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Home My WebLink About193-057Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / C~?.- ~.~-~¢ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] - Logs-of vadous kinds . [] Other COMMENTS: Scanned by: Dianna Vincent Nathan Lowell Date; TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si • OF T� Alaska Oil and Gas y w \ ��j , � s THE STATE G OVERNOR SEAN PARNELL 4- ,, - _ tt ° ALASKA 333 West Seventh Avenue O Anchorage, Alaska 99501 -3572 ALA Main: 907.279.1433 Fax: 907.276.7542 John McMullen Ep JAN 1 2013 Engineering Team Leader SCON _ o BP Exploration (Alaska), Inc. 1 P.O. Box 196612 Anchorage, AK 99519 -6612 . --4 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06 -22A Sundry Number: 312 -478 Dear Mr. McMullen: 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, D. ► 'el T. Seamount, Jr. ,.// " ommissioner DATED this < day of December, 2012. Encl. • STATE OF ALASKA � RECEIVED ' ' ALASKA OIL AND GAS CONSERVATION COMMISSION qiirk. 4 i ` APPLICATION FOR SUNDRY APPROVAL v A p' l w DEC 13 2012 20 AAC 25.280 \V AOGCC �°► 1. Type of Request: AOGCC ❑ 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 193 -057• 3. Address: ® Development. ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50. 029 - 20806 - 01 - 00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 06 -22A • Will planned perforations require a Spacing Exception? ❑ Yes N o 9. Property Designation 10. Field / Pool(s): ADL 028311 Prudhoe Bay Field / Prudhoe Bay Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10681' • 9237' 10600' • 9159' None Unknown Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2519' 13 -3/8" 2519' 2519' 4930 2670 Intermediate 9297' 9 -5/8" 9297' 7915' 6870 4760 Production Liner 3173' 7" 7508' - 10681' 6519' - 9237' 8160 7020 Scab Liner 5162' 7" 2348' - 7510' 2348' - 6521' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10451' - 10502' • 9016' - 9065' 3 - 1/2 ", 9.2# / 9.3# 13Cr80 / L - 80 9681' Packers and SSSV Type: 7" x 4 Baker Premier Packer; Packers and SSSV • 7397' / 6442' 7" x 4 -1/2" Baker Premier Packer; MD (ft) and TVD (ft):, 9471' / 8076' 7" x 3 -1/2" Baker SABL -3 Packer • 9615' / 8212' 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 December 21, 2012 • ❑ 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: Ron Phillips, 564 -5913 Printed Name: John McMullen n Title: Engineering Team Leader Email: Ron.Phillips @bp.com Fog 'J - c�rtfll - /Li/477 (c-U S S Signature» 7 Phone: 564 - 4711 Date: / ,Z _ ( - t Z Commission Use Only Conditions of approval: Notify Commission so that a representative may witness L`3 �� Sundry Number: ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: SOP ft h 3.5 I w Spacing Exception Required? ❑ Yes No Subsequent Form Required: /0 1 a APPROVED BY /Z-72W/ L Approved By: � V t . COMMISSIONER THE COMMISSION Date: -- F. i 1 Zs i Q /2Al2I Approved application is valid for 12 months from the date of approval Submit In Duplicate S op • • To: Alaska Oil & Gas Conservation Commission From: Ron