,814.14 8,847.26 18 -02B 9/27/10 APF 10,920. 10,925. 8,809.74 8,810.49 18-026 10/4/10 SQZ 10,310. 10,950. 8,468.57 8,814.14 18 -02B 11/12/10 BPP 10,950. 11,184. 8,814.14 8,847.14 18 -02B 11/12/10 FCO 10,310. 11,184. 8,468.57 8,847.14 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 18 -02B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/6/2010 ** *WELL S/I ON ARRIVAL * ** (sbhps) � ARAN FLAPPER CHECKER TO CONFIRM TRSV @ 2181' SLM/ 2202' MD IS j LOCKED OPEN ;DRIFTED TO DEV @ 10657' SLM/ 10681' MD W/ 2.25" CENT, 1.75" S. BAILER (rec E1/4 cup cement) i IRAN 2.25" CENT, PETREDAT SBHPS GAUGES (good data) 3 ! ** *WELL LEFT S/I ON DEPARTURE* ** l _..._. _----- _ i 11/10/2010 CTU #8 W/ 1.75" CT. Scope: CMT retainer sqz. «no interact >> Bleed IA from 1900 I to 1000 psi. Load well w/ 5 meth, 280 kcl, 7 bbl meth cap. RIH w/ 2.25" nozzle. fsat down high @ 10,694', repeat. would not pass thru. pooh. discussion w/ town. decision made to run mill. pooh. POH. L/O nozzle BHA. M/U Weatherford 2.30' j milling BHA. RIH to 10000'. * ** Job in Progress * ** I i 11/11/2010CTU #8 (Cont.from WSR 11- 10 -10) Scope; cmt retainer sqz. Ream down clean with 2. 30" mill from 10380 - 10700'. Ream cement stringers from 10700 - 10726'. WHP increasing. Circ hole to prevent plugging perfs. Ream clean down to bottom of sqz perfs at 10925'. Hard cement in sump below sqz perfs from 2 previous cement sqz jobs. Circ biozan pill. Ream up / down while chasing pill to surface. Flag coil at 10800'. POH. RIH w/ WOT one trip retainer. stop and tie in @ flag. Set retainer requested depth of 10895. Pump 8 bbls of of 15.8 ppg class G cmt thry lout of retainer and lay in remaining 2 bbls on top of retainer. contaminate w/ biozan !down to 20' above retainer @ 10875' and start chase to surface. Freeze protect 4- 1/2" tubing with 60/40 MEOH while POH. L/O BHA and rig down CTU. PT tree cqp. j _. Release CTU at 2 3:59 hr s. WO bef ore dri lling out c 11/12/2010;CTU #8 with 1.75" coil. Job Scope: Mill Sqz cement, retainer and EZDrill Bridge plug. MIRU CTU. PJSM. M/U Weatherford 2.30" milling BHA with Jars. RIH with milling `BHA. Tag cement at 10885' CTD. Milled hard cement to 10896' by midnight. ** *Job in Progress I � � I e 11/13/2010 CTU #8 WITH 1.75" COIL. Job Scope: Mill cement, retainer, cement and bridge plug. E Continue milling cement from 10896- 10904'. Tag cement retainer at 10904'. Milled 02, stalled, pull free, milled 1 ft. of retainer 8 stalls tot Milled retainer and cement I down to composite plug @ 10960'. lost circulation indicating seal on plug broke. cont 1milling down to 10964'. Injecter would not RIH so POH and repair injecter. SWS on downtime at 1900 hrs thru midnight. ** *Job in Progress * ** ! I i 11/14/2010�CTU #8 w/ 1.75" coil. Job Scope. Mill cement and EZDrill bridge plug after cement ISQZ, job continues from 11/13/10 ! mechanics replaced 2 counter balance valves on autodriller and tested injecter !at surface. RIH with 2.30" milling BHA. RIH Clean to 11000' Chase EZ Drill bridge iplug down to 11063', Stall on Bridge plug twice. Time mill on bridge plug. Continue Ito mill / c hase plug to 11184. C ould not RIH any deeper. Phone town, call it good. Pooh. (FP well with 25 bbls of 60/40 meth,well on vac) Rig down CTU and perform 1 hour of maintenance. Move CTU to K -10. ** job complete ** 9 FLUIDS PUMPED BBLS 1 DIESEL 2571 KCL 262 60/40 McOH 171 GEOVIS 65 BIOZAN 3070 TOTAL TREE= 5 -1/8" McEVOY SAFETY ES: WELLANGLE> 70° @ 10650'. WELLHEA = MCE VOY J M D D RA "'ORIG VTELLBORE (18 -02) NOT SHOWN... ACTUATOR = AXELSON KB. ELEV = 46.6' BF. ELEV KOP = 3100' Max Angle = 84° @ 11205' Datum MD = 11179' 2201 4 -112" CAMCO TRDP -4A TRSV, ID = 3.812" Datum TV D = 8800' SS 0 LOCKED OUT (0610 13 -318" CSG, 72 #, L -80, ID = 12.347" 2614' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 2.3" @ 10343' 1 2973 2972 7 MMG DOME RK 16 07/16/10 BOT OF DEPLOYMENT SLEEVE 2 614$ 5388 50 MMG RK 20 07/16/10 3 8637 6990 48 MMG DM Y RK 0 04/11/95 4 8748 17064 48 MMG I DMY RK 1 0 06/22109 7" BKR TIEBACK SLV, ID = 6.375" 8781' 8789' 9 -5/8" X 7" BKR LT PKR, ID = 6.188" 9 -5/8" X 7" BKR LNR HGR, ID = 6.188" 8794' 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 8960' 9 -5/$" MILLOUT WINDOW (18 -02A) 8960' - 9010' 10315' 4 -112" BKR KB LTP, I D 7 2 - 3 - 6 - F - 1 10333' 3.70" DEPLOYMENT SLV, ID = 2.972" 3 -1/2" TBG, 9.2 #, L -80 STL, .0087 bpf, ID = 2.992" 10384' 10384' PERFORATION SUMMARY REF LOG: MCNL ON 08/17/09 10398 7" X 4 -112" BKR SABL -3 PKR, ID = 3.$75" ANGLE AT TOP PERF: 81'@ 10920' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 10432' 4 -1/2" HES XN NIP, MILLED ID = 3.80" (05/22!09) 2" 6 10920 - 10925 S 11!11/10 2" 6 11050 11140 S 05/07/10 10444' 4 -1/2" WLEG, ID = 3.958" 2" 6 11165 - 11185 S 05/07/10 10440' ELMD TT LOGGE 0 4/18/95 4 -1/2" TBG, 12.6 #, L-80_0152 bpf, ID = 3.958" 10444' 7" MILLOUT WINDOW (18 -02B) 104 .. 95' - 10500 2 WHIPSTOCK (08115109) 10490' 7" LNR, 29 #, L-80_0371 bpf, ID = 6.1$4" 10495' 10865' —]3-3/16"X2-7/8" RA PIP TAG (08 F 10498' 11184 2 -7/8" HES FASDRILL 3- 3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.80" 10865' MILLED & PUSHED TO BTM (11/14/10) CEMENT SHEATH, ID = 2.3" 10865' - 10895' I PBTD 11203' 2 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, ID = 2.441" 11246' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/24/82 ORIGINAL COMPLETION 07/28/10 BSE/PJC TRSV LOCKED OUT (06/04/09) WELL: 18 -02B 04/09/95 RIG SIDETRACK 08/17/10 ? /JMD DRLG DRAFT CORRECTIONS PERMIT No: 2090460 09/18/03 AS/WLP RENAME 18 -02B TO 18 -02A 09/27/10 SPB /PJC SET FASDRILL / PERF (09/26/10) API No: 50- 029 - 20762 -02 -00 08/19/09 NORDIC 1 CTD SIDETRACK (18 -02B) 09/27/10 1 JKC/PJC CMT SQZ (05/07/10) SEC 24, T11N, R1 4E, 1300' FNL & 131' FEL 08122/09 PJC DRLG HO CORRECTIONS 11/14/10 RMH/PJC MILL CMT/ FASDRILL 07/15/10 WECIPJC GLV C/O (07/16/10) BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 8/2512010 Permit to Drill 2090460 Well Name/No. PRUDHOE BAY UNIT 18-02B Operator BP EXPLORATION (ALASF(A) INC API No. 50-029-20762-02-00 MD 11251 TVD 8807 Completion Date 8/19/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES, GR /CCL / CNL Well Log Information: Log/ Electr Ilafa Dinital Dataset (data taken from Logs Portion of Master Well Data Maint Loa Loa Run Interval pH i T Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Log Neutron 5 Blu 9814 11189 Case 9/16/2009 MCNL, Lee, TNN, GR< CCL 17-Aug-2009 ~~ D C Lis 1865i~/Neutron 9814 11193 Case 9/16/2009 LIS Veri, GR, CNT ED C Pds 18727~Cement Evaluation 10300 11138 Case 10/2/2009 Mem SCMT and Pits, Mem PSP CCL, GR, Pres, Temp, CBL, VDL 19-Aug- 2009 og Cement Evaluation 5 Col 10300 11138 Case 10/2/2009 Mem SCMT and Pits, Mem PSP CCL, GR, Pres, Temp, CBL, VDL 19-Aug- 2009 Rpt LISiVerification 10238 11249 Open 11/5/2009 LIS Veri, GR, ROP C Lis 18878 Gamma Ray 10238 11249 Open 11/5/2009 LIS Veri, GR, ROP Plus Graphics og Gamma Ray 25 Col 10495 11251 Open 11/5/2009 MD GR og Gamma Ray 5 Col 10495 11251 Open 11/5/2009 TVD GR g Gamma Ray 5 Col 10230 11230 Open 11/5/2009 Depth Shift Monitor Plot Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • • DATA SUBMITTAL COMPLIANCE REPORT 8/25/2010 Permit to Drill 2090460 Well Name/No. PRUDHOE BAY UNIT 18-02B Operator BP EXPLORATION (ALASKIy INC API No. 50-029-20762-02-00 MD 11251 TVD 8807 Completion Date 8/19/2009 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y / N Daily History Received? Y / N Chips Received? Y / N Formation Tops Y / N Analysis Y / N Received? Comments: Compliance Reviewed By: Date: STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAY 1 ~ 2010 1. Operations Abandon ^ Repair Well Q Plug Perforations ^ Stimulate^ ~~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ ~ UEEZE Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 209-0460 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20762-02-00 8. Property Designation (Lease Number) : ~ W1 5•C4 ~ 1 D 9. Well Name and Numbed ADLO-028308 ~ ~0 7 PBU 18-026 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11251 feet Plugs (measured) None feet true vertical 8853.88 feet Junk (measured) None feet Effective Depth measured 11203 feet Packer (measured) 10398 true vertical 8849.16 feet (true vertical) 8554 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 SURFACE - 80 SURFACE - 80 1490 470 Surface 2614 13-3/8" 72# L-80 SURFACE - 2614 SURFACE - 2614 5380 2670 Intermediate 8960 9-5/8" 47# L-80 SURFACE - 8960 SURFACE - 7208 6870 4760 Liner 1714 7"29# L-80 8781 - 10495 7087 - 8647 8160 7020 Liner 931 3-1/2"X3-3/16" L-80 11246 -8473 8853 - Liner X2-7/8" 9.2 6.2 6.16# Perforation depth: Measured depth: 11050 - 11140 11165 - 11185 True Vertical depth: 8828.81 - 8841.71 8844.92 - 8847.26 _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 SURFACE - 10444 SURFACE - 8598 Packers and SSSV (type, measured and true vertical depth) 7"X4-1/2" BKR SABL-3 PKR 10398 8554 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 758 44063 21 726 Subsequent to operation: 14. Attachments: 5. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X 6. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre I Title Data Management Engineer Signature Phone 564-4944 Date 5/18/2010 - ~ S•!9• to ~%j,~ i • 18-02B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY } 5/6/2010~CTU 9 1.75" CT. Job Scope: Drift, GSO CMT Squeeze. MIRU CTU. MU 3.00" Drift ?Nozzle BHA and RIH.....Job continued on WSR 5/7/10 5/7/2010CTU 9 1.75" CT. Job Scope: Drift & GSO CMT Squeeze. Continue from WSR 5/6/10. Continue RIH to tag TOL. Tag TOL 10330' ctmd, correct EOP to TOL, paint jflag and POOH. MU Slim BHA and RIH to flag and correct depth. RIH and tagged j bottom @ 11208', Flag coil at 10315', Kill well 5bbls meth, 245bb1s 2% KCI, 131 bbls diesel, swap to pumping dwn coil, 3 bbls meth, 2% KCI at 0.6 bpm; RU cmters, ,safety mtg, press test, pump 5bbls fresh wtr, 12 bbls 14.Oppg SgzCrete, 20 bbls 15.8_ppg LARC, 10bbls freshwater, 40 bbls meth POH to 9504' or sa ety, wai on ~cmt, attempt sqz on cmt, slight build in pressure for each bbl pumped, saw sqz pressure up to 329 psi w/ slow leak off thru out. Drop ball, chase w/ 8 bbls wtr, then biozan. Jetted biozan 2.5bpm from tailpipe to PBTD 11206.6'. POH jetting ;biozan at 2.0 bpm to 9500', Pumped total of 97 bbls biozan. RIH from 9500' pumping 1 %KCI w/ XS for 3rd jetting pass and lost 90% of our returns. Not enough :rate to carry contam CMT out, FP CT and BH away. Injectivity 33psi at 3.0 bpm with well displaced to KCL. OOH well FP with 40 bbls of diesel. RDMO CTU....Job 5/17/2010`T/I/0= 0/980/0 Temp=S/I Injectivity test (Cement Squeeze) Pumped 5 bbls 60/40 meth followed by 202 bbls 2% KCL down TBG. Test results= 4.4 bpm @ 500 psi & ~5 bpm @ 625 psi. Freeze protected TBG w/ 40 bbls 60/40 meth. ""Wellhead valves ;left in the following positions: SV, WV & SSV=S/I. MV, IA & OA left open.'"** FWP's=Vac/1000/0 FLUIDS PUMPED BBLS 767 2% KCL 150 50/50 METH 184 DIESEL 12 FRESH WATER 12 14PPG SQUEEZE CRETE 20 15.8 LARC 97 B I OZAN 290 1 %KCI W/XS 1532 Total ~ = 5;118" r+AcE`v ~WEI LHEAD~- MGEVUY ~A CTUA TC7 R = AXELS ON ~F, EtFV KQP = 3100' Max Ang = 84~' L~112nR`;; Datvm Mp = i i 17S Datvm ND = __ _._... 8800' SS ~ ~ 5 OTES: `* ~~ ANGLE • 7D (7i 90050' `**' PFD SCSTRK W FtE NOTSHQWN 01u LBAC~tAM B>^LC?W 9-518'• SEGTIOfd MILLm ~ ~ ~.. ~ ~ ~ T w1n)c~rw 896f3'. 13-318" CSC, 72#, x,-84, ID=12.347" 2614' h+linirt~urr~ IC1= ~.3" ~ '10342' F~t~TTQM t}~ DEPL+C~Y ~t~EE 7" BKR TIEBACK SLV, ~ = 8.375" $~$~` i-518" X 7" BKR LNR HGR, ~ - B-188" ', $'794' 5-518" GSG, 4T#, L-80, ID - 8.681" $$' 18-02 (3-112", 9.2#, L-80, STL LIVR, N7 - <.p95" 'f0~+;i4' 4-1/2., TBG, 12.&#, L-80..1?152 bpf, ED = 3.958" '(0397' 4112" TTP, 12.6A~, L-84, .4152 bpf, D = 3.858" 10444' 4-11''" x 7" w l~iipsto~,f<: T049Q' 14° 0 14 PERFQRAT3QN SUMMARY REF LOG: rUk~n~ry C;~dL 021,'17;09 A NGLE AT TOP F'ERF: 81 ° ~D 1 10~i0' Note: Refer to Production DB for historical perf tiet9 SIZE SF'F INTERVAL OpNSgz DATE 6 11 X50 11'=, 4{7 C.3pn OF3l18IOJ 6 I 1 i'~5' - 11 t 85' Opri 08~ t X109 14° 7" LNR, _, 1> L-~'0~ .4371 bpf, ID=s,ts4" 10846' 2201' 4-112" C;AI1A(:U -4A TRSV, ID= 3.812" GAS LFl'MANDREI.S ST MD TVD DEU TYPE VLV LATCH PC3 DATE 1 2373 '4972 7 [U6dMC" 13MY RK €~ 06/05/07 2 8148 5387 50 ' MM^v DFA`(' RK 4 06/05/47 3 8637 5990 48 MMG OMY RK 4 04/11/95 4 8748 7Q64 48 MMG DAdY RK 0 46!2'7J09 8789' ]--~ 9-518" ?C 7" BKR LT PKR, ID = 6.181 9-5,8" MIlLOIIT' (18-02A} 89n0"-5010' TSGR 10178' 10315' 4-1 r'?" BKR h:Ll LTP, IC;~ _ ?.36U 1~3~3' :~ s,.~.. BTr ~E"L~}Y ~w', tcs ~ ~s7t° 10398' 7"X4-112" BKR SABL-3 PKR, ~ = 3.875" .. ..r.~.r-- 10432' 411 HES XN N1P, tD tr~(led to = 3.80" ~... '~ (1444' 4112" VYLEG, ID = 4.00" 1044{I' ~ ~-At~} Tf LQGGFD 0~t118195 '103&5° 3-3118", h.21t,L--80, T`C-II LAIR w J turbuss ~ ~s7fi`~ ~; ~~", s 1 , c sTL 1 ~' MM~,rx~: ~ .r~,t ---{ PBTD ~ ~ oso0• A DATE REV BY COMMENTS DATE RE11 BY GCIMMENT5 07124/82 Of2ICsINAL CQMPlE71QN 0d1a9195 RtG SIDETRACK 09/18/03 AS/WLP RENAME 18-02Q 70 18-02A 08/19/09 AECSRfNC 1 CTD S1DEfRACK {18-0;281. 08/22/09 P.SC DRLG HO GORRECTfON5 PBTD 11203' `~"~ 2-718", 6.16#, L-t3(k, ~STL CNr ~t1 turbos PRUDFIOEBAY UNfC WELL: 18-028 PERMTT No: 2{'9046 API No: 50-029-20762-02 5irG 24, T11 N, R14E, 3380' NSL ~ 131 ` VVEC. BP Exptaratinn (Ataska) • P/®® BAKER M Vl~MES Baker Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLURA"1'lUN (ALASKA) 1NC CUUN"1'Y NUR'1'H SLUYE BURUUGH WELL NAME 18-02B STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 11/4/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2732222 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKAI INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston. Texas 77073 This Distribution List Completed Bv: g ~6 ~~ g",. ., ~ ~ NOV 0 5 20Q9 rr~~~~ ~~~ ~s ~~~ ~~Il~. c ,o,. :~nc~1~Ia Page 1 of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7~h Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 18-02B Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) `" 1 LDWG lister summary '` 1 color print - GR Directional Measured Depth Log (to follow) `' 1 color print - GR Directional TVD Log (to follow) ''" LAC Job#: 2732222 Sent by: Catrina G 'dry Date: 11/04/Q9 ~, Received by: r Date: PLEASE ACKNOWLEDGE RECEIPT BY~S~~'~ A ING -arc ~ ~ ,. OR FAXING YOUR COPY FAX: (907) 267-6623 _ Baker Hughes INTEQ ~/~® 7260 Homer Drive B~ Anchorage, Alaska 99518 1 Direct: (907) 267-6612 INTEQ FAX: (907) 267-6623 c~0~ ' ~~~ ~ ~~~~ ~~ Sehlumherger Alaska Data b Consulting Services 2525 Gambell Street, Suka 400 Anchorage, AK 99503-2638 ATTN: Beth Well Job B NO. 5405 Company: State o1 Alaska Alaska Oil 8: Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL r t,,, r•n K-11 - AY1 M-00033 SBHP SURVEY - L4-30 P2-31 AWLS-00031 AP3O-00045 PRODUCTION PROFILE LDL L ..~ 09/12/09 08/06/09 1 1 1 1 01-29 B6JE-00009 PRODUCTION PROFILE _ 07/11/09 1 1 J-22A B69K-00013 PRODUCTION PROFILE ~ 09/11/09 t 1 W-44 12-25 B14B-00071 8561-00010 INJECTION PROFILE INJECTION PROFILE 08/30/09 09/06/09 1 i 1 1 LS-33 P2-08 AYKP-00051 B69K-00015 SBHP SURVEY SBHP SURVEY 08/2Z/09 09/01/09 1 1 1 1 Z-28 B69K-00016 INJECTION PROFIL 09/01/09 1 1 O-02A N-t0A W-24 AP3O-00054 AxBD-00040 AWJI-00044 IBPA.DL _ ~ MEM PROD PR FILE MEM INJECTION PROFILE 09/19/09 07/24/09 08/25/09 1 1 1 1 1 1 V-03 H-14B P1-01 P1-05 NK-10 13-27A 18-028 82NJ-00021 B2WY-00026 AY1M-00031 8581-00009 B2WY-00023 B2NJ-00019 B2WV-00021 MEM PROD PROFILE O MEM PROD PROFILE INJECTK)NPROFILE PRODUCTION PROFIL MEM INJECTION PROFILE - G MEMORY SCMT MEMORY SCMT - 8115/09 09/03/09 08/27/09 08/20/09 08/20/09 08/22/09 08/13/09 1 1 1 1 1 1 1 1 1 1 1 1 1 1 NK-38A AYKP-00049 USIT ~ 08/19/09 1 1 06-09 13-03A SWLB-00028 09AKA0150 USIT OH MWD/LWD EDIT ~ 08/17/09 07/30/09 1 1 1 1 C-186 B2NJ-00017 MCNL - 07/06/09 2 1 1-35/0-25 B69K-00011 RST 08/09/09 1 1 04-35A AXED-00025 MCNL 08/26/09 1 1 05/13/09 1 1 PLEASE ACKNOWLEDGE REC EIPT BY SIGNIN G AND RETURNING ONE COPY EACH TO: Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Dafa 8 Consulting Services 2525 Gamhell Street, SuBe 400 Anchorage, AK 99503-2838 i /. 10/01/09 ~~ ,f u rL. Maunder, Thomas E (D4A) From: Maunder, Thomas E (DOA) Sent: Friday, September 25, 2009 3:25 PM To: Rixse, Mel G Cc: 'McMullen, John C' Subject: DS 18-02B (209-046) Page 1 of 1 Mel and John, have just completed reviewing the 407 submitted for this well. Very interesting after 10720'. Is this the most severe lost circulation case you have encountered? The memory compensated neutron log is in our file, however I don't find a copy of the SCMT/PITS log run on 8/18. Would you please send in a copy? PDS is fine. Thanks in advance. Tom Maunder, PE AOGCC 9/25/2009 ~~ PLQL Data Manager Files Pass # 1: Repeat Pass 30 FPM Down Pass # 2: Main Pass 30 FPM Up Pass # 3: Warmback Pass 30 FPM Down. Pumped 100 bbls down the coil, then waited 60 mins before logging. Output DLIS Files DEFAULT SCMT_PSP_034PUP FN:39 PRODUCER 19-Aug-2009 12:47 11139.5 FT 10317.0 FT OP System Version: 16C0-147 MCM SCMT-CB SRPC-3778-Q1_2009_OP16 PSRP-A/B SRPC-3778-Q1_2009_OP16 Warmback Pass 30 FPM Down _ _ _ ~03CVL~ _ r- -- --- -200 (F/MN) 200 Gamma-Ra 01 P01LGR 0 (GAPI) 100 CCL 01 P01CCL Fluid Tem Re eat Pass 30 FPM Down P01TMP -19 (V) 1 110 (DEGF) 150 Re eat Pass 30 FPM Down P01CVL _ Fluid_Temp Main_Pass 30 FPM Up,P02TMP) !-200 (F/MN) 200 110 (DEGF) 150 ... Main Pass 30 FPM Up (P02CVL~ __ -200 (F/MN) 200 _ _ _ _ Fluid Temp Warmback Pass 30 FPM Down ~P03TM~ _ _ _ _ 110 (DEGF) 150 TOL XO 10400 RA Ta 105D0 10600 10700 I OS ~-~~~ GO' 10800 T 3 3/16" Liner to 2 7/8" Liner °o °o rn o o X 11100 Main Pass 30 FPM Up (P02CVL) -200 (F/MN) 200 _ _ _ _ Fluid Temp Warmback Pass 30 FPM Down ~P03TMt~ _ _ _ _ ~ !, 110 (DEGF) 150 Re eat Pass 30 FPM Down P01CVL Pass 30 FPM_UpSP02TMP)________ _ _ Fluid Temp Main -200 (FIMN) 200 __________________ _ 110 _ (DEGF) CCL 01 P01CCL Fluid Tem Re eat Pass 30 FPM Down P01TMP -19 (V) 1 110 (DEGF) Gamma-Ra 01 P01LGR 0 (GAPI) 100 Warmback Pass 30 FPM Down _____ P03CVL ___ ~--~-- -200 (FIMN) 200 Parameters DLIS Name Description PSRP-A/B: Production Services Recorder Platform Description of this pass CSID Casing Size I.D. PLQL: Production Logging Quick Look CCLS CCL Selector FCHD Cased Hole Diameter Selector PCVS CVEL Selector PGRS GR Selector PGS Pressure Gauge Selector PWHS PLQL Water Holdup Selector RHOS Fluid Density Selector SPIS Spinner Selector TMPS Temperature Selector System and Miscellaneous DO Depth Offset for Playback PP Pla back Processin Value 6.5 IN CCLC PARAMETER CVEL GR WPRE NONE WFDE SPIN WTEP -58.0 FT NORMAL Format: TEMP OVERLAY Vertical Scale: 5" per 100' Graphics File Created: 19-Aug-2009 12:47 OP System Version: 16C0-147 MCM SCMT-CB SRPC-3778-Q1_2009_OP16 PSRP-A/B SRPC-3778-Q1_2009_OP16 Output DLIS Files DEFAULT SCMT_PSP_034PUP FN:39 PRODUCER 19-Aug-200912:47 .,..~...y ..~.y... ......,.,. Expected CBL Amplitude 104 MV in Free Pipe Section Master Calibration (Normalization) Date of Master Calibration 8-MAY-2009 Minimum Sonic Amplitude MAP Minimum Sonic Amplitude Before Calibration (Adjustment) 0.342856 MV (100% Cement) 1.07522 MV (80% Cement) 2.53559 MV (100% Cement) 5.28766 MV (80% Cement) CBL Correction Factor 0.0667218 CBL Adjustment Factor (CBAF) 1.0 MAP 1 Correction Factor 0.111526 MAP Adjustment Factor (MPAF) 1.0 MAP 2 Correction Factor 0.110741 MAP 3 Correction Factor 0.105268 MAP 4 Correction Factor 0.0978471 MAP 5 Correction Factor 0.0955324 MAP 6 Correction Factor 0.0928002 MAP 7 Correction Factor 0.0890086 MAP 8 Correction Factor 0.0933254 Parameters DLIS Name Description Valu e SCMT-CB: Slim Cement Mapping Tool, 1-11/16 OD BILI Bond Index Level for Zone Isolation 0.8 C63D SCMT CBL 3 ft Peak Detection Mode PEAK CB3G SCMT CBL 3 ft Peak Detection TO Delay and Noise Gate 202.93 US CB3T SCMT CBL 3 ft Fixed Threshold Level 20 MV C65D SCMT CBL 5 ft Peak Detection Mode PEAK CB5G SCMT CBL 5 ft Peak Detection TO Delay and Noise Gate 316.93 US C65T SCMT CBL 5 ft Fixed Threshold Level 20 MV CBLG CBL Gate Width 40 US CBRA CBL LQC Reference Amplitude in Free Pipe 104 MV CMCF CBL Cement Type Compensation Factor 1 CMTC SCMT Slow Channel Multiplexer Mode SCAN CMTM SCMT Operating Mode LOG CSCS SCMT Slow Channel Index VCC CTHI Casing Thickness 0.216734 IN DTF Delta-T Fluid 203 US/F FATT Acoustic Attenuation due to Fluid 0 DB/F FCF CBL Fluid Compensation Factor 1 GOBO Good Bond 1.07522 MV MAPD SCMT MAP Peak Detection Mode PEAK MAPG SCMT MAP Peak Detection TO Delay and Noise Gate 145.93 US MAPT SCMT MAP Fixed Threshold Level 30 MV MATT Maximum Attenuation 19.6263 DB/F MCCF MAP Cement Type Compensation Factor 1 MCI Minimum Cemented Interval for Isolation 1.25 FT MMSA MAP Minimum Sonic Amplitude 2.53559 MV MSA Minimum Sonic Amplitude 0.342856 MV PEDE Peak Detection On/Off Switch in Playback OFF VDLG VDL Manual Gain 5 ZCMT Acoustic Impedance of Cement 6.8 MRAY PSRP-A/B: Produc tion Services Recorder Platform Description of this pass System and Miscellaneous DO Depth Offset for Playback 46.0 FT PP Playback Processing NORMAL TD Total Depth -50000 FT Input DLIS Files DEFAULT SCMT PSP 008PUP FN:9 PRODUCER 19-Aug-200 910:57 11170.1 FT Output DLIS Files 10271.7 FT DEFAULT SCMT_PSP_012PUP FN:16 PRODUCER 19-Aug-200911:27 CUSTOMER SCMT_PSP_012PUC FN:17 CUSTOMER 19-Aug-200911:27 Page 1 of 1 Maunder, Thomas E (DOA) From: Rixse, Mel G [Mel.Rixse@bp.com] Sent: Friday, September 25, 2009 4:54 PM To: Maunder, Thomas E (DOA) Cc: McMullen, John C Subject: RE: DS 18-02B (209-046) Attachments: Main Pass 2 875 Iiner.PDF; Temperature Overlay.PDF Tom, We have drilled with total losses before. Sometimes we have cuttings buildup in the loss zone which can cause us hole problems. We did not see that on this well. It was short enough that we may have not had the time or volume. Attached are the logs in PDF form. Do you need the logs in the SLB viewer form? Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564-5620 -Office (907)223-3605 -Cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, September 25, 2009 3:25 PM To: Rixse, Mel G Cc: McMullen, John C Subject: DS 18-02B (209-046) Mel and John, I have just completed reviewing the 407 submitted for this well. Very interesting after 10720'. Is this the most severe lost circulation case you have encountered? The memory compensated neutron log is in our file, however I don't find a copy of the SCMT/PITS log run on 8/18. Would you please send in a copy? PDS is fine. Thanks in advance. Tom Maunder, PE AOGCC 9/30/2009 Company: BP Exploration (Alaska), Inc. ~ Well: 18-028 Input DLIS Files DEFAULT SCMT_PSP_008PUP FN:9 PRODUCER 19-Aug-2009 10:57 11170.1 FT 10271.7 FT Output DLIS Files DEFAULT SCMT_PSP_012PUP FN:16 PRODUCER 19-Aug-2009 11:27 11216.0 FT 10318.0 FT CUSTOMER SCMT_PSP_012PUC FN:17 CUSTOMER 19-Aug-2009 11:27 11216.0 FT 10318.0 FT OP System Version: 16C0-147 MCM SCMT-CB SRPC-3778-Q1 2009 OP16 PSRP-A/B SRPC-3778-Q1 _2009_OP16 PIP SUMMARY F Time Mark Every 60 S Discriminated CCL .............................................................. ..... ...... CCLD GoodBond -15 (V) 1 ~~ ~ From ACBL to.GOBO..;.;~:~;~:~;~;~;~;~;~;~;~; Transit Time TT Good Bond GOBO '400 (US) 200 0 (MV) 10 Gamma Ra GR ._ CBL Amplitude (CBL).._ 0 (GAPI) 100 0 (MV) 100 Min Amplitude Max . _ ......Cable Speed (CS~__ __ .____. ~ CBL Am litude CBL ;~;r 200 0 (F/MN) 0 (MV) 10 VDL VariableDensity (VDL) 0 (US) 1000 -LR- TOL ~-•Y 8 ~' tl~1 "^}1(~ ~~! ry 1;16 R+~ 4?r, k I* ~I$m .i~t ~~~ ~ °ik na~t~N ~~. '~~ ~'~x °~~~Ry~ ~~. . ~~ K " ~'.`~C'+snl~-1 '~' ~ '~s as.~c .f ~~== !gK i' z~ .u. _;. r.. ... .... ., .^. ~ i I I ~ ~i i I ~i ~ ~ ~i i ~ '~ ~ ~ I~ / I ~ I 1 1 / • r 1 y fV Q 0 ~~ i o ~ ~J o Q -~X~ ~ r ~_ J ti N o 0 0 w +r O L d C J tD r M M II+C_I\LJ..JCJaJ/_L-I]Jil~+~1:~1.1-I.J.t~4.I..1.Jr~L.i~1..CJ.1\J~/-111~LV[J.~.I-a-~-I-a-{-I--I,#-F-I-{=1~.Y-k•I•J-i•F-I-i-I-a-{-I-i-h•I-a•l"~Ir~~~•1-I•.I.i.h.l.{.h•I•.I Fi-i•F-I-i•h-I•i•h-I•i•F•hi•f-hy•i-h•I•t•F•I•t•h'y-t•I'-I.1• x .+.L.I•{.F•I.i.Y•I`{•F.l`{F.1•ih.1.i•M.1.i1.Yy•{•Y•I.i.F•1.iF•I.{f.1.H•Y•I.H•f•I•N.t`Y•I.i•YY•{.Y•I.i.l`i•Y•I•i•Y•I•i•f•I•f.f.l•i•Y`I.'I.f`I`y`}•MM•i•Y1•i`Y.I•f•Y`I.1I•I'y`!•I•Y•!•I•Y•!•P Y•!•Y •I. i•F y•i•I. •I•i• 0 0 0 0 rn o o n s _ ~ 11100 v ~ t ~~ ~ ~, ~ K IFL i ~ s p ~ ~ ~ ~ ~ t . : ~. . „ # ~ . ' f ~ ~ _ .__ - .°€ 9a. ~d ~ ~ r " f' y "bb ,,. F *7 : { w., ~'* t.' 4 : 3 u J z --- ~ k ~`r e'en ~ ~ ~` ~ ~ a . .~ ' ;, -FR- ~~~ ~~r ~ ~{ 1 - . ~ ~ ~~ »` ~ 11200 ~ ~$ Min Amplitud e Max _ _ ._ ...Cable Speed_(_CSI..__ _ ~ ~ ~ ~ _.., CBL Am litude CBL ut. (F/MN) 0 200 0 (MV) 10 VDL VariableDen sity (VDL) 0 (US) 1000 GammaRa GR .._ .CBL Amplitude_(C__B_L)_ ._ ~ ~ ~ 0 (GAPI) 100 0 (MV) 100 Transit Time TT Good Bond GOBO 400 (US) 200 0 (MV) 10 Discriminated CCL ...... .. ...... CCLD GoodBond :.:.:...:::::.::.::.: '~ -15 (V) 1 ~:~::~:.From.QC.B4..tQ.G9~0.~:~:~:~:~:~:~:~:~:~:~:~:~: . .. '.. '.PIP .SUMMARY . . F Time Mark Every 60 S Format: CBL VDL Vertical Scale: 5" per 100' Graphics File Created: 19-Aug-2009 11:27 OP System Version: 16C0-147 MCM SCMT-CB SRPC-3778-Q1 2009 OP16 PSRP-A/B SRPC -3778-Q1 2009 OP16 «<SCMT Cement Evaluation Information Summary»> Sonde Serial Number SCMS-CB 8155 Current Casing Size 2.87500 IN r~~~.,., wo~..h• a SRAM 1 R/F Schlum6erger Alaska Data 8 Consulting Services 2525 Gambell Street, Suke 400 Anchorage, AK 99503-2938 ATTN: Bath Well Job M N0.5353 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD V-02 B2WY-00018 MEM PRODUCTKN PROFILE 07/27!08 1 1 W-26A H-32 B1JJ-00033 ANHY-00102 MEM PRODUCTKN PROFILE ~ PRODUCTION PROFILE L - 07/26/09 07/25/09 1 1 1 1 P2-29 AYTU-00052 INJECTION PROFILE '~ - 08/02/09 1 1 L2-11 ANHY-00106 LDL 08/02/09 1 1 L2-O6 869K-00007 CROSS FLOW CHECK 07/31/09 1 1 P2-28 L-213 AYTU-00051 82WV-00019 INJECTION PROFILE L - MEM INJECTION PROFI E 08/01/09 07/29/09 1 1 1 1 V-221 AXBD-00037 MEM INJECTION PROFILE - 07/28/09 1 1 L-220 BiJJ-00035 MEM INJECTKN PROFILE 07/30/09 1 1 07.22 AZCM-00036 PRODUCTON PROFILE - ~ 08/09/09 / 1 04-02A AYS4-00091 USIT 08!11/09 1 1 J-11A AWLS-00029 USIT 08/05/09 1 1 L1-09 AYS4-00088 PRODU TION PROFILE _Qp 08/08/09 1 1 X-28 AXBD-00026 MEM INJECTION PROFILE lJ' 05/17/09 1 1 L2-O6 B3S0-00020 PRODUCTION PROFILE 08/14/09 1 1 3-29/J-32 AP30-011055 IBP SET RECORD W/CROSSGLOW ~ 08/08/09 1 1 06-04A BSJN-00009 RST 08/23/09 1 1 15-098 B2NJ-00013 MCNL 07/15/09 1 1 03.328 09AKA0030 OH MWD/LWD EDIT 02/28/09 2 1 G•14B AWJI-00043 MCNL 07/24/09 1 1 L2-13A AWJI.00036 MCNL 06/17/08 1 18.028 AWJI-00045 MCNL ~ 08/17/09 1 1 P1-OS AWLB-00032 RST 08/09/09 1 1 B-16A B2WY-00020 MCNL Q ~ 08/03/09 1 1 J•208 AXED-00020 MCNL (REVISED) - ~ pr' ~`l. ' 04/12/09 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Sude 400 Anchorage, AK 99503-2838 osn vos h; ti u • ~~ STATE OF ALASKA ALASKA AND GAS CONSERVATION COMM ION ~ , .i WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC 2s.