Phillips b P CTD Engineer Date: December 11, 2012 Re: 06 -22A Sundry Approval Sundry approval is requested for well 06 -22A. HISTORY Well 06-22A is a rotary ST drilled in May 1993 but not completed initially due to lower than expected NLOC and a leaking casing patch at 2980'. A RWO in Nov 1993 ran a 7" scab liner to repair the casing leak and then ran 3 -1/2" tubing. Initial perfs were shot (10,482 -502') in Zone 2B above the HOT, but the well didn't flow. A 75 bbl HC1 acid stim was pumped with no response, followed with 8' adperfs in March 1994 with short lived benefits. Two additional sets of adperfs were shot, but the 3rd set from 10451' -461' was finally successful. The well was produced until Aug 1999 when it was shut - in for a PC leak. From 2003 -2004 it flowed under a temporary integrity waiver. In 2008 a RWO was completed that restored wellbore integrity. The well was brought online and flowed until reaching MGOR in 2011. Well 06 -22A is currently cycling with degrading production and ontime. REASON FOR SIDETRACK The well 06 -22A is not a competitive producer due to a high GOR, and there are no remaining well work options. The proposed sidetrack will access Zone 2B reserves in a —60 acre target in north- eastern DS 06. PROPOSED PLAN The proposed plan for 06 -22A is to drill a pilot hole through a cement plug, set a 2 -5/8" OH Anchor whipstock in the pilot hole and drill a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing. The existing perforations will be isolated by a cement plug to be laid in by service coil pre -rig as well as the primary cement job for the liner. The sidetrack, 06 -22B, will exit the existing 7" liner and kick off and land in the Ivishak. This sidetrack will be completed with a 2 -3/8" liner in the production interval. The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. �r e P ti lOctior,/ �,y �1t� /� 1$1/1G n�f4(c 6-v- rA4/4 /l ecAt g c Gtn �� /�/ t o uh /e i �e G oR p T e a' v ' e // s ( �i , �y y , r0 ., d e r O f ,irco✓e-A ei t 44- ;'., ,,y r wr r n r Jt v ` ' �'P f' 'rraticit r) w€ C/ sloid i nor drn 602 Gf de (C e 1 40 A !` 3 'b r ' 8/1 6 ` /fie fe d�. j • Pre -Rig Work: (scheduled to begin December 21 2012) 1. F MIT- IA to 3,000 psi, MIT -OA to 2,000 psi) 2. W Cycle LDS; PPPOT- T to 5,000 psi 3. C Set 48 bbl, 17 ppg cement plug in the 7" casing. Clean out down to 9,650'. 4. V PT MV, SV, WV. 5. S Drift tubing down to 9,650' with 2.75" centralizer. 6. F MIT -T to 2500 psi. (Wait 24 hours on compressive strength of cement.) Bleed wellhead pressures down to zero. 7. 0 Bleed production flow lines and gas lines down to zero and blind flange. 8. 0 Remove wellhouse, level pad. PE A - Rig Work: (scheduled to begin on January 15, 2013) 312 4 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. iVt /7,9 neotL 2¢ h r3 I r? adr - r ' e2 ' 2. Drill 2.75" pilot hole from top of cement at 9,650' down to 10,295' (50' Rat hole). 3. Calliper Pilot hole using PDC logging conveyed on coil. 4. Run dummy whipstock drift. 5. Run and set 2 -5/8" OH anchor whipstock at 10,245' (Top of Whipstock) 6. Mill 2.74" window at10,245' and 10' of rathole. 7. Drill Build: 3" OH, 391' (23 deg/100 planned) 8. Drill Lateral: 3" OH, 792' (12 deg/100 planned) with resistivity 9. Run 2 -3/8" 13CR-80 liner leaving TOL at 9,510' MD 10. Pump primary cement leaving TOC at 9,650' MD, 6.6 bbls of 15.8 ppg liner cmt planned. 11. Make a liner cleanout run. 12. MCNL /GR/CCL log. fi 13. Test liner lap to 2,400 psi 14. Perforate liner per asset instructions ( -200') T P 15. Freeze protect well, set BPV, RDMO 712, - 181. Post -Rig Work: 1. Set 3 -'/2" liner top packer, and test to 2,400 psi (if fails liner lap test) 2. Re- install wellhouse and FL's. 3. Generic GLV's Ron Phillips CTD Engineer 564 -5913 CC: Well File Sondra Stewman/Joe Lastufka TREE _ CM/ I 11�ELLHEAD = FMC • SAFE�TES: """CHROME TBG & NIPPLES"'' ACTUATOR = BAKER C 0 6 -2 2 A KB. ELEV = 63.0' BF. ELEV'= KOP = 2900' ' 1 I 2117 H 3 -1 /2" HES X NP, ID = 2.813" I Max Angle = 48° @ 6800' Datum MD = 10355' (TOP OF 7" LNR I� 2348 I I 2348' H 9-5/8" X 7" BKR C-2 ZXP LTP, 10 = 6.290" I Datum TVD = 8800' SS , t ,�' 2365 H 9 -5/8" X 7" BKR FLEXLOCK LNR HGR, ID = 6.350" I •1 X GAS LIFT MANDRELS •. 1 113 -3/8" CSG, 72 #, L -80, ID= 12.347" I-I 2519 I ∎� A ST MD TVD DEV TYPE VLV LATCH PORT DATE �� X 1 1 3 3230 3217 19 MMG DMY RK 0 11 /21 /11 �� X 1 1 2 5583 5116 38 MMG DMY RK 0 11 /21 /11 44 �•1 1 7302 6377 46 MMG DMY RK 0 05/12/08 Minimum ID = 2/5" @ 9669' ,S a i l �' ' r ,.' I 7372' I-1 3 -1 /2" HES X NP, ID = 2.813" I 3 -1/2" PARKER SWN NIPPLE 1 �� X 7392 I--I 3 -1 /2" X 4 -1 /2" XO, ID = 2.960" I 1 1 1 I 7397 - H 7" X 4 -1 /2" BKR PREMIER PKR, ID = 3.875" I 1 ,1, I� 014' 7407' H 4 - 1/2" X 3 XO, ID= 2.970 I o 1 7" LNR, 26 #, L -80 BTGM, -I 7491 #1 �1� 0383 bpf, = 6.276" �� ' �• 7439 H 3 -1 /2" HES X NIP, ID = 2.813" I I7" BOWEN CSG PATCH w /SEALS I-L 7506' I •�' 9087' 1 -JTIW TYPE LG SEAL ASSY, ID = 6.200" I 1 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 9087' 1 ' 9118 1 9 -5/8" X 7" TIW LTP w /TM/ LNR HGR & J TIEBACK SLV, ID = 6.18" TOP OF 7" LNR -I 9126 ( = MILLOUT WINDOW (06 -22A) 9297' - 9347' I 19 -5/8" CSG, 47 #, L -80, ID = 8.681 " H 9297 I 9466' H 3 -1 /2" X 4 -1 /2" XO, HD = 2.960" I 9471' H 7 -1 /2" X 4 -1 /2" BKR PREMIER PKR, ID = 3.875" I PERFORATION SUMMARY \� I 9483' H4 -1/2" X 3 -1/2" XO, ID= 2.960" I RE= LOG: BHCS ON 05/03/93 ` ANGLE AT TOPPERF:91° @10451 9514 I� 3- 1 /2 "HESXNIP,O= 2.813" Note: Refer to Production DB for historical pert data 9581 I� 7 -1/2" X 3 -1/2 UNIQUE OVERSHOT I SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/8" 4 • 10451 - 10461 O 07/04/94 9591' I� 3 -1/2" PARKER SWS NIP, 0= 2.813" I 2 -1/8" 4 10461 - 10466 O 05/14/94 , 9615 I-1 7" X 3 -1/2" BKR SABL -3 PKR, ID = 3.87" I 2 -1 /8" 4 10466 - 10474 O 04/27/94 2 -1 /8" 6 10474 - 10482 O 03/03/94 1. 