~os zoa+c zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., sp., or Aband. 8 6%2009 ~~ 12. Permit to Drill Number 209-046 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/14/2009 i 13. API Number 50-029-20762-02-00 / 4a. Location of Well (Governmental Section): Surface: ' 7. Date T.D. Reached 8/15/2009 / 14. Well Name and Number: PBU 18-02B ~~ FEL, SEC. 24, T11 N, R14E, UM 3980' FSL, 131 Top of Productive Horizon: 51' FSL, 1202' FEL, SEC. 24, T11N, R14E, UM 8. KB (ft above MSL): 46.6' Ground (ft MSL): ~ ~D~ 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 226' FSL, 1412' FEL, SEC. 24, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 11203' 8849' Oil Pool F 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 691638 ~ y- 5960565 'Zone- ASP4 10. Total Depth (MD+TVD) 11251' ,~8~4` 6. Property Designation: ADL 028307 ~ 028308f TPI: x- 690667 y_ 5956611 Zone- ASP4 5956780- Zone- ASP4 690453 th T t l D 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: : x- . y- o a ep 18. Directional Survey ®Yes ^ No mi I roni n rin ed informati n er 20 AA 0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD DIR, GR, RES, GR / CCL / CNL /~-S~l'~ BSS 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM :SIZE CEMENTING RECORD PULLED 20" 91. H-40 Surface 80' Surface 80' 30" 2256 # Poleset - / " 7 # L- rf 2 14' 2 4' 1 - /2" x Fond 4 PF ' ' - /8" 47# L- 0 Surf ce 8960' urfa 72 12-1/4" x CI s 'G' 50 Bbls PF' ' 7" 2 -80 8781' 7087' 8647' 8-1/2" 459 x lass' ' 3-1/2" x 3-3116" .2# / 6 # L- 1 1 1124 ' 847 ' S3' 4-1 / " s I ' x 2-7/8" / 6.1 23. Open to production or inject ion? ®Yes ^ No 24, TusING RECORD If Yes, list each i & B P TVD f T tt nterval open mb r ti Si d N f SIZE DEPTH SET MD PACKER SET MD ): on ze an u e om; er ora (MD+ op o o 6 spf 2" Gun Diameter 4-1/2", 12.6#, L-80 10444' 10398' , MD TVD MD TVD 11050' - 11140' 8829' - 8842' 8847 8 ' 8845' ' 2~j, ACID, FRACTURE, CEMENT .SQUEEZE, ETC. 11165 - 111 - 5 DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protected w/ 40 Bbls of Diesel 26, PRODUCTION TEST Date First Production: August 27, 2009 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date Of Test: 9/1 /2009 HOUfS Tested: 5 PRODUCTION FOR TEST PERIOD OIL-BBL: 256 GAS-MCF: 7,988 WATER-BBL: 6 CHOKE SIZE: 64 GAS-OIL RATIO: 31,139 Flow Tubing Press. 751 Casing Press: 900 CALCULATED 24-HOUR RATE. OIL-BBL: 1,231 GAS-MCF: 38,341. WATER-BBL: 28 OIL GRAVITY-API (CORK): Not Available 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewall Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None ~~~~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~w ry 1 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MA S ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? Yes ®No -Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Base CGL /Zone 2C 10495' 8647' None 23SB /Zone 26 10562' 8708' 22TS 10629' 8754' Zone 1 B 10720' 8780' TDF /Zone 1A 10975' 8818' Base Sadlerochit 11227' 8852' Formation at Total Depth (Name): Base Sadlerochit 11227' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoi g is true and correct to the best of my knowledge. Q Q/~ Signed Terrie Hubble Title Drilling Technologist Date PBU 18-02B 209-046 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A rOV81 NO. Drilling Engineer: Mel Rixse, 56a-5620 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Operations Summary Report Legal Well Name: 18-02 Common Well Name: 18-02 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ~ From - To 'Hours Task I Code ~ NPT 8/12/2009 12:00 - 23:30 11.50 MOB P~- 23:30 - 23:45 0.25 MOB P 23:45 - 00:00 0.25 MOB P Start: 8/8/2009 Rig Release: 8/20/2009 Rig Number: N1 Page 1 of 9 Spud Date: 6/28/1982 End: 8/20/2009 Phase ' Description of Operations PRE Move from C-Pad to DS-18 via K-Pad road to West Dock. Check IA pressure. PRE PJSM for backing rig over well and setting down. PRE Back rig over wellhead and set down. RIG ACCEPT AT 00:00 8/13/2009 00:00 - 03:30 3.50 BOPSU P PRE NU BOPE. Fill Stack. 03:30 - 09:30 6.00 BOPSU P PRE Test BOPE to 3500 si & annular to 2500 psi. AOGCC witness waived by Chuck Sheeve. Bob Swab would not hold pressure initially, greased & cycled the valve several times then it held. Swab valve on the tree did not hold pressure. 09:30 - 10:00 0.50 RIGU P PRE Fill coil. 10:00 - 10:45 0.75 BOPSU P PRE Pressure Test Inner Reel Valve. 10:45 - 14:00 3.25 RIGU P PRE Pump slack back. Cut 400' of coil. MU CTC. Rehead eline. Pressure test and pull test connection. 14:00 - 15:00 1.00 STWHIP P WEXIT SAFETY MEETING, re: PU Milling BHA PU mills, motor, 2 jnts PH-6, & CoilTrak. 15:00 - 17:00 2.00 STWHIP N SFAL WEXIT SLB hydraulic pump for the packoffs failed in the Ops cab. Replace Haskel pump. 17:00 - 19:15 2.25 STWHIP P WEXIT RIH, pump 2-3 bpm through EDC to pump slack forward from surface to 3300' Continue RIH pumping minimum rate to 10,330' 19:15 - 20:15 1.00 STWHIP P WEXIT Log tie-in ass. - 10.5' correction 20:15 - 00:00 3.75 STWHIP P WEXIT RIH pumping min rate and tag WS at 10494.4 PU and bring pumps up to 2.5 in / 2.5 out and RIH, tag WS at FS 2692 psi 10493.7' 2.53 in/ 2.55 out 2750 psi ~~ 10494.3' 2.54 in/ 2.58 out 2772 psi 10494.5' 2.53 in/ 2.57 out 2805 psi 0.33k DHWOB 10495.0' 2.54 in/ 2.57 out 2802 psi 0.27k DHWOB 10495.6' 2.53 in/ 2.58 out 2823 psi 1.23k DHWOB 10496.3' 2.54 in/ 2.56 out 2864 psi 2.54k DHWOB 10496.6' 2.52 in/ 2.57 out 2904 psi 2.70k DHWOB 10497.0' 2.53 in/ 2.55 out 2941 psi 2.25k DHWOB 10497.4' 2.53 in/ 2.55 out 2944 psi 1.71 k DHWOB 10498.0' 2.52 in/ 2.51 out 2772 psi 1.08k DHWOB 10498.4' 2.51 in/ 2.57 out 2805 psi 1.90k DHWOB 10.498.8' 2.50 in/ 2.55 out 2820 psi 2.81 k DHWOB 8/14/2009 00:00 - 05:35 5.58 STWHIP P WEXIT Continue Milling Window 10499.1' 2.49 in/ 2.53 out 2720 psi 2.15k DHWOB 10499.5' 2.53 in/ 2.59 out 2842 psi 2.61 k DHWOB 10500.1' 2.54 in/ 2.59 out 2966 psi 2.98k DHOWS 10500.5' 2.55 in/ 2.60 out 2978 psi 1.69k DHWOB 10501.0' 2.45 in/ 2.59 out 3015 psi 1.58k DHWOB 10501.5' 2.54 in/ 2.59 out 3038 psi 1.38k DHWOB 10502.0' 2.53 in/ 2.58 out 2853 psi 0.80k DHWOB 10502.5' 2.53 in/ 2.57 out 2897 psi 0.98k DHWOB Presumed BTM of Window. Wlndow 10494.5'to 10502.5' 10503.5' 2.53 in/ 2.57 out 2908 psi 1.39k DHWOB Printed: 9/1/2009 10:12:41 AM s BP EXPLORATION Page 2 of 9 Operations Summary Report Legal Well Name: 18-02 Common Well Name: 18-02 Spud Date: 6/28/1982 Event Name: REENTER+COMPLETE Start: 8/8/2009 End: 8/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date I' From - To ~ Hours Task ~ Code ~ NPT ~ Phase Description of Operations 8/14/2009 00:00 - 05:35 5.58 STWHIP P WEXIT 10505.5' 2.51 in/ 2.54 out 2889 psi 1.79k DHWOB String reamer is out window Mill rathole to 10,511.7' 05:35 - 06:00 0.42 STWHIP P WEXIT PU, RIH and ream down through window. PU, RIH and dry drift through window three times. Extend Rathole to 10513' 06:00 - 07:15 1.25 STWHIP P WEXIT POOH with window milling BHA. 07:15 - 08:45 1.50 STWHIP P WEXIT SAFETY MEETING, re: BHA swap L/D Milling BHA, Mills gauged 3.80" go / 3.79" no go. PU Build Drlg BHA. Stab on injector. 08:45 - 09:45 1.00 DRILL N DFAL PROD1 Short detected in CoilTrak LOC. Unstab injector & C/O LOC. 09:45 - 11:45 2.00 DRILL P PROD1 RIH Build Drlg BHA, 3.4 deg mtr, HYC BC bit 11:45 - 12:10 0.42 DRILL P PRODi Log Tie-In, -13.5 'correction. Start reconditioned Geo-Vis system downhole. 12:10 - 13:40 1.50 DRILL P PRODi RIH, dry tag TD at 10514' Drill Build/Turn at 2.5 bpm-in/ 2.5 bpm-out ~ 2860 psi, 2600 psi FS 1.2k-2.3k# DHWOB, 30-35 fph, 9.9 ppg ECD IA = 266psi, OA=O, SEVXYX= 2 to 5 Drill to 10544'. Short wiper. 13:40 - 15:40 2.00 DRILL P PROD1 Drill Build/Turn at 2.2bpm/2.2bpm ~ 2860 psi, 2600 psi FS 0.9-i.ik# DHWOB, 25-42 fph, 9.9 ECD IA=332, OA=O, SEVXYX=2 to 5 Drill to 10573'. 15:40 - 18:10 2.50 DRILL P PROD1 Drill Build/Turn at 2.5bpm/2.5bpm ~ 2800 psi, 2650 psi FS 0.9k-1.6k# DHWOB, 25-90 fph, 9.9 ECD IA=332, OA=O, SEVXYX=2 to 5, PVT=308 Centrifuge aerated mud up to 328 bbls. Drill to 10,690.3 18:10 - 19:10 1.00 DRILL P PROD1 POOH. Slow down, pump min rate while pulling through the window. Continue to POOH. 19:10 - 19:25 0.25 DRILL P PROD1 SAFETY MEETING. PJSM for popping off injector, laying down motor, adjusting AKO, PU and stabbing on. 19:25 - 20:40 1.25 DRILL P PROD1 Pop off inj, pull tools out. Break off bit 3-2-WT-S-X-I-BT-BHA. Lay down motor, adjust AKO from 3.4 to 1.2. MU motor and rebuilt 4-bladed HCC with new "Cheetah" cutters. Stab on inlec or. 20:40 - 22:45 2.08 DRILL P PROD1 RIH circ through EDC at 2.6 bpm. 22:45 - 23:15 0.50 DRILL P PROD1 Close EDC and log tie in pass (-13' correction). 23:15 - 23:30 0.25 DRILL P PROD1 Cont. RIH circ at 2.55 bpm. FS 2692 psi 23:30 - 23:45 0.25 DRILL P PROD1 Drill ahead from 10690' 3080 psi, 0.82 DHWOB, 2.55/2.64 ROP 140-150'/hr, ECD 2.68, PVT 318 23:45 - 00:00 0.25 DRILL P PROD1 Bottom fell out at 10,720' returns dro to 2.49 in / 0.71 out No healing, after -10 min. 2.05 in / 0.03 out Drilling ahead at 2.09 in / 0.04 out. 120 - 150 fph. 8/15/2009 00:00 - 00:55 0.92 DRILL P PROD1 PU for short wiper and survey, 8k overpull. Drill ahead at 10,820', 2.10 in, no out. 30-70 fph. 00:55 - 01:50 0.92 DRILL P PROD1 PVT down to 160 bbls. Pull up into casing and pump min rate until fluid arrives. 01:50 - 02:00 0.17 DRILL P PROD1 Head back to bottom to drill while CH2M rigs up to fill pits. 02:00 - 02:50 0.83 DRILL P PRODi Drill ahead at 2.0/0.0 2084 psi 2.04 DHWOB 120-150 fph F'flfltEO: `J/1/LUU`J IU:l C:41 HM ~ ~ BP EXPLORATION Operations Summary Report Page 3 of 9 ~ Legal Well Name: 18-02 Common Well Name: 18-02 Spud Date: 6/28/1982 Event Name: REENTER+COMPLETE Start: 8/8/2009 End: 8/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 8/15/2009 02:50 - 03:10 0.33 DRILL P PROD1 Wiper back from 10928 to 10700' 03:10 - 05:40 2.50 DRILL P PROD1 Drill ahead. 1.98 in / 0.0 out ROP 30-100 fph, ECD 8.9 ppg, 1.5k DHWOB 05:40 - 05:55 0.25 DRILL P PROD1 PU 23k overpull off bottom. Wiper from 11,010 to 10,520'. 05:55 - 09:10 3.25 DRILL P PROD1 Drill ahead from 11,010' on seawater 09:10 - 09:45 0.581 DRILL i P 09:45 - 10:15 0.501 DRILL ~ P 10:15 - 11:50 I 1.581 DRILL I P 11:50 - 12:05 0.25 DRILL P 12:05 - 12:25 0.33 DRILL P 12:25 - 14:15 1.83 DRILL P 14:15 - 14:30 0.25 DRILL P 14:30 - 14:45 0.25 DRILL P 14:45 - 15:45 1.00 DRILL P 15:45 - 16:45 1.00 DRILL P 16:45 - 17:00 0.25 DRILL P 17:00 - 19:10 2.17 DRILL P 19:10 - 20:00 0.831 DRILL P 20:00 - 21:20 1.33 DRILL 21:20 - 23:25 2.08 CASE 2.20/0.0, 1388 psi, 8.64 ECD ROP 30-100 fph, 0.25k-0.66k# DHWOB Drill to 11100' until 15 bbl Geo-Vis sweep at the bit. PROD1 Wi er to Fault. PU Weight is 48k#. Overpull 20k at a shale at 10780'. Overpull 10k twice before orienting past. PUH to 10700'. PROD1 Drill ahead on seawater. 2.6/0.0 ?~ 2300 psi, 2160 psi FS 1.Ok# DHWOB, 160 fph, 7.6 to 7.9 ppg ECD IA=371, OA=132, PVT=220 Differential sticking at 11150'. Frequently losing charge pump pressure, wiper to window while troubleshoot the pump. PROD1 Wiper to window. Pull up to 10400'. Open EDC and pump to establish returns at 3.5 bpm, 2200 psi; decrease to 2.00 bpm C~ 440 psi (well is on a screamin vac . No returns. Close EDC. Pump 30 bbl down the backside. PROD1 Log tie-in at 10,500'. +4' correction. PROD1 Wiper to TD. PROD1 Drill ahead on 2% KCL. 2.5/0.0 C~ , 1170 psi FS 0.3k# DHWOB, 135 fph, 7.9 to 8.15 ECD IA=361, OA=O, PVT=235 trickle of returns once BOBD, -0.1 bpm; lost returns about 11,200') Drilled into the Kavik 11 227' and drilled with reconditioned FloPro. TD called at 11254'. PROD1 Wiper to window. PRODi Log tie-in, +1' correction. PROD1 Wi er to TD. Ta at 11254'. Wiper back up to below window then to TD to ensure hole cleaning. PROD1 POH la in in liner runnin ill. PROD1 PUH to 10460' and fill backside. PROD1 POH pumping 2 bpm down backside. Stop at 4300' and pump 10 bbls to assure backside stays full. PUH to surface. PROD1 Tag-up. Pump down backside to see if we can fill hole while offloading some of Inteq's tools and loading the shed with liner. Pum ed 60 bbls. Never cau ht returns or filled hole. PROD1 Pop off injector and break off tools. Lay coilTrack tools out. Bit 1-3-BT-X-I-WT-TD. RUNPRD PU 1 jt of PH6. Stab on well and pump slack out of coil at 4.5 - 5 bpm. SLB says they hear it zing. Unstab, no wire. Re-stab. Pump at 4.5 bpm. Hear it zing then stop. Surge pumps. Pop off, pull F'rlllt8tl: `J/1/'LUUy IU:l L:41 HM BP EXPLORATION Operations Summary Report Page 4 of 9 ~ Legal Well Name: 18-02 Common Well Name: 18-02 Spud Date: 6/28/1982 Event Name: REENTER+COMPLETE Start: 8/8/2009 End: 8/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To ~ Hours Task i Code ~ NPT I Phase I Description of Operations 8/15/2009 121:20 - 23:25 2.081 CASE 23:25 - 00:00 0.581 CASE 18/16/2009 100:00 - 00:30 0.501 CASE P 00:30 - 00:45 0.25 CASE P 00:45 - 04:30 3.75 CASE P 04:30 - 06:30 2.00 I CASE P 06:30 - 07:40 1.171 CASE P 07:40 - 09:30 1.831 CEMT P 09:30 - 09:45 0.25 CEMT P 09:45 - 11:50 2.08 CEMT P RUNPRD 385' of a-line out and cut. Cut off SLB CTC, MU BOT CTC. Pull test to 35k. PT to 3500 psi. RUNPRD Continue to strap and drift liner. Begin prepping floor to run liner. RUNPRD Continue strapping/drifting liner and prep rig floor. Load BOT tools to floor. RUNPRD SAFETY MEETING. PJSM for MU and running liner. RUNPRD MU Liner and Stab on injector. 