9652 H 3 -1 /2" PARKER SWS NP, ID = 2.813" I 2 -1/8" 4 10482 - 10502• O 11/16/93 1\ \► 9669 J 3 -1/2" PARKER SWN NP, ID = 2.75" 13 -1 /2" TBG, 9.2#, 13CR -80 VAM TOP,.0087 bpf, ID = 2.992" H 9566 ? I— FISH -HES BB 13 -1/2" TBG STUB (05/06/08) I-1 9569' PLUG ELEMENT (06/16/08) 13 -1/2" TBG -IPC, 9.3#, L -80 TDS,.0087 bpf, ID = 2.992" H 9681 I 9681 I — 3 - 1/2" WLEG 1 7" MKR JOINT H 10266' I m = 2.992" . I PBTD I� 10600' I i \%4. I 9685 I- E.MD TT LOGGED \i ►► 03/19/97 17" LNR, 29#, L -80 NSCC, .0371 bpf, ID = 6.184" H 10681 I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/30/82 ORIGINAL COMPLETION WELL: 06 -22A 11/05/93 D16 RWO PERMIT No: 1930570 05/13/08 D16 RWO API No: 50- 029 - 20806 -01 04/30/09 AW /JMD DRLG DRAFT CORRECTIONS SEC 2, T1 ON, R14E, 584' FSL & 985 FEL 11/25/11 JLJ /JMD GLV GO (11/16/11) 11/28/11 JLJ /JMD GLV GO (11/21/11) BP Exploration (Alaska) aIVaLFEAD = FMC • 06 -22 B SAFI IOTES: '* = CHROME TBG & MPPLES I ACTUATOR= BAKER C KB. aEV = 63.0' Pre -rig CTD Sidetrack BF. EEV= I KOP= 2900' I 2117' H3-1/Z' HE5 X NP, D = 2.813" Max Angie = 48° (06800' Datum DatumA421= = 8800' I TOP OF 7" LNR - I 2348' . 2348' H9-5/8" X 7" BKR C-2 ZXP LTR ID= 6.290" I 4 1 41 2365' H9-5/8" X 7" BKR FLD�OCK LNR HGR, D = 6.350" I 4 1 * 1 GAS LFT MANDRELS " � 4 ' ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8" CSG, 72#, L-80, D= 12.347" H I 4� 1 4 1 3 3230 3217 19 MMG DMY Po( 0 11/21/11 41 / * ( 2 5583 5116 38 MMG DMY RK 0 11/21/11 t �� 1 7302 6377 46 MMG DMY RK 0 05/12/08 Minimum ID = 2.75 9669 j � I 7372• H3 -1/2" HES X MP, ID = 2.813" I 3 -1/2" PARKER SWN NIPPLE t ri V • I 7392' I-I3 -112" X 4 -1/2" XO, ID = 2.960" 41 • A 4 tj 0 I 7397' H7` X 4 -1/2" BKR PREMIER PKR, ID = 3.875" I 7" LNR, 26#, L -80 BTC-M, - 7491' I ,4 ; 4 ( I •i1 I 7407' H4 -1/2" X 3-1/2" XO, ID = 2.970" .0383 bpf, D = 6.276' •i i "V ‘� 1 I 7439' H H3-1/2" HES X NP, ID = 2.813" I IT BOWEN CSG PATCH w /SEA LS H 7506' I •1 1•( 41 / • I 9087' I --ITIW TYPE LG SEAL ASSY, ID = 6.200" I 17" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 9087' • I 11 • 9118" 9-5/8" X 7" TMV LTP w mvv LNR HGR & TEBACK SLV, D = 6.18" MLLOUT WIDOW (06 - 22A) 929 9466' H3 -1/2" X 4 -1/2" XO, ID = 2.960" I 7' - 9347' I I 111 l 1 I 9471' H7 -1/2' X 4 -1/2" BKR PREMIER PKR, ID = 3.875" A I I TOP OF 7" LNR I 9126' I 9 483' H -1/2" X 3 -1 /2' XO, ID = 2.960" I 19 -58" CSG, 47#, L -80, D = 8.681" H 9 2 9 T I 9514' (- I3 -1/2' HES X D = 2.813' 3 -1/2" TBG, 9.2 #, 13 -CR -80 VAM TOP .0087 _I 9566' PERFORATION SUMMARY 4k, bpf, I0= 2.992" REF LOG: BHCS ON 05/03/93 `% ANGLEAT TOPPERF:91•® 10451' Note: Refer to Production DB for historical perf data 1 -1/2" TBG STUB (05 /06 /08) H 9569' I SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/8' 4 10451 - 10461 O 07/04/94 2 -1/8• 4 10461 - 10466 O 05/14/94 I 9581' H7 -1/2' X 3-1/2' UNIQUE OVERSHOT 2 -1/8' 4 10466 - 10474 O 04/27/94 200 S2 -1/8' 6 10474 - 10482 O 03/03/94 I 9581' I-i 3 -112' PARKER SWS MP, ID = 2.813' 2 -1/8' 4 10482 - 10502 O 11/16/93 •, 9615' H 7• X3 -1/2' BKRSABL-3 PKR, 13 = 3.87" \� 9652' 3 PARKER SWS NP, D =2.813" • Tt. j ( 9669' I - 3-1/2' PARKER SWN NP, D = 2.75' 9681' 3-1/2' TBG FC, 9.3#, 1 -80 / ' TDS, .0087 bpf, 1=2.992' Top of cement pilot hole at 9,650' * 111, ► ► . 