2-7/8" Indexing Shoe, 1 jt 2-7/8" STL w/ turbo, 2-7/8" Ported Pup Jt, Float, Float, 2-7/8" STL pup, Landing collar, 2-7/8" STL pup, 2-7/8" Stage Collar 10 jts 2-7/8" 6.16# STL L-80 LINER w/turbo, 2-7/8" STL pup, XO 3 3/16" TCII x 2-7/8" STL, 15 Its 3-3/16 6.2# L-80 TCII Liner w/ turbos, XO 3 1/2" STL x 3-3/16" TCII, 1 jt 3-1/2", 8.81#, L-80, STL Liner, 3-1/2 STL 10' Pup, Liner deployment sleeve. Liner Length = 913.73' BOT SELRT, XO, Hyd Disco, XO, 2 jts 2-3/8' PH-6, XO, Swivel, XO, BOT CTC Total BHA = 987.69' RUNPRD RIH while pumping 0.83 BPM down coil. Check PU above window, 47.6k. Bobble at 10,950' RIH to 11,268'. Check PU wt, 52k. RUNPRD Shift change, RU cementers, Fill backside with 40 bbl 1 %KCL, 8.3 ppg RUNPRD SAFETY MEETING, re: launching ball Launch 5/8" AL ball with 1000 psi, 3 bbl Bio ahead & 7 bbl behind. Pump ball at 2.5 bpm, 1600 psi. Slow to 1.0 bpm at 35 bbl away (56.2 bbl Coil Vol). Ball on seat at 50.8 bbl, sheered at 2000 psi. Stack 10k# at 11,270'. Circulate 1 %KCL at 2.5 bpm, 1500 psi RUNPRD SAFETY MEETING, re: Cement Job RUNPRD Batch up 14 bbl of 15.8 ppg Class G cement w/ arrtifoam, dispersant, GASBLOK, & retarder. Thickening time of 3 hr 27 min to 70 Bc. Compressive strength of 500 psi in 6 hr 27 min. Cement at weight ~ 10:00 PT Cement lines to 6500 psi w/ KCL Pum 14.0 bbl cement. Shut down pumps, clean up cement lines. Vol in, Pump rate in/out, Pressure 6 bbl cmt, 1.5/0.0 bpm, 500 psi 12 bbl cmt, 1.5/0.0 bpm, 610 psi 14 bbl cmt, 1.5/0/0 bpm, 700 psi In MM total = 14.1 bbl cmt Zero In MM Clean up cement lines w/ 2# Bio 1 %KCL Displace cement w/ 2# Bio 1 %KCL Vol 2# Bio, Pump rate in/out, Pressure rnncea: ai uzuuy iv: icv i rwi • BP EXPLORATION Page 5 of 9 ~ Operations Summary Report Legal Well Name: 18-02 Common Well Name: 18-02 Spud Date: 6/28/1982 Event Name: REENTER+COMPLETE Start: 8/8/2009 End: 8/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task 8/16/2009 09:45 - 11:50 2.08 CEMT Code I NPT I Phase P RUNPRD 5 bbl, 2.2/0 bpm, 1110 psi 13 bbl, 2.2/0 bpm, 990 psi 13.5 bbl, 2.6/0 bpm, 1600 psi 20 bbl, 2.7/0 bpm, 1400 Decrease pumprate to keep from shearing liner wiper plug 22.0, 1.7/0 bpm, 374 psi 25.0 bbl, 1.7/0 bpm, 385 psi 28.0 bbl, 1.7/0 bpm, 380 psi 30.0 bbl, 1.7/0 bpm, 385 psi 34.5 bbl, 1.7/0 bpm, 380 psi 40.0 bbl, 1.7/0 bpm, 385 psi 45.0 bbl, 1.7/0 bpm, 385 psi 48.0 bbl, 1.7/0 bpm, 380 psi 49.2 calculated cement at shoe 50.5 bbl, 1.7/0 bpm, 380 psi 52.0 bbl, 1.7/0 bpm, 385 psi 53.5 bbl, 1.7/0 bpm, 385 psi 54.2 bbl, 1.7/0 bpm, 690 psi 55.0 bbl, 1.7/0 bpm, 700 psi Shut down pumps PU to breakover wt (43k#) at 11264', then PU to 11250'. Pump 5 bbls Open Baker choke, slack back into deployment sleeve & stack 10k#. Pressure up to 1770 psi to shear LW P, Zero IN MM 1.5 bbl, 1.0/0 bpm/0, 550 psi 2.5 bbl, 1.2/0 bpm/0, 600 psi 3.5 bbl, 1.2/0 bpm, 650 psi 4.5 bbl, 1.2/0 bpm, 810 psi 5.0 bbl, 1.2/0 bpm, 810 psi 5.5 bbl, 1.2/0 bpm, 815 psi 6.0 bbl, bump the plug Pressure up to 1600 psi and hold for 5 min. Ooen Baker choke & check floats, no returns so can't tell if Description of Operations Pressure up to 500 psi, unsting from liner. Cement In Place ~ 11:40 11:50 - 13:45 1.92 CEMT P RUNPRD Pump 1 bbl then POH at 60 fpm, pumping 1.0 bpm 2# Biozan 1%KCL Pump 3.0 bpm down backside from 6000' to surface. 13:45 - 14:45 1.00 CEMT P RUNPRD SAFETY MEETING, re: L/D Liner running tools & PU Cleanout BHA LD liner running tools 14:45 - 16:30 1.75 CEMT P RUNPRD PU Cleanout BHA w/ 16 stands 1-1/4" CSH & 2 jnts PH6 16:30 - 16:45 0.25 CEMT P RUNPRD Fill coil and circulate through ceanout assy to ensure it is clear of rust Fill back side w/ 30 bbl 1 %KCL, establish returns after 20 bbls. 16:45 - 19:00 2.25 CEMT P RUNPRD RIH circulating 1.0 bpm, no returns 42k# Up Wt ~ 10200' 19:00 - 19:30 0.50 CEMT P RUNPRD Returns started comin back, KCL ve uickl turned gas cut then all as. Diverted returns to Tiger Tank, brought rate up to 1.5 bpm. Notified pad operator of venting. Continued circulating rnrnea: ai vzv~a w: i cv i Hrvi • BP EXPLORATION Page 6 of 9 ~ Operations Summary Report Legal Well Name: 18-02 Common Well Name: 18-02 Event Name: REENTER+COMPLETE ..Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours ; Task Code NPT Spud Date: 6/28/1982 Start: 8/8/2009 End: 8/20/2009 Rig Release: 8/20/2009 Rig Number: N1 Phase Description of Operations 18/16/2009 119:00 - 19:30 0.501 CEMT ~ P 19:30 - 19:45 0.25 ~ CEMT ~ P 19:45 - 21:20 I 1.581 CEMT I P 21:20 - 22:00 0.671 CEMT ~ P 22:00 - 0.00 CEMT P 8/17/2009 00:00 - 00:15 0.25 CEMT P 00:15 - 00:30 0.25 CEMT P 00:30 - 02:00 1.50 CEMT P 02:00 - 02:15 I 0.251 EVAL I P 02:15 - 03:30 I 1.25 EVAL ~ P 03:30 - 05:00 1.50 EVAL P 05:00 - 06:15 1.251 EVAL ~ P 06:15 - 08:15 2.00 EVAL P 08:15 - 08:45 0.50 EVAL P 08:45 - 10:00 1.25 EVAL P 10:00 - 10:45 ~ 0.75 ~ EVAL ~ P 10:45 - 12:45 2.00 EVAL P 12:45 - 01:50 13.08 CASE P 01:50 - 14:25 12.58 CASE P 14:25 - 17:00 2.58 CASE P 17:00 - 18:50 1.83 CASE P 18:50 - 21:00 i 2.17 ~ CASE i P RUNPRD while choke pressure bled down. Consult with town and evaluated options. Decided to proceed once gas flow decreased. RUNPRD Headed back down to liner top, circulating 1.2 bpm in, no fluid returns 4-7 psi WHP. RUNPRD Tagged SELRT LWP bushing at 10,359.4' (uncorrected). Ease into bushing, mill ahead based on mtr work, PU twice when mtr work climbed. RUNPRD No more mtr work, RIH confirm that we are through bushing. PU and drift bushing twice. RIH at 1.10 in, 0 out, 4-7 psi WHP. Tag PBTD at 11229' (uncorrected). RUNPRD P .Pumping 1.42 in, 0 out, 4-7 psi WHP. RUNPRD Cont. POOH. RUNPRD PJSM for popping off injector and standing back CSH. RUNPRD LD PH6, Stand back 1.25" CSH, LD mill/motor. Circ across backside ~ 0.8 BPM, no returns. LOWERI PJSM for pulling SLB logging tools to floor and MU MCNL. Discuss source handling and running CSH. LOWERI Circ across backside ~ 0.8 BPM, no returns. Load SLB tools to floor. MU MCNL carrier and load source. MU Hyd Disco, XO, 15 stds of 1.25" CSH, XO, Hi-load Disco, DBPV, XO, 2 jts PH6, XO, Swivel, XO, BOT CTC. Total length 1024.95' LOWERi RIH with logging BHA pumping down coil at 1.24 bpm, no returns. Stop at 5,000' and match SLB CTU and logger depths. Cont. RIH. LOWERI Lo down w/ MCNL from 9850' to PBTD at 30 fpm. Tag PBTD twice at 11220' uncorrected Log up from PBTD to 9850' ~ 60 fpm. LOWERi POH 60 fpm, pumping 1.4 bpm. LOWERI Fill backside at surface 1.4 bpm. LOWERI Bullhead 320 bbls from surface down the backside at 4.5 bpm w/ choke closed. LOW ER1 Flow check well. Well continues to be on a vacuum. LOWERI SAFETY MEETING, re: S/B CSH & UD Logging tools Continuously pump 0.8 bpm down the backside while at surface. UD 2 jts PH6, S/B 16 stands of 1-1/4" CSH, Remove source from logging tool, & UD Logging tools RUNPRD SAFETY MEETING, re: PU LTP PU LTP, 10' 2-7/8" spacer pup, Disco, 2 jts PH6, & swivel. RUNPRD Circulate 30 bbls down the backside at 1.4 bpm. RUNPRD RIH w/ 45 KB Liner To Packer w/ 4" GS Profile RUNPRD Coil RIH Wt 26k; Up Wt 45k Set down at 10361' uncorr. Set 10k Down, 10363'. PU to breakover (10358') then to 10347'. RIH, Set down at 10361' uncorr. Set 10k Down, 10363'. Did not pressure up liner then PUH for fear of setting dawgs w/ differential pressure. PUH to 10327'. Load 5/8" aluminum ball into reel and launch away with 950 psi. and pump ball over gooseneck + 10bbls. RIH. Set down, PUH to stroking depth 10,355.6'. RUNPRD Wait 30 min for ball to fall on seat. Pressure up to 2100 psi to rnncea: ai uzuuy w: i cv i Hm i BP EXPLORATION Operations Summary Report Page7of9~ Legal Well Name: 18-02 Common Well Name: 18-02 Spud Date: 6/28/1982 Event Name: REENTER+COMPLETE Start: 8/8/2009 End: 8/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 8/17/2009 18:50 - 21:00 2.171 CASE P 21:00 - 21:30 21:30 - 22:15 8/18/2009 22:15 - 23:15 23:15 - 00:00 00:00 - 00:15 00:15 - 00:30 00:30 - 06:10 06:10 - 06:30 06:30 - 08:30 08:30 - 09:30 09:30 - 11:00 11:00 - 13:30 13:30 - 14:15 0.50 CASE P 0.75 CASE P 1.00 CASE P 0.75 CASE P 0.25 CASE P 0.25 CASE P 5.67 CASE P 0.33 PERFO P 2.00 PERFO P 1.00 CASE P 1.50 PERFO P 2.50 PERFO P 0.75 PERFO P 14:15 - 18:00 I 3.751 PERFOS, P 18:00 - 18:45 0.751 PERFOB~ P RUNPRD set slips. Stack 10k down, 10,359'. Pump 15 bbls KCI to start loadin backside then close choke and ressure u 2000 si on backside to PT LTP, 15 min 1937, 30 min 1930 psi. Bleed RUNPRD POH at 80 fpm, circ 2.3 bpm in with intermittent returns of KCI and air. RUNPRD Start takin hea returns of air some crude. Divert to TT. Park at 8000' and circ 100 bbls at 2.5 bgm to remove all air and ensure well is fluid acked.. RUNPRD POOH. circ 2.5 b m with full returns. PJSM for LD LTP running assy. RUNPRD Stand back 1.25" CSH. Start LD PH6 RUNPRD Continue LD PH6 and LTP running tools. RUNPRD SAFETY MEETING. PJSM over RIH with extra CSH and laying down jts. RUNPRD Prep floor. RIH with 47 stds of 1.25" CSH. POOH laying down 94 jts of 1.25" CSH. LOWERi SAFETY MEETING covering SLB & Nordic procedure to PU pert guns. LOWERI Prep floor to PU guns PU perf 7 pert guns. SAFETY MEETING, re: UD Guns UD 7 perf guns. RUNPRD Pressure Test Packer to 2500 si for 30 min from surface. Test is good. Chart test. LOWERI PU 7 Perf guns, 13 stds 1-1/4" CSH, & 2 jts LOWERI RIH Perf Assy pumping minimum rate. LOWERi Tag PBTD at 11211' uncorrected, stack 5k# PU to Breakover wt at 43k#, RIH Tag 11211', stack 5k# PU to BO wt 43k#, 11206' uncorr. Correct to 11202', bottom shot depth (PBTD - 1.14'). Practice cyc ing t e pumps a different rates. Pump firing sequence. Shoot on depth creeping up hole. Bottom shot at 11185'. Good electronic shot detection and observed sharp pump rate decrease. Perf Guns: 2.00" 6 spf 2006PJ Perf Gun PERFORATION INTERVALS: 11,050' - 11,140' 11,165' - 11,185' TOTAL LENGTH = 110' LOW ER1 POH. Overpulls of 10k# to 25k# within the first 10'. Well is on a vacuum. Full losses to the fault rom the erfs. Full communication. PUH to 10300' just above the liner. Circulate at 2 bpm. No returns. Pump down the backside 2 bpm. Still no returns. 0 WHP. POH to surface, while pumping 2 bpm. Discuss plan forward with town. LOWERI Bullhead 1.5 tubing volumes at 3.6 bpm, 0 psi WHP, 235 bbls. rnniea: anreuua IU:IZ:41 HM • BP EXPLORATION Page 8 of 9 Operations Summary Report Legal Well Name: 18-02 Common Well Name: 18-02 Spud Date: 6/28/1982 Event Name: REENTER+COMPLETE Start: 8/8/2009 End: 8/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ~ Task .Code NPT Phase Description of Operations 8/18/2009 18:45 - 19:00 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH. 19:00 - 20:15 1.25 PERFO P LOWERI Stand back 13 stds of CSH. Pump 1.0 bpm across the top, no returns. 20:15 - 20:45 0.50 PERFO P LOWERi SAFETY MEETING. Review procedure, hazards and mitigation for laying out fired 2" pert guns. Read new procedure for laying out pert guns. 20:45 - 22:30 1.75 PERFO P LOWERI Laid out SWS fired pert guns. All shots fired. 22:30 - 00:00 1.50 EVAL P LOWERI SAFETY MEETING, re: PU Logging BHA PU SLB SCMT and PITS logging tool PU 34 jts 1-1/4" CSH PU 2 jts PH6 8/19/2009 00:00 - 00:45 0.75 EVAL P LOWERi PU remaining Logging Assy. 00:45 - 02:30 1.75 EVAL P LOWERI RIH w/ SCMT/PITS Logging Assy with no pumps. 02:30 - 03:30 1.00 EVAL P LOWERI Log down 30 fpm 10300' to 11170' (uncorr) with no pumps Log up 30 fpm from 11170' to 10300' 03:30 - 04:20 0.83 EVAL P LOWERI Pump 27 bbls ~ 2.4 bpm, 420 to 721 psi to fill the coil. Pump1%KCL Volume, Pressure, Rate 0 bbl, 2000 psi, 2.4 bpm 12 bbl, 2200 psi, 2.4 bpm 25 bbl, 2400 psi, 2.4 bpm 27 bbl, 2700 psi, 2.4 bpm 35 bbl, 2700 psi, 2.4 bpm 50 bbl, 2740 psi, 2.3 bpm 60 bbl, 2760 psi, 2.3 bpm 80 bbl, 2750 psi, 2.3 bpm 90 bbl, 2750 psi, 2.3 bpm 100 bbl, 2750 psi, 2.3 bpm 04:20 - 05:20 1.00 EVAL P LOWERI Wait for downhole temperatures to stabilize after pumping. 05:20 - 05:50 0.50 EVAL P LOWERI Log down 30 fpm 10300' to 11170' (uncorr) with no pump 05:50 - 08:00 2.17 EVAL P LOWERI POH 30 fpm pumping 2.0 bpm, 0 WHP. 08:00 - 09:00 1.00 EVAL P LOW ER1 Bullhead 1.5 tubin volumes down the backside at 4.0 bpm, 0 WHP. Pumped 235 bbls 1 %KCL. 09:00 - 09:15 0.25 EVAL P LOWERi SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH and UO SWS logging tools. 