41 1 ,, ► ■ 16° `,1► I 7" LNR, 29#, L -80 NSCC, .0371 bpf, ID = 6.184" I--I 10681' I DATE REV BY COMIIBJTS DATE REV BY COIi&U41S PRLDHOE BAY UNIT 09/30/82 ORIGINAL COMPLETION 7/16/2012 JCL CTD Sidetrack WELL 06-22A 11/05/93 D16 RWO PERIM ND: '1930570 05/13/08 D16 RHO AR Pb: 50 - 029 - 20806 - 01 04/30/09 AW/JMJ DRLG DRAFT CORRECTIONS SEC 2, T1ON, R14E, 584' FSL & 985 Fa 11/25/11 JLJ/JM) GLV C/O (11/16/11) 11/28/11 JLJ/JM) GLV C/O (11/21/11) BP Exploration (Alaska) TREE= C1VV WELLHEAD FMC • 06 -22 B TB SAFE TES: ** *CHROME G & IMPPLES * ** I ACTUATOR= BAKER C KB . ELEV = 63.0' Proposed CTD Sidetrack BF. FI FV I I KOP= 2900' ' 2117' H3-1/2" HES X NP, ID = 2.813" Max An = 46 Datum M3 - = ----- D = - - - - - 10355' TOP OF 7" LNR 2348' 2348' —19-5/8" X 7" BKR C-2 ZXP LTP, ID= 6290" Datum TV D = 8800' SS f 1 +1 • 2365' — 19-5/8" X 7" BKR FLEXLOCK LNR HGR, ID = 6.350" 0 ••• GAS LIFT MANDRELS � • ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8" CSG, 72#, L -80, ID= 12.347" 2519' , t �� ;�; 3 3230 3217 19 MMG DMY R}( 0 11/21/11 �� 11 2 5583 5116 38 MMG DMY RK 0 11/21/11 ■ 1 1 7302 6377 46 MMG DMY RK 0 05/12/08 Minimum ID = 2.75" @ 9669' �� ,'� I 7372' —{3 -112" HES X NIP, ID= 2.813" 3 -112" PARKER SWN NIPPLE � � y � � ,* 7392' — 13 -1/2" X 4 -1/2" XO, ID = 2.960" �� ► 1 1 . •• I 7397' 7" X 4-1/2" BKR PREMI ER PKR, ID = 3.875" 7" LN 26#, L -80 BTC-M, 1 I R H 749 I �� i 7407' H4 -1/2" X 3 -112" XO, ID = 2.970" .0383 bpf, D = 6.276" •4 "i .� ► i ' 7439' H3 -1/2" HES X NIP, ID = 2.813" I 7" BOWEN CSG PATCH w /SEA I--1 7506' �� ► 0.4 11 I 9087' --ITIW TYPE LG SEAL ASSY, ID = 6.200" 17" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 9087' .� ' IV • 9118' 9-5/8° X 7" TNV LTP w /TNV LNR HGR & TEBACK SLV, D = 6.18" • ■ 9466' H3 -1/2" X 4 -1/2" XO, ID = 2.960' MLLOUT WINDOW (06 -22A) 9297' - 9347' 1 I '� '� I 9471' — I7 -1/2" X 4 -1/2" BKR PREMIER PKR, ID = 3.875' TOP OF 7" LNR H 9126' �1 b1 9483' —{4 -112" X 3 -1I2" XO, ID = 2.960" i t 9 - 5/8" CSG, 47 #, L -80, ID= 8.681" H 9297' I 9514' — 3 - 112" HES X NIP, ID = 2.813" PERFORA TION SUMMARY \ 3 - 1/2" TBG, 9.2 #, 13 - CR - 80 VAM TOP .0087 bpf, ID= 2.992" 9566' ; ; REF LOG: BRCS ON 05/03/93 N ANGLE AT TOP PERF: 91° @ 10451' Note: Refer to Production DB for historical pert data 4111 4. 1 n._ 13 -1/2" TBG STUB (05/06/08) H 9569' SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/8' 4 10451 - 10461 O 07/04/94 2-1r6 a 1oas1 -1o4ss o os/1ars4 I 9581' H7-1/2" X 3-1/2" UNIQUE OVERSHOT 2 -1/8' 4 10466 - 10474 O 04/27/94 Silk 2 -1/8• 6 10474 -10482 O 03/03/94 9591' I-{3 -1/2" PARKER SWS NIP, ID = 2.813" 2 -118' 4 10482 -10502 O 11/16/93 • Top of 2 -3/8" chrome liner 9,510 , 9615' H7" X 3 BKR SABL -3 PKR, 13 = 3.87" • \ 4 9652' HI 3-1/2" PARKER SWS NP, ID = 2.813" 1 11 , - 9669' — 3-1/2" PARKER SWN NP, D = 2.75" 9681' — z ry 3 -1/2" TBG IPC, 9.34, L -80 TDS, .0087 bpf, 113=2.992" Top of liner cement 9,650' Top of cement pilot hole at 9,650' 4 3 -1/2" Mono -bore Whipstock at 10,245' * 2 -3/8" chrome liner with TD 16° 1% • at 11,428' 1 7" LNR, 29 #, L -80 NSCC, .0371 bpf, ID = 6.184" H 