09:15 - 11:00 1.75 EVAL P LOWERI Stand back CSH and Lay out SWS SCMT logging tools. Circ 1.0 bpm across the top with no returns. Download memory data, good data. 11:00 - 14:00 3.00 EVAL N WAIT LOWERi Wait on logs presentation, send logs to town and wait on orders. Grease injector, general rig maintenance. Will move rig to DS-15. 14:00 - 16:30 2.50 RIGD P POST Clean rig pits. Call for N2 pumper to blowdown coil. Order diesel for tubing freeze protect. 16:30 - 17:00 0.50 RIGD P POST Freeze protect 4-1/2" tubing with 40 bbl diesel to 2500'. 17:00 - 17:15 0.25 RIGD P POST SAFETY MEETING. Review procedure, hazards and " mitigation for setting BP Valve with T Bar. 17:15 - 18:00 0.75 RIGD P POST Set BPV with valve crew. Well was on a vac. 18:00 - 20:00 2.00 RIGD P POST SAFETY MEETI , re: blowdown o coil rnineu. ai ucuua iv.ic.~~..~~~ BP EXPLORATION Operations Summary Report Page 9 of 9 ~ Legal Well Name: 18-02 Common Well Name: 18-02 Spud Date: 6/28/1982 Event Name: REENTER+COMPLETE Start: 8/8/2009 End: 8/20/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/20/2009 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To ~ Hours Task Code i NPT Phase I; Description of Operations 8/19/2009 18:00 - 20:00 2.00 RIGD P POST 20:00 - 22:30 2.50 RIGD P POST 22:30 - 00:00 1.50 RIGD P POST 8/20/2009 00:00 - 01:00 1.00 RIGD P POST i 01:00 - 06:00 5.00 RIGD P POST 06:00 - 07:00 1.00 RIGD P POST 07:00 - 07:15 0.25 RIGD P POST 07:15 - 08:00 0.75 RIGD P POST Pump 40 bbl water, 15 bbl corrosion inhibitor, 6 bbl McOH, then blowdown coil w/ N2. SAFETY MEETING, re: Remove pack-offs & Pulling coil across Remove pack-offs from injector Pull coil across and secure to reel. Set injector on the floor SAFETY MEETING, re: Reel swap, RU reel & hardline Lower 2-3/8" eline reel PU 2" aline reel. RU reel and RU inner reel hardline. SAFETY MEETING, re: C/O BOP rams to 2", ND BOP stack, NU Tree Cap & PT C/O BOP rams to 2" ND BOP stack NU Tree Cap & PT w/diesel to 3500 psi. Greased tree with new Clare grease. Released Rig at 06:00 hrs, 08/20/2009. TOTAL TIME FROM ACCEPT TO RELEASE = 7 DAYS 6 HOURS Move to DS 15-42B Prep to jack up rig and move off of well. SAFETY MEETING. Review procedure, hazards and mitigation for moving rig off of well. Jack up rig and move to end of pad for move to DS 15-42B. All further rig information will be under DS 15-42B. Nnnteo: anrzwa IUa Z:41 HM ~~~~ BAKER 1~1~HES INTEQ North America - Prudhoe Bay PBDS18 18-02 -Slot 02 ALASKA - BP 18-02B Design: 18-02B Survey Report -Geographic 19 August, 2009 by BAI~R ^ l~s • Survey Report -Geographic ~ ~" ° 1NTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 18-02 -Slot 02 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 18 MD Reference:. 18-02 @ 46.OOft (Parker 176) Well: 18-02 North Reference: True Wellbore: 18-026 Survey Calculation Method: Minimum Curvature ...Design: 18-02B Database; EDM .16 - Anc Prod - WH24P project Prudhoe Bay, North Slope, UNITED STATES ~Aap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point flap Zone: Alaska Zone 04 Using geodetic scale factor ..Site PB DS 18, TR-11-14 Site Position: Northing: 5,959,213.15ft Latitude: 70° 17' 35.252 N From: Map Easting: 691,583.44ft Longitude: 148° 26' 55.555 W Position Uncertainty: 0.00 ft Slot Radius: O.000in Grid Convergence: 1.46 ° Well 18-02 API No 500292076200 Well Position +N/-S 0.00 ft Northing: 5,960,565.30 ft Latitude: 70° 17' 48.534 N +EI-W 0.00 ft Easting: 691,637.67ft Longitude: 148° 26' 52.970 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 16.10ft Wellbore 18-026 API No 500292076202 .Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2009 8/4/2009 22.68 80.95 57,676 Design 18-02B Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,444.79 Vertical Section; :Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) ` (ft) (°) -16.10 0.00 0.00 198.84 Survey Program Dater 8/19/2009 !, From To (ft) (ft) Survey (Weilbore) Tool Name Description 100.00 8,900.00 18-02 Boss (18-02) BOSS-GYRO Sperry-Sun BOSS gyro multishot ', 8,959.40 9,698.40 18-02P61 MWD (18-02APB1) MWD MWD -Standard 9,710.40 10,444.79 18-02 MWD (18-02A) MWD MWD -Standard ~I 10,490.00 11,251.00 MWD (18-026) MWD MWD -Standard 8/19/2009 4:05:16PM Page 2 COMPASS 2003.16 Bulld 71 . ~BAIQR ^ • lips Survey Report - Geographic ` INTEQ `company: North America -ALASKA - BP Locaf Co-ordinate Reference: Well 18-02 -Slot 02 ..Project: Prudhoe Bay TVD Reference: Mean Sea Level :Site: PB DS 18 MD Referenced 18-02 @ 46.OOft (Parker 176) WeR: 18-02 NorthReferences True Wellbore: 18-02B Survey Calculation Method: Minimum Curvature Design: 18-026 Database: EDM .16 - Anc Prod - WH24P ,Survey Measured TVD Below Map Map ' Depth Inclination Azimuth System +N/-S +~ W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 10,444.79 14.64 341.73 8,552.89 -4,238.66 -785.90 5,956,308.23 690,960.15 70° 1T 6.846 N 148° 2T 15.864 W' TIP 10,490.00 14.64 341.88 8,596.63 -4,227.80 -789.47 5,956,318.99 690,956.31 70° 1T 6.953 N 148° 2T 15.968 W', KOP ~ 10,510.74 17.86 327.29 8,616.55 -4,222.63 -792.00 5,956,324.09 690,953.64 70° 1T 7.004 N 148° 2T 16.042 W ~, 10,543.90 29.05 315.55 8,646.94 -4,212.57 -800.42 5,956,333.94 690,944.97 70° 17' 7.103 N 148° 27' 16.287 W 10,575.94 39.95 309.53 8,673.31 -4,200.43 -813.85 5,956,345.73 690,931.24 70° 1T 7.222 N 148° 2T 16.679 W j 10,607.40 50.93 305.13 8,695.35 -4,186.93 -831.68 5,956,358.77 690,913.07 70° 1T 7.355 N 148° 2T 17.198 W i 10,639.08 62.38 303.48 8,712.74 -4,172.06 -853.52 5,956,373.08 690,890.86 70° 1T 7.501 N 148° 2T 17.834 W I, t 10,673.83 75.62 304.47 8,725.17 -4,153.96 -880.36 5,956,390.49 690,863.57 70° 1T 7.679 N I 148° 2T 18.616 W, 10,707.47 81.62 308.31 8,731.80 -4,134.40 -906.88 5,956,409.37 690,836.56 70° 17' 7.871 N 148° 27' 19.389 W j 10,737.85 82.24 313.94 8,736.07 -4,114.62 -929.53 5,956,428.56 690,813.41 70° 1T 8.066 N 148° 2T 20.049 W' ' 10,770.05 80.99 318.89 8,740.77 -4,091.55 -951.49 5,956,451.05 690,790.88 70° 1T 8.293 N , 148° 2T 20.689 W 10,800.93 80.87 322.98 8,745.64 -4,067.88 -970.70 5,956,474.22 690,771.07 70° 1T 8.525 N 148° 2T 21.249 W ~ ° 10,839.13 81.49 327.91 8,751.50 -4,036.80 -992.10 5,956,504.75 690,748.88 70° 1T 8.831 N 2T 21.872 W ~ 148 10,869.79 81.15 329.07 8,756.13 -4,010.97 -1,007.94 5,956,530.17 690,732.39 70° 17' 9.085 N 148° 27' 22.334 W 10,902.43 81.34 325.41 8,761.10 -3,983.84 -1,025.40 5,956,556.84 690,714.25 70° 1T 9.352 N 148° 2T 22.842 W I. 10,932.87 81.54 321.42 8,765.63 -3,959.68 -1,043.33 5,956,580.54 690,695.70 70° 1T 9.590 N 148° 2T 23.365 W'~ 10,971.23 81.96 317.09 8,771.14 -3,930.92 -1,068.11 5,956,608.65 690,670.21 70° 1T 9.872 N 148° 2T 24.087 W', 10,999.97 82.11 314.02 8,775.12 -3,910.61 -1,088.03 5,956,628.45 690,649.77 70° 1T 10.072 N 148° 2T 24.667 W I, ~, 11,036.71 80.62 310.93 8,780.64 -3,886.08 -1,114.82 5,956,652.28 690,622.37 70° 1T 10.313 N 148° 2T 25.448 W I I 11,071.03 80.98 307.76 8,786.13 -3,864.60 -1,141.02 5,956,673.08 690,595.63 70° 1T 10.525 N 148° 2T 26.211 W', 11,110.29 82.47 304.69 8,791.78 -3,841.65 -1,172.35 5,956,695.23 690,563.72 70° 1T 10.750 N 148° 2T 27.124 W'.. ' 11,143.89 82.38 304.21 8,796.21 -3,822.81 -1,199.82 5,956,713.36 690,535.79 70° 1T 10.935 N 148° 2T 27.925 W, 11,173.89 83.23 308.40 8,799.97 -3,805.19 -1,223.80 5,956,730.36 690,511.37 70° 1T 11.109 N 148° 2T 28.623 W'~, 11,205.35 84.35 313.18 8,803.37 -3,784.76 -1,247.47 5,956,750.18 690,487.19 70° 17' 11.310 N 148° 27' 29.313 W I 11,251.00 84.35 313.18 8,807.86 -3,753.68 -1,280.60 5,956,780.41 690,453.28 70° 1T 11.615 N 148° 2T 30.278 W, TD - 2.875" 8/19/2009 4:05:16PM Page 3 COMPASS 2003.16 Build 71 TREE = 5-1 !8" Mc E1tflY WFLLHEAO= ... .... ...rv. NC',l-UATQR = _ __. MGEVflY .._ __ AXELSON KB. ELEV = 4b.&' 6F. ELEV - - K(JF = 3100' Max Anyle = Datum MD -~ _ Datum 7V D = ~:? 1 ~ r ~~8800' SS ~L~ b ~ a,.r 41 y ..4.. 13 318 CSG 72#, L-80, ID=12.347" I 2f:1$~ $~ _, ~ ^} i it1[t?~/it 3pp i€j~LS,~~y(`. ,.~ ~J~tiil~-J,..'~~'j ,~' ~~)'~...~ \..t i4~ R,d i CJ' i._ r" ~.. : 8 ~'~.i ~ C ~ SI C.. 7" BiCR TIEBACK SLV, ID = 6.375" $78~f' I-518 X 7"" BKR L~tR HGR, IB = 5.188" $794 9_6rg" CSG, 47#, L-80, 111= 8.687" 8960' 18-02B SAFE-1~3TE~,'-`"`°.', ~ :., ,~ . ; ~,; , '.` :PRE-SDTRKWELLBC3f~ N4TSHC115IN p1~ 5l)(ACa~2AM BEL.QW 9-5t8""SEC [ 14lV MILLEfJ YY I111LArQYY ~ S~sO"» ~ 22a1• 1 4-'t i2~ CAtvk; ~7 in = 3.812„ [~A S LIFT MAN ©RELS ST Mb TVC1 flEV TYPE VLV LATCH PERT GATE 1 2973 2972 7 MN1G DMY RK 0 G6i05.~07 2 6148 5387 5Q h7h~ DIvR' RK 0 06;05107 3 8637 9990 48 MMG C~M1' RK 0 04,`11; 05 4 8748 7064 ' 48 MMG t~I+rTY RK 0 O6; 27 `OJ 9-518° X T' BKR LT PKR, iD = 6,186„ ~ - 3 112", 9.2# L 80, STL LNR, 9D = 2.995" ~--~ 1~~~4° 4-112" TBG, 12.6#, L-80, .0952 bpf, ID = 3.358" 10397' -0-112" TTP, 12.6#, L-80, .Q152 bpf, tU = 3.958" 1fl444' 4-1l"x7"v~rhipstock 1Ct4p` PER€CIRATI~N SUMMARY REF LCJG: ~t'>/ L~IL -'1 i A NGLE ~, T TaP PF~F s1 t u.5=a' Nate: Refer to Production. DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATc ~., 1 iLj[1' 11141' r~`> t i'.S~{fir:' ~' 6 ;116:x' - 111L;~' Opt j~a1';,r.: 7" LNR, 29#. L-80, .0371 bpf, ID =6.184" I-°~ 10846` ~~ 1 ~ I ~`~r i i'' . ~~ (78-02A} 1039$' ~7" X ~#-112" BKR SA BL-3 PKR ID = 3.x;75' 10432' 4-1{Z" HES XPJ NII', tQ 10444` --~ 49t2" WLEG, ID=-0.00" l ~10441}' ELMD TT LC, ..,~ t4Ji8195 l ,F ~' 6.i6f€, Lt8{l wf ;1' ' Pi3TD 11t}3' ', '-~.,v'` __ ~ `~ , , '` "`> __ PBTD DATE RE'/ BY CQit/It+IEhITS DATE REII BY COMMENTS Q7t2411f2 Oi~GINAL G+nMPLE?lQN Q4(49f35 RiG Sil]ETRAGK 09118103 ASNULP RENAME 18-028 TO 18-C32A 081191t18 N©RDtG GTfJ SIDETRACK (18-028) 08122f09 PJC QRLG HO Cf)RRECTIONS PRUDHOE C^:Y UNIT WELL. 1 e-'~ ' PERM(T ~: " API Nta: 50-029-20762-(7= SEC 24, T11 N; R14E, 393u' NSL $i 131' V1fEt- L3P Exploration lAtastca~ ((~~ ` 1 J ~~ ~ ~~ 111 C~~ ALASSA OIL A1~TD GA5 COI~TSERQAZ`IO1~T COMN'II551O1~T John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANGHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-02B BP Exploration Alaska Inc. Permit No: 209-046 Surface Location: 3980' FSL, 131' FEL, SEC. 24, T11N, R14E, UM Bottomhole Location: 528' FSL, 1640' FEL, SEC. 24, T11N, R14E, UM Dear McMullen: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commissian specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, ~,,,r Daniel T. eamount, Jr. t, ~ Chair DATED this Z~ day of April, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~s~~' STATE OF ALASKA ~ ~ ~~ ~ ~ ~ ~ 209 ~~O-D9 ALAS AND GAS CONSERVATION COMMIS PERMIT TO DRILL I,~ as 20 AAC 25.005 ,~lasita Jit ~ i~u~s~n ~r3ftlffliSSioft 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well i d for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inca 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 18-02B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11636' TVD 8940' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028307 & 028308 Oil Pool FEL, SEC. 24, T11 N, R14E, UM FSL, 131 3980 Top of Productive Horizon: UM T11N R14E 936' FEL SEC. 25 202' FNL 8. Land Use Permit: 13. Approximate Spud Date: June 14, 2009 , , , , , Total Depth: 528' FSL, 1640' FEL, SEC. 24, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 37,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-691638 y-5960565 Zone-ASP4 10. KB Elevation (Height above GL): 46.6' feet 15. Distance to Nearest Well Within Pool: 1157' 16. Deviated Wells: Kickoff Depth: 10490' feet Maximum Hole An le: 81 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3307 Surface: 2427 1 Ca in Pro r m: ifi 'o T - e 'n _ B m u f .f. Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/8" s-~n"x3-3/16" 8.81#/6.2# L-80 TL 1286' 1 350' 8 7' 11 3 ' 8940' 2sxCla s' ' 1 g, PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and'Re-entry Operations) Total Depth MD (ft): 10847' Total Depth TVD (ft): 8988' Plugs (measured): None Effective Depth MD (ft): 10800' Effective Depth TVD (ft): 8943' Junk (measured): None Casin Length Size Cement Volume MD TVD Conductor /Structural 2 22 Surface 2 14' 1 -3/ " 2 sx Fond 400 sx P rmafrost "C' 2614' 2614' Intermediate 9 -5/ " 0 x la s' 0 Bbls PF'C' 8 60' 72 8' r n Liner 2 7" 45 x I ss ' 8781' - 1 846' 7 87' - 8 87' Perforation Depth MD (ft): 10698' - 10739' Perforation Depth TVD (ft): 8844' - 8884' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the fo oin is correct. Printed Name John ul Si nature ~'~ Contact Mel Rixse, 564-5620 Title Engineering Team Leader Prepared ey Name/Number Phone 564-4711 Date /Fs O Terrie Hubble, 564-4628 Commission Use Onl Permit T rill N tuber: o?!~ ~6 API Number: 50-029-20762-02-00 Permit Approval See cover letter for t h r re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ~0 f S i ~-a~~g~ Samples Req'd: ^ Yes ~No Mud Log Req'd: ~^,/Yes ~No ~~©PS~ ~`~~~ ~"`'~'~~G~'~v~'~ ~~,~ HZS Measures: Yes ^ No Directional Survey Req'd: pe7 Yes ^ No Other: ~ ~ ~~~ ~ APPROVED BY THE COMMISSION ~~~ Date -°~` GOMMISSIONER Form 10-401 Revised 12f2605 ~11~ f GiNAI DS18 - 02B - Coiled Tubing ing To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Mel Rixse CTD Engineer Date: April 2, 2009 Re: 18-028 Application for Permit to Drill Request CTD Drill and Comgletelproctram: Spud in_June 14, 2009 Pre-Rig Operations 1. O MIT-OA - 2000 psi Failed 12/19/2008 2. O MIT-IA - 3000 psi Passed 12/19/2008 3. E Drift for 4-1/2" X 7" Thru tubing whipstock to 10,500' MD 4. E Set whipstock ~ 10,490'MD (see procedure below.) 5. C Mill XN nipple at 10,432' MD to 3.80". 6. C Test for infectivity through perforations 7. C Squeeze cement past whipstock to abandon existing perforations 8. O MIT-Tubing 3000 psi 9. O AC-LDS; AC-PPPOT-IC, T 10. O PT tree (MV,SV,WV), function LDS 11. O Bleed gas lift and production flowlines down to zero and blind flange 12. O Remove S-Riser, Remove wellhouse, level pad -Complete Rig Sidetrack Operations: (Scheduled to begin on June 15, 2009) 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high 2. Pull BPV. DONE DONE "" by ~Z~~ - \~ 5"~-- 4. Drill build/turn section with 4.25" bicenter bit, and land well. 5. Drill lateral section to 11,636' MD w/ resistivity log. 6. Run 3-1 /2"x 3-3/16"x 2-7/8" solid liner w/cementralizers to TD. Place liner top at 10,350' MD. 7. Cement liner from TD to TOL (10,350'MD) with 15.8ppb cement. 8. Clean out liner/Run MCNL/GR/CCL log. 9. Test liner lap to 2000 psi. 10. Perforate per geologist. 11. Set liner top packer (if tails liner lap test) 12. Freeze protect well to 2500' with diesel. 13. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 14. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design 4. RU test separator, flow test well. ~)G..~M ~~ 5 ~ April 2, 2009 • DS18 - 026 - Coiled Tubing ~ing Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new FIo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/8" Casing Program: • 3-1/2", 8.81 #, L-80, STL connection solid liner - 10,350'MD - 10,380' MD w/ liner top packer. • 3-3/16", 6.2#, L-80, STL TC-II connection solid liner - 10,380'MD - 10,870' MD. • 2-7/8", 4.7# , L-80, STL connection Solid liner - 10,870'MD - 11,636' MD. • A minimum of 10.8 bbls 15.8 ppg cement will be used for liner cementing. (TOC 10,350'MD) Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 82 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line - 37,000' N Anticollision Summary • 18-036 1157' ctr-ctr, Status: Producing • 18-03A - 1208' ctr-ctr, Status: Abandoned • 18-19 - 1242' ctr-ctr, Status: Shut-in • 18-03 - 1242' ctr-ctr. Status: Abandoned Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCUCNL log will be run. Hazards • The maximum recorded H2S level on DS 18 is 20 ppm on 18-186(06-28-2008). Drill Site 18 is not an H2S pad. • Lost circulation risk is low. No fault crossings are expected. Reservoir Pressure Res. press. is estimated to be 3,307 psi at 8,800'ss (7.3 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2427 psi. `_'`' Mel Rixse CTD Engineer April 2, 2009 DS18 - 02B - Coiled Tubing Drilling ~• wka/ov LHEAD= ACEVOY CIUATOR = A7(ELSON KB. ELEV = 48.8' F. ELB/ = 3100' An9k = S? ®~i00' umA~= 10707 mTVD= 8800'SS 13-3f8• t~6, 7zE L-W, D=1z.3ar 2614' Minimum ~ = 3.725" ~ 10432' I 4-1/2" HES XN N~PLE 7' BKR T8~11CIC SLV, D = 9.375• 8781' X518' X T BKR LNR HcR D= 9.196• 8794' x518' CS{i, 478; L-80. D = B.q1' 8980' 41f? TBO, 12.lE, L-BD, .0152 bpi, D = 9.0.~i6' 10397 7•X41/2'BKRSA843PKRD=3.W5' ~ 4-1r!' FB XN NP. D = 3.7,2 - - - - -- -~ • - - ' ' ~ 10444' F1 4.1? YIILF3q D = 4.00' ~ 10440' ELwO) TT LOGGED 01/18A5 1061 T r MARKER .108rT (20' ) PERFORATION SUAAI9IRY REF LOC6 BHCA ON 04A8A5 ANOLEATTOP PERF: 14 ®10875' Note: Rata /o Production DB tar hbtorical data S¢E SPF N1H4VAL O)ItdSgt OATS 3.3A' 4 10875 -1071 S S OQH 2104 3-3A' 8 10098 -10718 O 08N 3104 3-318' 9 10708 -10718 O 07/03/0~t 3.318' 8 10721-10739 O 0TI0310~t 3-318• 4 10722-10740 S 08/121W 3.318• 4 10743 -10783 S 06/12104 3-318' 4 10744 - 10784 S 06112/04 I T WR 299. L-W..0371 bot. 8) = 9.184' I QATE Ref/ BY CONIMBUT8 QATE RH/ 8Y 00891~ITS O7i»f/9I 0180NAL COMPLlf10N 07103104 MDCIK/1 AOIR69iF RIO BMLRRACK 08/13104 P AOD PERF tOM0/01 CFYKAK 04ASA35 K38ftLH GLV GD OORR~T. (08J'-7104) 09118103 ASNYLP RBWIMEIB-02BTO18~02A 081107 CJNIRRO OLVCJO 0'5117104 KSIKAK GLV CID OQH2104 JAF/KAK SOZ FERFS PRUa~IOS eAr ulrr YIIELL: 1&02A P8ii8T Ne: ~1950l00 API No: 50.021.20712 02 8BC a4, 711 N, R14Q 3980' N8l i 131' ~ ~lontbn (Alaaka~ 1 ~_O~~ 8AFETYNOTES: PRErSDTRKWELL910RENOT 8i40WN ON DIAGRAM BELOW 9.618" 8®CTION MIUED WN4D01N a ~so•. 2201' J--' 4-12• CAM;A TF~ii4A lR'SV , D = 3.812• [`-AR 1 RT WI~RA.S sT wro 7vo oev TrPE vLV uTa1 PORT DATE 1 2973 2972 7 we4c3 own RK o oe1o5107 8148 5388 50 MNN<ii OAAY RK 0 08106/07 3 8837 9N6 40 IAYIG 04AY RK 0 04/11/96 4 8748 7059 48 A81K'a DMY RK 0 08110196 8788' X518• X 7' BKR LT PKR D = 9-5f8' SIDETRACK WINDOfN 8960' -9010' (SECTIQN MLL) April 2, 2009 ~6• MoEVOY LLHFADa NCEVOY CTWTOR= AXELSON KB. ELEV = 46.8' 1 $ ~O 2 B SAFETY NOTES: PRE- SDTRK WELLBORE NOT 8HOWN ON DU-GRAM BELOW 95/9" SECTION Proposed CTD Sidetrack MILLED wlNDOw ~ a9eo•. DATE REV BY COMMBJTS GATE REV BY C~MYIBV'rS 07Q4112 ORIC4f~Y1L COMPLETION 07103!04 NDCIKAK AD1REf~RF 04AW9S R1CiSIDETRACK 06/13104 LDK/TLP ADOPERF 10MOI01 CWKAK CORRECTIONS 04/05/05 KSBITLH GLV Cl0 CORRECT. (Od197104) 09!16/03 AS/VMLP RB~WIrE 18-028 T018.OZA OE105/07 CJNIPAG GLV CIO 05/17/04 KSIKAK GLV d0 02/24109 MISS RiDPSEDCTDSDETRACK D8/12/04 JAF/KAK SOZ R7iFS RiUGHOE BAY UNR WELL: 1 &028 PERMR No: A R No: 50-02x20762-03 BP Biploratan (Alaska DS18 - 02B - Coiled Tubing fling are i to 18-02B BAG 7 1/16" 5000 psi. Blind/Shears cross 2 318" combi ram/slips Mud Cross variable bore pipe 3 1/2"-2 318" 2 318" combi ram/slips ab Valy Flow Tee TOTs 7 1 / 16" 5000p si Mud Cross 7 1116" 5000psi TOTs 7 1/16" 5000psi April 2, 2009 i ~- ^~.~r BAR ~~ INTEQ North America -ALASKA - BP Prudhoe Bay PB DS 18 18-02 -Slot 02 Plan 10, 18-02B Plan: Plan #10 Survey Report -Geographic 14 April, 2009 by N.~~ ~ Survey Report -Geographic by ]INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: We1118-02 -Slot 02 Project: Prudhoe Bay TVD Reference: 18-02A @ 46.60ft (Nabors 2ES) Site: PB DS 18 MD Reference: 18-02A @ 46.60ft (Nabors 2ES) Well: 18-02 North Reference: True Wellbore: Plan 10, 18-026 Survey Calculation Method: Minimum Curvature Design: Plan#10 Database: EDM .16 - Anc Prod - WH24P Project Prudhoe Bay, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 18, TR-11-14 - -- - _ Site Position: Northing: 5,959,213.15ft Latitude: 70° 1T 35.252 N From: Map Easting: 691,583.44ft Longitude: 148° 26' 55.555 W li Position Uncertainty: 0.00 ft Slot Radius: O.000in Grid Convergence: 1.46 ° --- -- Well _ _ 18-02 -Slot 02, 18-02 - -- - - _ Well Position +N/-S -0.00 ft Northing: 5,960,565.30 ft Latitude: 70° 1T 48.534 N', +E/-W 0.00 ft Easting: 691,637.67 ft Longitude: 148° 26' 52.970 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 16.10ft Wellbore Plan 10, 18-026 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2008 4/3/2009 22.88 80.94 57,713 Design - - P{an #10 - - -_ - Audit Notes: this plan done by Mel R. ~ Version: Phase: PLAN Tie On Depth: 10,444.70 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) '~~ 30.50 0.00 0.00 315.00 Survey Tool Program _ _ Date 4/14/2009 From To (ft) (ft) Survey (Wellbore) Tool Name 100.60 8,900.60 18-02 Boss (18-02) BOSS-GYRO ~~ 8,960.00 9,699.00 18-02P61 MWD (18-02AP61) MWD 9,711.00 10,444.70 18-02 MWD (18-02A) MWD 10,444.70 11,636.20 Plan #10 (Plan 10, 18-02B) _ - - __ MWD Description Sperry-Sun BOSS gyro multishot MWD -Standard MWD -Standard MWD -Standard 4/14/2009 11:10:42AM Page 2 COMPASS 2003.16 Build 70 S Survey Report -Geographic ~ ~ 1NTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 18-02 -Slot 02 Project: Prudhoe Bay TVD Reference: 18-02A @ 46.60ft (Nabors 2ES) Site: PB DS 18 MD Reference: 18-02A @ 46.60ft (Nabors 2ES) Weli: 18-02 North Reference: True Wellbore: Plan 10, 18-02B Survey Calculation Method: Minimum Curvature Design: Plan. #10 Database: EDM .16 - Anc Prod - WH24P Planned Survey Measured Vertical Depth Inclination Azimuth Depth +N!-S +E/-W (ft) (°) (°) (ft) (ft) (ft) 10,444.70 14.64 341.73 8,598.82 -4,238.82 -785.85 Start DLS 0.08 TFO 90.34. 10,490.00 14.64 341.88 8,642.65 -4,227.95 -789.42 Start DLS 9.00 TFO 330.00 10,500.00 15.43 340.19 8,652.31 -4,225.49 -790.27 10,510.00 16.22 338.66 8,661.93 -4,222.94 -791.22 Start DLS 42.00 TFO 330.00 10,600.00 52.38 315.90 8,735.29 -4,184.22 -821.72 10,669.00 81.01 310.93 8,762.31 -4,141.35 -867.46 Start DLS 12.00 TFO 91.00 10,700.00 80.97 314.70 8,767.17 -4,120.55 -889.92 10,800.00 81.08 326.85 8,782.83 -4,044.18 -952.26 10,819.00 81.15 329.16 8,785.76 -4,028.26 -962.20 .Start DLS 12.00 TFO 268.00 10,900.00 80.94 319.32 8,798.40 -3,963.42 -1,008.90 11,000.00 81.04 307.17 8,814.12 -3,895.89 -1,080.71 11,019.00 81.11 304.86 8,817.07 -3,884.85 -1,095.89 Start DLS 12.00 TFO 91.00 11,100.00 81.07 314.70 8,829.65 -3,833.72 -1,157.31 11,200.00 81.37 326.84 8,844.98 -3,757.31 -1,219.69 11,219.00 81.47 329..14 8,847.81 -3,741.38 -1,229.65 Start DLS 12.00 TFO 268.00 11,300.00 81.26 319.31 8,860.00 -3,676.49 -1,276.40 11,400.00 81.34 307.17 8,875.18 -3,608.91 -1,348.27 11,419.00 81.40 304.87 8,878.03 -3,597.86 -1,363.46 Start DLS 12.00 TFO 130.00 11,500.00 75.25 312.55 8,894.43 -3,548.36 -1,425.32 11,600.00 68.03 322.67 8,925.98 -3,478.54 -1,489.29 11,636.20 65.57 326.56 8,940.25 -3,451.43 -1,508.56 TD at 1 1636.20 Map Map Northing Easting (ft) (ft) Latitude Longitude 5,956,308.07 690,960.21 70° 17' 6.845 N 148° 27' 15.863 W 5,956,318.85 690,956.36 70° 17' 6.952 N 148° 27' 15.967 W 5,956,321.28 690,955.45 70° 17' 6.976 N 148° 27' 15.991 W 5,956,323.80 690,954.43 70° 17' 7.001 N 148° 27' 16.019 W 5,956,361.73 690,922.96 70° 17' 7.382 N 148° 27' 16.908 W 5,956,403.42 690,876.14 70° 17' 7.803 N 148° 27' 18.241 W 5,956,423.64 690,853.16 70° 17' 8.008 N 148° 27' 18.895 W 5,956,498.39 690,788.90 70° 17' 8.759 N 148° 27' 20.711 W 5,956,514.05 690,778.55 70° 17' 8.915 N 148° 27' 21.001 W 5,956,577.68 690,730.22 70° 17' 9.553 N 148° 27' 22.362 W 5,956,643.35 690,656.71 70° 17' 10.217 N 148° 27' 24.454 W 5,956,653.99 690,641.26 70° 17' 10.325 N 148° 27' 24.897 W 5,956,703.54 690,578.56 70° 17' 10.828 N 148° 27' 26.686 W 5,956,778.33 690,514.26 70° 17' 11.580 N 148° 27' 28.504 W 5,956,794.00 690,503.90 70° 17' 11.736 N 148° 27' 28.794 W 5,956,857.67 690,455.51 70° 17' 12.374 N 148° 27' 30.156 W 5,956,923.40 690,381.94 70° 17' 13.039 N 148° 27' 32.251 W 5,956,934.05 690,366.47 70° 17' 13.148 N 148° 27' 32.693 W 5,956,981.96 690,303.38 70° 17' 13.634 N 148° 27' 34.496 W 5,957,050.12 690,237.65 70° 17' 14.321 N 148° 27' 36.360 W 5,957,076.73 690,217.70 70° 17' 14.587 N 148° 27' 36.921 W 4/14/2009 11:10:42AM Page 3 COMPASS 2003.16 Build 70 sw~aR ~ ~ui~s Survey Report -Geographic 1NTEQ Company: North America -ALASKA - BP Local Coordinate Reference: Well 18-02 -Slot 02 Project: Prudhoe Bay TVD Reference: 18-02A @ 46.60ft (Nabors 2ES) Site: PB DS 18 MD Reference: 18-02A @ 46.60ft (Nabors 2ES) Well: 18-02 North Reference: True Wellbore: Plan 10, 18-026 Survey Calculation Method: Minimum Curvature Design: Plan #10 Database: EDM .16 - Anc Prod - WH24P Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) lft) (ft) (ft) lft) 18-02B Polygon 0.00 0.00 46.60 -3,459.77 -1,641.52 5,957,065.00 690,085.00 - plan misses target center by 8630.16ft at 10444.70ft MD (8598.82 TVD, -4238.82 N, -785.85 E ) - Polygon Point 1 46.60 -3,459.77 -1,641.52 5,957,065.00 690,085.00 Point2 46.60 -3,334.38 -1,537.28 5,957,193.00 690,186.00 Point3 46.60 -3,708.21 -1,196.68 5,956,828.00 690,536.00 Point 4 46.60 -4,102.98 -701.56 5,956,446.00 691,041.00 Point 5 46.60 -4,309.42 -765.85 5,956,238.00 690,982.00 Point 6 46.60 -3,860.79 -1,293.61 5,956,673.00 690,443.00 18-026 Fault2 0.00 0.00 46.60 -3,675.03 -1,555.98 5,956,852.00 690,176.00 - plan misses target center by 8605.31ft at 10444.70ft MD (8598. 82 TVD, -42 38.82 N, -785.85 E ) - Polygon Point 1 46.60 -3,675.03 -1,555.98 5,956,852.00 690,176.00 Point 2 46.60 -3,569.90 -1,167.15 5,956,967.00 690,562.00 18-02B Target 2 0.00 0.00 8,941.60 -3,445.14 -1,509.10 5,957,083.00 690,217.00 - plan misses target center by 6.45ft at 11636.20ft M D (8940.25 TVD, -3451.43 N, -1508.56 E) - Point 18-026 Target 1 0.00 0.00 8,868.60 -3,824.22 -1,158.63 5,956,713.00 690,577.00 - plan misses target center by 37.72ft at 11114.10ft MD (8831.84 TVD, -3823 .78 N, -1167.06 E) - Point 18-026 Fault 1 0.00 0.00 46.60 -4,230.08 -934.89 5,956,313.00 690,811.00 - plan misses target center by 8553.52ft at 10444.70ft MD (8598. 