10681' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRI JDI DE BAY UNIT 09/30/82 ORIGINAL COMPLETION 7/16/2012 JCL CTD Sidetrack WELL: 06-22A 11/05/93 D16 RWO PERMf No: '1930570 05/13/08 D16 RWO AR No: 50- 029 - 20806 -01 04/30/09 AW /JMD DRLG DRAFT CORRECTIONS SEC 2, T10N, R14E, 584' FSL & 985 Fa 11/25/11 JLJ/JMD GLV C/0 (11/16/11) 11/28/11 JLJ/JMD GLV CIO (11/21/11) BP Exploration (Alaska) NORDIC - CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM V12 --► r-- • '`( + g V14 if 7- 1116" 5000 psi ROP's tD = 7.06" "" Nni �ti;rc � V15 V11 .� v r 1118" 5000 psi. RX<6 Transducers CO In o ECnss '4 V2 v1 V 16 ( — ib a " �o '` w Note typical SOP rgement for 2318" coded tubing drilling � # . + I 7 1/16 5000 psi, Rx46 t 1 1 V17 z HCR I IC II= .' IK OK To Poor Boy Gas Buster J • V111 v+e I •' 2 1or soap.. Rx.24 I • 300 - 5008 psi HCR ® .it .. 111111111111., 1 • 1 11/11 ' 3B Comb 2.106 pail CHECK ... II Y P5 I.'" VALVE Manual Choke "1111111111 wr' " ioiP5P5 �-' �� 71118 Cameron FOV Gate EOH • • Valve x 5000 pm I ct it lir— Line /Diesel • • t— FP Lino CoFlez Hose M I Motion CJ 114 Tum Hako ,,. 10WOCI To Production Tree or Cross Over ' CoFlex Hose T ft •ftritl" CV++ o 4 � Bleed OR r Cement Line In I Ground Level Tie -in I -' CV3 CV2 T Stand Pipe T _ –_ –: `al/ -- – _ – _ 7. _ – A te/ Manual Choke NW - – „ – -- – – Pressure Transducers cv9 ' Melt CO f 4 ' CV17 NM/ MI CV8 Tiger Tank Mud Pum 2 f -�_�_ O O _ _ _ In From Baker MP 1 d MP 2 D 1 11. Choke ; O 0 CV14 to Pits Rig Floor Mud Pump #1 40 CV16 Reverse Circulates& ., Cir CT while OOH `�\/ �� ® 7. r� O 0 0 To Manifold CV15 1 -Jun -2010 Rave... Ci.r ,,t.tlerx fine 1 rr ud•ile nn1 CoFlex Hose OPERABLE: 06 -22A (PTD #19305701ubing Integrity Restored Page 1 Regg, James B (DOA) • From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Wednesday, August 31, 2011 4:23 PM 11,(1 To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, D &C II Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug A; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Stechauner, Bernhard Subject: OPERABLE: 06 -22A (PTD #1930570) Tubing Integrity Restored All, 4/ Producer 06 -22A (PTD #1930570) passed L on 08/30/2011. The passing test confirms the presence of two competent barriers in a well. The well is reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator k 3 L ; 1 , Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Wednesday, August 24, 2011 4:38 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, 0'S FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug A; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIO = LLC); Stechauner, Bernhard Subject: NOT OPERABLE: 06 -22A (PTD #1930570) Producer with Sustained Casin• 'ressure During TAR AII, The following producer was found to have sustained cas g pressure on the IA on 08/22/2011 during the shut down for turnaround activity. The immediate actio' is to perform a TIFL on the well and evaluate for IA repressurization. If the well fails the TIFL, a follow p email will be sent to the AOGCC with a remedial action plan. 06 -22A (PTD #1930570) The well will be classified as Not Oper.