82 TVD, -42 38.82 N, -785.85 E ) - Polygon Point 1 46.60 -4,230.08 -934.89 5,956,313.00 690,811.00 Point 2 46.60 -4,157.51 -759.97 5,956,390.00 690,984.00 Point 3 46.60 -4,120.68 -399.90 5,956,436.00 691,343.00 Point 4 46.60 -4,157.51 -759.97 5,956,390.00 690,984.00 rPlan Annotations Measured Depth (ft) 10,444.70 10,490.00 10,510.00 10,669.00 10,819.00 11,019.00 11,219.00 11,419.00 11,636.20 Vertical Depth (ft) 8,598.82 8,642.65 8,661.93 8,762.31 8,785.76 8,817.07 8,847.81 8,878.03 8,940.25 Local Coordinates +N/S +E/-W (ft) (ft) -4,238.82 -785.85 -4,227.95 -789.42 -4,222.94 -791.22 -4,141.35 -867.46 -4,028.26 -962.20 -3,884.85 -1,095.89 -3,741.38 -1,229.65 -3,597.86 -1,363.46 -3,451.43 -1,508.56 Comment Start DLS 0.08 TFO 90.34 Start DLS 9.00 TFO 330.00 Start DLS 42.00 TFO 330.00 Start DLS 12.00 TFO 91.00 Start DLS 12.00 TFO 268.00 Start DLS 12.00 TFO 91.00 Start DLS 12.00 TFO 268.00 Start DLS 12.00 TFO 130.00 TD at 11636.20 by Latitude Longitude 70° 17' 14.505 N 148° 27' 40.795 W 70° 17' 12.388 N 148° 27' 38.302 W 70° 17' 14.649 N 148° 27' 36.937 W 70° 17' 10.922 N 148° 27' 26.724 W 70° 17' 6.930 N 148° 27' 20.205 W Checked By: Approved By: Date: 4/14/2009 11:10:42AM Page 4 COMPASS 2003.16 Build 70 by Project: Prudhoe Ba Aana,ma to mre Nonh M. naUC rmnh zz ea WELLBORE DETAILS: Plan 10, 18-028 REFERENCE INFORMATION y Site: PB DS 18 g . . Magnetic Fek Patent Welbofe: 18-02A Coartlinate (NIE) Reference: We918-02 -Slat 02, Tr Well: 18-02 Swngih. 5n12.2en Tie on MD: 10444 70 Venial (TVD) Reference: 18-02A @ 46 fi0ft (Nah Welllwre: Plan 10, 18-026 ov nnele. eo.ea . Section (vS) Reference: Slot - 02(o.ooN, O.oOE) Plan: Plan #10 (18-021PIan 10, 18-028) Momt'BGGM200 Meawretl Depth Reference: 18-02A@ 4660ft (Na Calculation Method: Minimum Curvature WELL DETAILS: 18-02 Ground Level 16.10 *N/-S 'EI-W Nornr~ny East-~c~ Lali lli.de I. cn,it.i:ic Slut 0.00 000 596056S.S0 u51ti:f /.67 1 I".E .`,3=: h !~~A' 26' 529/0 W 0'/ SECTION DETAILS ANNOTATIONS Sec MD Inc Azi ssND +NI-S +E/-W DLeg TFace VSec Target Annotation 1 10444.70 14.64 341.73 8598.82 -0238.82 -785.85 0.00 0.00 -2441.62 Start DLS 0.08 TFO 90. 2 10490.00 14.64 341.88 8642.65 -4227.95 -789.42 0.08 90.34 •2431.40 Start DLS 9.00 TFO 330. 3 10510.00 16.22 338.66 8661.93 -4222.94 -791.22 9.00 330.00 -2426.59 Start DLS 42.00 TFO 3301, 4 10669.00 81.01 310.93 8762.31 -4141.35 -867.46 42.00 330.00 -2314.99 Start DLS 12.00 TFO 91.f 5 10819.00 81.15 329.16 8785.76 -4028.26 -962.20 12.00 91.00 -2168.03 Start DLS 12.00 TFO 268 6 11019.00 81.11 304.86 8817.07 -3884.85 -1095.89 12.00 268.00 -1972.09 Start DLS 12.00 TFO 91.( 7 11219.00 81.47 329.14 8847.81 -3741.38 -1229.65 12.00 91.00 -1776.07 Start DLS 12.00 TFO 268 8 11419.00 81.40 304.87 8878.03 -3597.86 -1363.46 12.00 268.00 -1579.96 Start DLS 12.00 TF0 130. 9 11636.20 65.57 326.56 8940.25 -3451.43 -1508.56 12.00 130.00 -1373.81 TD at 11636.20 c w 0 c. Q U .~ [-" 18-02A @ 46 ri.~ e Nonh ~Au~(.LRu- rs 2ES) /!Y~-~1i! rs 2ES) Iii i 1NTEQ • Vertical Section at 315.00° (60 ft/in) West(-)/East(+) (90 ft/in) by w 0 7O' C L N 7 O 16-02A @ 46.601t (Nc Project: Prudhoe Ba Azimuths to True North neuc NoM: 2T BB Me WELLBORE DETAILS: Plan 10, 18-028 REFERENCE INFORMATION y Site: PB DS 18 g Magnetic FeW parent Wellbore: 18-02A Couminate (NIE) Reference: WeN 18-02 - slot o2, True NoM Well: 18.82 StmngN' SzzlPlan A l ao g4 D' Tie on MD: 10444.70 Vertical (TVD) Reference: 18-02A @ 46.60ft (Nabors 2E5) slot-02(O OON OOE) O f Wellbore: Plan 10, 18-026 Plen: Plan N10 (18-027PIen 78, 18-02B) ng e: , p GbE le,~c3ArP , . Section (VS) Re erence: Measured Depth Reference: 18-02A @ 46.60ft (Nabors 2E5) Calculalun Method: Minimum CurvaWre rr;.r BAKER Nu~~s LN1L'lt 306 - -- i ~ 312 - - / 318 /~ 324 - 330 - 8 3360 ~ ~0 342 9~~ ~ ~ 3as -~ ~~ 9/ 18-I q 4 3540 I I -02/ Ian 1 X18 028 - 3600 -- 3660 - 372 378 384 --- i 3900 - ---{- ~O 396 -- 402 i 408 -- 8 4140 ~ 42U 0 4260 '-- _1 - 432 --- 438U -- 4440 _-__. r _ _ 45U 4560 - i 462 bors --- --- ES) ~'' ~ -~ - ~, - 4680 T ____ ___ .. 18-I -2040 -1980 -1920 -1860 -1800 -1740 -1680 -1620 -1560 -1500 -1440 -1380 -1320 -1260 -1200 -1140 -1080 -1020 -960 -900 -840 -?8t3ULA2U3-U.660 -600 -540 -480 -020 -360 -300 -240 -180 -120 -60 0 60 120 180 West(-)/East(+) (60 frlin) u !`I Project: Prudhoe Ba ANTI-COLLISION SETTINGS coMPaNr DeruLS. Nmn a,a.r~ -uasxa- eP y Site: PB DS 18 NORTR aM RICA ti ~ Wall 18'82 Interpolation Method: MD, interval: 25.00 ^ ' '`sw' p ' Depth Range From: 10444.70 To 11636.20 cMmmon MCMm: M mwn c~wMar+ Results Limited By: Centre Distance: 1360.57 E..« sm1.n Iscwsa Wellbore: Plan 10, 18-028 Reference: Plan: Plan #10 (18-02IPIan 10, 1&028) Sun McNm: Tnr mer N+M Erta sw+a°e: rwooa~cona Plan: Plan 010 (18-02/Plan 10,18-026) w.mre Melllm wp.p Braa u WELL DETAILS: 18-02 Ground Level: 16.10 +NI•S *E/-W Northing Easting Lalittude Longitutle Slot 0.00 0.00 5960565.30 691637.67 70° 17' 48.534 N 148° 26' 52.970 W 02 SECTION DETAILS MD Inc Azi ND +N!-S +El-W DLeg TFace VSec Target 0444.70 14.64 341.73 8598.82 -4238.82 -785.85 0.00 0.00 -2441.62 0490.00 14.64 341.88 8642.65 -0227.95 -789.42 0.08 90.34 -2431.40 0510.00 16.22 338.66 8661.93 4222.94 -791.22 9.00 330.00 -2426.59 0669.00 81.01 310.93 8762.31 4141.35 -867.46 42.00 330.00 -2314.99 0819.00 81.15 329.16 8785.76 4028.26 -962.20 12.00 91.00 -2168.03 1019.00 81.11 304.86 8817.07 -3884.85 -1095.89 12.00 268.00 -1972.09 1219.00 81.47 329.14 8847.81 -3741.38 -1229.65 12.00 91.00 -1776.07 1419.00 81.40 304.87 8878.03 -3597.86 -1363.46 12.00 268.00 -1579.96 1636.20 65.57 326.56 8940.25 -3451.43 -1508.56 12.00 130.00 -1373.81 SURVEY PROGRAM Date: 2009-04-14700:00:00 Validated: Ves Version: Depth From Depth To Surrey/Plan 100.60 8900.60 18-02 Boss (18-02J 8960.00 9699.00 18-02P81 MWD (11 9711.00 10444.70 18-02 MWD (18-02 LEGEND +02-30 02aB, 02-38 V1 +BI-39L1 o2asL1. o2-30L1 v1 02-39. 02-39. 02a9 V2 ~ t8-Ot, 1B-0t 18-01 V1 . 18-01, 18-01A, 18-01q V1 s 18-02, 10-02. t0-02 V0 + 18-02. 18-02A, 18-02A V2 18-03.18-02aG81, 18-02APB1 v1 • 18.03. 18-03, 1803 V3 18-03, 18-03A. 18-03A V1 ~~ 18AB. t8-038 18~03B V2 a 18-00. 18-09, 18-01 V2 + 18-09. 10-04A, 18J10A V1 + 18-00. 18-008. 18-000 VO 18-00. 18-OOB Plen # fiU Vt 18-00.10-0OBPB1. te-OOBPBI v9 . 18-05. 18-05. 18-05 V5 + 1BA5. 18-0SA. 10-0SA V8 ~- 18-0.5. 18-05a. 18-0SA xyO] V6 18-11. 18-n. 18-11 VI 18-11, 18-11DPN, 10-11DPN V3 + 18-1), 18-1 ], 161] V1 10-19, 18-19. 1819 V1 •~ 18-2], 18-2], 182] Vt 10-2). 10-2)A. 18-2)A Vt 10-27, 10 18-T1, 10-2]C, Pan p102 V2 + 18-2I. 18~2]D, 18-2]D V2 + 18-2], 18-2]DPBt, 10-2)DPBt V2 10-28. 10-28. 1620 V1 + 1638PB1, 18-20PB1, 18-28PB1 V1 18-29, 18-29. 1629 V1 - 10-29, 10-29A. 18-29A V0 +~ 18-29, 16298, 10-Z9B VO + 18-29, 18-29BPB1. 18-29BPB1 VO • 18-29, Plan 1629C, Plan p218-29C V0 18.31, 18-31, 10-31 V4 18-31 18atq 18atA V3 + 18-31. 10a1PBt. 1631PB1 V3 • 18-32, 18-32, 18-32 V1 • 18a2. 18-32A, 1B-32A V2 10-33.18-33A, Plan p103 Vt + 18a2. 18a20. 18-338 V3 `~ ~~ BAKER NLlGHES 11\1L`ll Tool BOSS-GYRO )MWD MWD • Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [16 ft/in] • • r~~~ s~~~ ~~ INTEQ North America -ALASKA - BP Prudhoe Bay PBDS18 18-02 Plan 8, 18-02B Plan #8 Travelling Cylinder Report 31 March, 2009 by r BAKER 1~1l3-1~S INTE(~ North America -ALASKA - BP Prudhoe Bay PBDS18 18-02 Plan 10, 18-02B Plan #10 Travelling Cylinder Report 14 April, 2009 by • uri~~ Company: North America -ALASKA - BP Project: Prudhoe Bay Reference Site: PB DS 18 Site Error: O.OOft Reference Well: 18-02 Well Error: O.OOft Reference Wellbore Plan 10, 18-026 Reference Design: Plan #10 Travelling Cylinder Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: ~ ~ Well 18-02 -Slot 02 18-02A @ 46.60ft (Nabors 2ES) 18-02A @ 46.60ft (Nabors 2ES) True Minimum Curvature 1.00 sigma EDM .16 - Anc Prod - WH24P Offset Datum teference Plan #10 ., ~ilter type: GLOBAL FILTER APPLIED: Ali wellpaths within 200'+ 100/1000 of referE nterpolation Method: MD Interva125.00ft Error Model: ISCWSA )epth Range: 10,444.70 to 11,636.20ft Scan Method: Trav. Cylinder North tesults Limited by: Maximum center-center distance of 1,360.57ft Error Surtace: Elliptical Conic ;Survey Tool Program Date 4/14/2009 From To (ft) (ft) Survey (Wetlbore) Tool Name 100.60 8,900.60 18-02 Boss (18-02) BOSS-GYRO 8,960.00 9,699.00 18-02P61 MWD (18-02AP81) MWD I, 9,711.00 10,444.70 18-02 MWD (18-02A) MWD 10,444.70 11,636.20 Plan #10 (Plan 10, 18-026) MWD Casing Points Description Sperry-Sun BOSS gyro muitishot MWD -Standard MWD -Standard MWD -Standard __ __ ____ { Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 11,636.20 8,940.25 2.875" 2.875 4.125 CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/14/2009 11:20:03AM Page 2 of 14 COMPASS 2003.16 Build 70 swuss ' INTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Reference Site: PB DS 18 Site Error: O.OOft Reference Well: 18-02 Well Error: O.OOft Reference Wellbore Plan 10, 18-02B Reference Design: Plan #10 Travelling Cylinder Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: CJ Well 18-02 -Slot 02 18-02A @ 46.60ft (Nabors 2ES) 18-02A @ 46.60ft (Nabors 2ES) True Minimum Curvature 1.00 sigma EDM .16 - Anc Prod - WH24P Offset Datum by Summary Site Name Offset Well -Wellbore -Design PB DS 02 02-38 - 02-38 - 02-38 PB DS 18 18-01 - 18-01 - 18-01 18-01 - 18-01 A - 18-01 A 18-02 - 18-02 - 18-02 18-02 - 18-02A - 18-02A 18-02 - 18-02AP61 - 18-02AP61 18-03 - 18-03 - 18-03 18-03 - 18-03A - 18-03A 18-03 - 18-036 - 18-03B 18-04 - 18-04 - 18-04 18-04 - 18-04A - 18-04A 18-04 - 18-046 - 18-046 18-04 - 18-04B -Plan # 6b 18-04 - 18-04BPB1 - 18-046P61 18-05 - 18-05 - 18-05 18-05 - 18-05A - 18-05A 18-05 - 18-05A - 18-05A wp07 18-11 - 18-11 - 18-11 18-11 - 18-11DPN - 18-11DPN 18-17 - 18-17 - 18-17 18-19 - 18-19 - 18-19 18-27 - 18-27 - 18-27 18-27 - 18-27A - 18-27A 18-27 - 18-276 - 18-276 18-27 - 18-27C - 18-27C 18-27 - 18-27C -Plan #102 18-27 - 18-27D - 18-27D 18-27 - 18-27DP61 - 18-27DP61 18-28 - 18-28 - 18-28 18-28P61 - 18-28P61 - 18-28PB1 18-29 - 18-29 - 18-29 18-29 - 18-29A - 18-29A 18-29 - 18-296 - 18-296 18-29 - 18-29BPB1 - 18-296PB1 18-29 -Plan 18-29C -Plan #2 18-29C 18-31 - 18-31 - 18-31 18-31 - 18-31 A - 18-31 A 18-31 - 18-31 PB1 - 18-31 P61 18-32 - 18-32 - 18-32 18-32 - 18-32A - 18-32A 18-32 - 18-32A -Plan #103 18-32 - 18-326 - 18-32B Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft) (ft) (ft) 10,467.99 11,562.10 977.17 10,450.00 11,125.00 1,177.29 10,500.00 10,500.00 0.08 10, 448.61 10, 475.00 153.21 11,628.25 9,000.00 1,245.57 11,265.27 9,800.00 1,211.34 10,540.00 10,675.00 1,160.36 11,636.20 8,825.00 1,219.61 No-Go Allowable Distance Deviation Warning (ft) from Plan (ft) 913.80 758.78 Pass -Major Risk Out of range Out of range 971.71 1,104.68 Pass -Major Risk 0.89 -0.81 FAIL -Major Risk 694.65 -263.05 FAIL -Major Risk 840.68 801.37 Pass -Major Risk 712.26 519.72 Pass -Major Risk 963.96 356.41 Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 641.36 938.16 Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/14/2009 11:20:03AM Page 3 of 14 COMPASS 2003.16 Build 70 Alaska Department of Natural R~ces Land Administration System ~ Page 1 of~ ~.~ °~.Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Na#ural Resources ~~~ ~~:; Alaska DNR Case Summary File Type: ADL File Number: 28307 ~- Printable Case File Summary See Township, Range, Section and Acreage? ~ New Search ~~ Yes ~;~ No LAS IVlenu I Case_Abstract I Case Detail I Land Abstract File: ADL 28307 '~"' Search for Status_Plat Updates As of 04/20/2009 Customer.• 000107377 BP EXPLORATION (ALASKA) [NC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784_ OIL & GAS LEASE COMP DNR Unit.• 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 014E Section: 13 Section Acres: 640 Search. Plats Meridian: U Township: Ol 1N Range: 014E Section: 14 Section Acres: 640 Meridian: U Township: Ol IN Range: 014E Section: 23 Section Acres: 640 Meridian: U Township: O11N Range: 014E Section: 24 Section Acres: 640 Legal Description 0~-28-1965 *SALE NOTICE LEGAL DESCRIPTION* C14-128 11 N 14E UM 13,14, 23, 24 2560.00 U- 3- 7 End of Case Summary Last updated on 04/2012009. cfm?FileTvne=ADL&FileNumber=2830... 4/20/2009 Alaska Department of Natural l~urces Land Administration System ~ Page 1 off g-~ • .Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28308 ~ Printable Case File Summary. See Township, Range, Section and Acreage? r-~ ~% Yes ~i No New Search LAS Menu ~ Case Abstract I Case Detail I Land Abstract File: ADL 28308 '-` ~ Search for Status Plat_Updates As of 04/20/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784. 0[L & GAS LEASE COMP DNR Unit: 780 0[L AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/ 1965 Office of Primary Responsibility: DOG D[V OIL AND GAS Last Transaction Date 12/04/2006 Case ,Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: Ol 1N Range: 014E Section: 25 Section Acres: 640 Plats Meridian: U Township: 011 N Range: 014E Section: 26 Section Acres: 640 Meridian: U Township: O11N Range: 014E Section: 35 Section Acres: 640 Meridian: U Township: Ol 1N Range: 014E Section: 36 Section Acres: 640 Legal Description 05-28-1965 * * *SALE NOTICE LEGAL DESCRIPTION* Cl ~-129 I 1 N 1-1E UM 25, 26, 35, 36 2560.00 U- 3- 7 End of Case Summary Last updated on 04120/2009. Search .cfm?FileTvpe=ADL&FileNumber=2830... 4/20/2009 C~ TRANSMITTAL LETTER CHECKLIST WELL NAME __ f ~ /~ Q~~ PTD# e~?Q O ~,~ / Develo ment S p e Non-Conventional Well rvice Exploratory Stratigraphic Test FIELD: ~.E'!