• e until start -up operations commence and are stable or the well passes a pressure test proving integr' . After start -up, the well will then be reclassified as Under Evaluation with POP parameters to •revent any over - pressure incident. Please call with any question •r concerns. Thank you, / Gerald Murphy It. Mehreen Vazir) 8/31/2011 NOT OPERABLE: 06 -22A (PTD #193470) Producer with Sustained Casing P•sure During T... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] `�(3a /<< Sent: Wednesday, August 24, 2011 4:38 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug A; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Stechauner, Bernhard Subject: NOT OPERABLE: 06 -22A (PTD #1930570) Producer with Sustained Casing Pressure During TAR All, The following producer was found to have sustained casinapressure on the IA on 08/22/2011 during the shut down for turnaround activity. The immediate action is to perform a TIFL on the well and evaluate for IA repressurization. If the well fails the TIFL, a follow up email will be sent to the AOGCC with a remedial action plan. 06 -22A (PTD #1930570) The well will be classified as Not Operable until start-up operations commence and are stable or the well passes a pressure test proving integrity. After start-up, the well will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incident. Please call with any questions or concerns. Thank you, A 1 1 ,1 8 'Ali, , Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 8/30/2011 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 • ~~ i~ ~~ a 3- ©~'~ 1 ~~f aa-~ Subject: Corrosion Inhibitor Treatments of GPB DS 06 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 06 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-06 Data' 12/1 (l/(19 ~~ Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 06-01 1750490 50029201720000 NA Sealed NA 06-02 1770780 50029202820000 NA Sealed NA o6-o3A 1951520 5o02s201860100 NA Sealed NA o6-oaA 2001020 500292o17so1oo NA Sealed NA 06-05 1780200 50029202980000 NA Sealed NA Os-osB 2050980 50029202010200 NA Sealed NA 06-07 1780210 5oo2s2o2ssoooo NA Sealed NA 06-08A 1951950 50029203000100 NA Sealed NA o6-O9 1790730 50029204000000 NA Sealed NA o6-1oA 1981960 50029204020100 NA Sealed NA Os-11 1791100 50029204280000 NA Sealed NA 06-12A 1920640 50029204560100 NA 0.5 NA 3.40 10/6/2009 06-13A 2061020 50029204570100 NA Sealed NA 06-14B 2090120 50029204580200 NA Sealed NA 06-15 1800320 50029204590000 NA Sealed NA os-16 1800330 50029204600000 NA Sealed NA 06-18A 2090630 5oo2s2o767010o NA 0.3 NA 1.70 11/5/2009 06-19A 2081020 50029207910100 NA 1.5 NA 6.80 10/4/2009 o6-20A 2050790 5ooz9zo7ssoloo NA 1 NA 5.10 10/4/2009 06-21 B 2080990 50029208020200 NA 6 NA 42.50 12/14/2009 o6-22A 1930570 500292o8oso100 NA 1.5 NA 5.10 10/4/2009 06-23C 2080920 50029208080300 NA 4.6 NA 30.60 10/6/2009 os-24A 2000960 50029208220100 NA Sealed NA STATE OF ALASKA ~B' ~°'~ ALP OIL AND GAS CONSERVATION COMMON i~ Lei ; ~ ~,~ REPORT OF SUNDRY WELL OPERATIONS ~ - ~~ Alaska {~16 & , ~ .,a~,~ , (~;~„?omission 1. Operations Performed: E~vl ~~.J;t",;1u4 ^ Abandon ®Repair Well ' ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~er Casing ~ ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. O erator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 193-057 , 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20806-01-00 7. KB Elevation (ft): 63.0. 