/,D~/DE" AY POOL: ~,eL/Q f ~O~ /~ 9/~ G , , ~ / Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing (If last two digits in API number wel l } Permit No. ,API No. SO- - _ are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 2S.OOS(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (SO- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 2S.OSS. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception, assumes the liability of any protest to the spacing exception that may occur . DRY DITCH SAMPLE q(I dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Well please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Comaany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _(Companv Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: I / I 1 /2008 WELL PERMIT CHECKLIST Field ~ Pool PRUDHOE BAY, PRUDHOE OIL -640150 Well Name: PRUDHOE BAY UNIT 18-026 Program DEV Well bore seg ^ PTD#:2090460 Company BP EXPLORATION~(ALAStCA) INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11650 OnlOff Shore ~ Annular Disposal ^ Administration 1 Permit-feeaitached----- - ----------- --- -- - NA - ------ ---- -- -- -- --- -- -- - - - --- -- 2 lease numbersppropriate -- ------ - ------- - Yes - ----- -- -- -- - - - -- ------- -- - 3 Unlqueweil-nameandrumber -- -- -- -- - - - ---- --- Yes - - -- -- -- -- ------ - - - - ----- -- - - 4 Welliocatedina_definedpool- ---------- -- - - - ------- Yes - -- -- -- --- --- --- - - -- - -- -- - - 5 Weilloc~tedp[operdisianGef[om_drUlingunitboundary----------------------- Yes- -------------------------------------------------------------------------- 6 Weil locatedP[opQrdistanoef[omotherwelis--------------------------- Yes- --------------------------------------------------------.----------------- 7 Suffoiertaoreage_ayailabletndrillirgunii_______-_______--__--__--____ Yes. _-.__-256QaCres___________________- 8 Ifdeviated,is-wellboreplatincluded--------- --- - --------- Yes --- -- --- -- -- -- --- - -- --- ------ - 9 9peratoronlyaffeciedparty---- -- - -- --- - -- Yes- - --- --- - -- ------ -- --- --- -- -- - -- -------- 10 Opecatorhasapproprtate.bondinforCe__.__._.________--__________-_ Yes- ------Blanketf3ond#6194193.--___________________________________-__-___--____ 11 Petmiteanbeissuedwithoutconservafionorder----------------------- -- Yes- ----------------------------------------------------------.-_--- Appr Date 12 Petmitr~nb8issuedwithoutadministCativeapproyal------------------------- Yes- --------------------------------------------------------------.--_. -- 13 Can permit beapRrov_edbefon315•day-wait---- -- -- - - --- - Y~- -- -- -- - -- -- ------ -- --- -- -- - --- --- -- -- ACS 412012009 14 Well located within area and straiaeuihorizedky-InjeotiorOrde[#(puiJO#incommerts)-(For_ NA- ---------------------------------------__.___--_---_-----__-______-- 15 Ali wellsv~ithin114-mile area of review identified(FO[servicewell only)--------------- ~-_ -______---_--_---_---_---_---_--.----_-----.------.-_---_---_---_-.- 16 Pre-produced injector; duration of pre-ptoduotionless tban_3months_(Forsecvicevrellonly)__ NA_. _____________________________-____-_________-___-___-_-_.-_.__--_ 17 Nonconven gas-conforms to AS31,05.03QQ.1.A)~(L2.A-D) - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductorstnng_provided________________________--__--_________ NA_ .--_--Conductorset_inDS18.02(182-092).___.-..----------.-_-----_------ .-._-__--- Engineering 19 Surface-casirg_protectsail known USDWS------------------------------- KA__ - _NOaquif~rs,AIQ48corclusign5.-_--_--_------ ---- -- ------------------------- 20 CMT_val_adequate_tocirculateoneonductor_&surf_csg--__----_____---_--__ NA__ _____-Surface casing set in_DS1-fl•Q2-----------------------------_-------_--__-__--_ 21 CMT_voladequate_tone-in long string to surf csg_-___-----------------_-_ NA__ --__--Production-casing set in_DS_1.8.02,_________-_______-__--__-______.--_-------_--- 22 C-MT will rAyerall knownproduotiye horizons- - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - 23 Casingdes'k)nsadequatef9rC,? 8&_permafrost --- -- -- -- -------- Yes- -- - -- -- -- --- --------------- -- - - -- -- -- ---- 24 Adequate tankage_or reserve pit - - - - - - - _ - - - - - - - - - - - - - - - - - Yes - - - - - - -Rig equipped with steel pits, No-reserve pit plarned._ Ail waste_to approved disposal wel_I(s). - - - - - _ - - - _ - - - 25 Ifa-re-drili,has_a10.403forabandorment been approved____________________ Y_es- __---309,135-_________-_____________________--_____--__--__-____--_-- 26 Adequate weilgo_re separationproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - Yes - - - _ - -Proximity- analysis performed, Nearest segment is P$A p4rtion_ of DS 18-02A and_ paths diverge,- - - _ - . - - - 27 If divertertequired,doesitmeetregulations------------------------------- NA_- -___l30Pstackwillalready-be inplaee.--------___--__-___---__--------------_---_--_ Appr Date 28 Dulling fluid_program schematic & e4uip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - Yes - - _ - - - _ Maxjmum expected formafion pressure._ 7.3 EMW.- MW planned 8.& ppg, _ - - _ _ . - _ - - - - - - - - - - - - - - - - TEM 4!2212009 29 ROPES, do they meetregulation - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - 30 130PE_press rating appropriate; Zest to_(puf prig in comments)- - - - - - - - - - - - - - _ - - Yes - - _ - - - _ MASP calculated at 2427 psit 3500_psi_BOP tesiplanned, _ - - - - - - - - - - - - - - - - - - - - _ - - - _ `~ 31 Choke_manifoid camplieswlAPI_RP-53 (_May $4)- - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown_____------------------------ Yes- ----------------------------------------------------------.------_---- 33 Is presence_of H2S gas probable - - - - - - - - - - - - - - - - - - - - _ - - - _ - - - _ - - - Yes - _ - _ Low H2$is present at DS_18, Mud should_preclude H2S on riq. Rig has sensors and alarms, - - _ . _ _ - _ - - . _ 34 Mechanical condition of wells withinAQRyenfed(FOrservicewell orly)_____-_--- NA__ ___------------------------------------__-----.-_-.-----------__-------_ 35 Permii_canb8issuedwlohyd[ogensuffdemeasures__------___------------- No__ ____-Max_IeveIH2$20ppmonwe1118-18B_(61281QSa.______________._-.--:----------__.--_- Geology 36 Data_presented orpotential ove_rRressurez4nes - - - - - - - - - - - - - - - - _ - - _ Appr Date 37 Seismicanaysis_ofsbaliowgas_zQnes------ - - - --- ---- - - ~- --------- -- - - -~ --------------- -- -- _ ---------- ACS 4/20!2009 38 Seabed conditionsurvey_(ifoff-shore)--------------------------------- NA__ ________--__--__--__--__-___--____________--___--__--__--_____ - -.. 39 ContaGinamelphoneforweekly_proq-ressreports-[exploratory only]_________________ Yes_ ______MelRixse,564-562Q.__--__-____-_______________--__--___-_--___-___________ Geologic Engineering Public Date Dale Date: Commissioner: Commissioner Co missioner. g ~~~/ Welt 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. • tapescan.txt **** REEL HEADER **** MWD 09/10/30 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/08/15 2732222 Ol 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 10238.5000: Starting De th STOP.FT 11249.5000: Ending Depth STEP.FT 0.5000: Level spacing NULL. -999.2500: Absent value COMP. COMPANY:. BP Exploration (Alaska), Inc. WELL. WELL: 18-026 FLD FIELD: Prudhoe Bay Unit Loc LocATION: 70 deg 17' 35.252"N 148 deg 26' 55.555"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 15 Aug 2009 API API NUMBER: 500292076202 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 24 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 46.6 DMF DF EKB .F 0 EDF .F 46.6 EGL .F 0 CASE.F N/A OSl DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVOSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. Page 1 ~~_b~~D l ~~ ~~ tapescan.txt (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to lob this well.. (6) Tools ran in the string included casing collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth ad,77'usted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 17 Aug 2009 per Doug stoner with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from 18-02A through a milled window in a 7 inch liner. Top of window 10495 ft.MD (8600.9 ft.TVDSS) Bottom of window 10502 ft.MD (8607.6 ft.TVDSS) RA Tag 10498 ft.MD (8603.8 ft.TVDSS) (9) Tied to 18-02A at 10250 feet MD (8364.0 feet TvD55). (10) The interval from 11224 feet to 11251 feet MD (8804.5 feet to 8806.7 feet TvD55) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~VG -> Rate of Penetration, feet/hour TvDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, 10240.9, 10241.5, 10245.1, 10245.2, 10246.9, 10247.8, 10250.1, 10250.6, 10253.5, 10254, 10254.9, 10254.9, 10256.6, 10257.1, 10258.9, 10259.4, 10264.1, 10264.1, 10268.2, 10268, 10269.5, 10269.8, 10273.8, 10274.5, 10274.8, 10275.6, 10280.8, 10281.5, 10285.6, 10286, 10288.5, 10289.4, 10293.5, 10293.7, 10296.6, 10296.7, 10301.6, 10301.9, 10307.9, 10307.3, 10487.8, 10487.7, 10495.7, 10495.4, 10497.3, 10497.9, 10499.1, 10500.2, 10507.9, 10507.8, 10524.3, 10524.1, 10525.9, 10526.2, 10547.2, 10547.4, 10548.5, 10549.9, 10551.5, 10552.4, 10563.4, 10564.4, 10566.6, 10567.5, 10573, 10573.6, 10579.1, 10580.4, 10593.9, 10595.5, 10598.9, 10599.1, 10602.8, 10603.4, 10606.6, 10606.4, 10621.1, 10622.3, 10623.9, 10624.3, 10625.2, 10626.5, 10627.5, 10628.1, 10630, 10630.8, 10638.4, 10639, 10641.3, 10641.8, 10644.2, 10645.6, DISPLACEMENT 0.538086 0.179688 0.897461 0.538086 0.538086 0 0.538086 0.538086 0 -0.179688 0.358398 0.717773 0.717773 0.717773 0.358398 0.896484 0.178711 0.179688 0.358398 -0.539062 -0.178711 -0.359375 0.538086 1.07617 -0.179688 -0.178711 0.358398 0.179688 1.43555 0.897461 1.07617 0.896484 0.538086 1.25586 1.61426 0.179688 0.538086 -0.179688 1.25586 0.358398 1.25586 0.538086 0.717773 0.538086 0.538086 1.43555 Page 2 r~ u tapescan.txt 10652.2, 10654.2, ! 1.97363 10666.8, 10668.8, ! 1.97363 10699.9, 10700.5, ! 0.538086 10712.5, 10712.5, ! 0 10718.4, 10717.9, ! -0.539062 10735.1, 10733.5, ! -1.61426 10740.7, 10739.1, ! -1.61426 10754.5, 10754.5, ! 0 10763.5, 10762.4, ! -1.07617 10767.4, 10766.9, ! -0.538086 10769.6, 10769.6, ! 0 10786.2, 10783.9, ! -2.33301 10803.6, 10803.2, ! -0.358398 10808.3, 10806.8, ! -1.43555 10817.6, 10815.8, ! -1.79395 10835.3, 10835.2, ! -0.179688 10841.4, 10840.4, ! -1.07617 10849, 10847.5, ! -1.43555 10855.2, 10852.9, ! -2.33203 10862.8, 10861.7, ! -1.07617 10870.4, 10866, ! -4.48535 10877.4, 10873.7, ! -3.76758 10917.2, 10913.2, ! -3.94727 10920.2, 10915.9, ! -4.30566 10934, 10930.6, ! -3.4082 10936.9, 10934.2, ! -2.69141 10943, 10941.3, ! -1.61426 10950, 10948, ! -1.97363 10959.6, 10956.6, ! -3.0498 10974.9, 10971, ! -3.94727 10984.3, 10980.8, ! -3.4082 11028.2, 11025.1, ! -3.0498 11037.1, 11036.2, ! -0.897461 11041.4, 11042, ! 0.538086 11043.6, 11044.5, ! 0.897461 11083.2, 11082.5, ! -0.717773 11138.9, 11141, ! 2.15332 11140.8, 11143, ! 2.15234 11149.1, 11150, ! 0.896484 11160.8, 11159.3, ! -1.43555 11164, 11163.1, ! -0.896484 11168.8, 11166.7, ! -2.15332 11181.6, 11180.1, ! -1.43555 EOZ END BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 160 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 Page 3 tapescan.txt The data presented here is final and has been depth adjusted a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 17 Aug 200 per Doug Stoner with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Loggin direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 one depth per frame (value= 0) Datum Specification Block sub-type is: FRAME SPACE = 0.500 * F 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 F/HR Total Data Records: 25 1 Size Length 4 4 4 4 --- 8 Tape File Start Depth = 10238.500000 Tape File End Depth = 11249.500000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 2 34 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MwD data. • Page 4 *** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) optical Lod Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.250 * F 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 F/HR Total Data Records: 49 tapescan.txt 1 size Length 4 4 4 4 8 Tape File start oepth = 10238.000000 Tape File End Depth = 11250.750000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 3 58 records... Minimum record length: 54 bytes Maximum record length: .4124 bytes **** TAPE TRAILER **** MWD 09/08/15 2732222 O1 **** REEL TRAILER **** MWD 09/10/30 BHI O1 Page 5 Tape Subfile: 4 Minimum record length: Maximum record length: tapescan.txt 2 records... 132 bytes 132 bytes D Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP 10238.5000 -999.2500 -999.2500 10239.0000 -999.2500 -999.2500 11249.5000 0.0000 0.0000 Tape File start Depth. = 10238.500000 Tape File End Depth = 11249.500000 Tape File revel Spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP 10238.0000 -999.2500 -999.2500 10238.2500 -999.2500 -999.2500 11250.7500 -999.2500 -999.2500 Tape File start Depth = 10238.000000 Tape File End Depth = 11250.750000 Tape File revel Spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 4 is type: CIS Page 6