9• Well Name and Number: PBU 06-ZZA 8. Property Designation: 10. Field /Pool(s): - ADL 028311 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10681 ~ feet true vertical 9237 ~ feet Plugs (measured) 9635' Effective depth: measured 10600 feet Junk (measured) N/A true vertical 9159 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2519' 13-3/8" 2519' 2519' 4930 2670 Intermediate Production 9297' 9-5/8" 9297' 7915' 6870 4760 Liner 8538' 7" 7508' - 10681' 2348' - 9237' 8160 7020 Scab Liner 5162' 7" 2348' - 7510' 2348' - 6521' 7240 5410 ~~~N~~~ JUL ~ ~ 2008 Perforation Depth MD (ft): 10451' - 10502' Perforation Depth TVD (ft): 9016' - 9065' 3-1/2", 9.2# L-80 9681' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker Premier Packers 7397' & 9471' 7" x 3- 1/2" Baker SABL-3 Packer 9615' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 9569'. Cut and pull 7" casing from 7508'. Run 7" (26#, L-80, BTC-M) scab liner and Bowen Casing Patch. Cement w/ 161 bbls Class 'G' 904 cu ft / 779 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Aras Worthin ton, 564-4102 ~ 308-140 & 308-170 Printed Name Sondra L tewman ~ Title Drilling Technologist Prepared By Name/Number. Signature Phone 564-5743 Dat ° ~ ~°'('~, Sondra Stewman 564-4750 r; Form 10-404 Revised 04/2006 ~y ~ ~ ~ 1 ~' ~, ~~~rt ;~ 2Dd~ Submit Original Only rya TREE = CNV WELLHEAD= ACTUATOR = FMC KB. ELEV = BF. ELEV = 63.0' KOP = 2900' Max Angle = Datum MD = 48 ~ 6800' 10355' Datum TVD = 8800' SS DRLG DRAFT O 6'2 2A TOP OF 7" LNR 2348' 13-3/8" CSG, 72#, L-80, ID =12.347" Minimum ID = 2.760" a~ 9669' 3-112" PARKER SWN NIPPLE 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6276" 7491' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9087' ~TOPOF7" LNR ~ 9106' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9297' PERFORATION SUMMARY REF LOG: BHCS ON 05/03/93 A NGLE A T TOP PERF: 91 ° ~ 10451' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL OpnlSgz DATE 2-1 /8" 4 10451 - 10461 C 07/04/94 2-1 /8" 4 10461 - 10466 C 05!14/94 2-1 /8" 4 10466 - 10474 C 04/27/94 2-1 /8" B 10474 - 10482 C 03/03/94 2-1 /8" 4 10482 - 10502 C 11 /16/93 2108) 3-112" TBG-EC, 9.3#, L-80,.0087 bpf, D = 2.992" H 9681' CSCz SPED NIP HAS BEEN WELDED. 2117' I-(3 1 /2" HES X Nippk: D = 2.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3230 3217 19 MMG DOME RK 16 05/24/08 2 5583 5116 38 MMG SO RK 20 05/24/08 1 7302 6377 0 MMG DMY RK 0 05/12!08 7372' 3 1 /2" HES X Nipple ID = 2.813" 7397' 7"x4-112" Baker Premier Pkr, ID=3.875" 7439' 3 1/2" HES X Nipple ID = 2.813" 7506' Bowen 7' Csg Patch w /Seals 908T TIW TYPE LG SEAL ASSY, ID = 6.200" M~LOUT WNDOW 9-5/8" @9297' - 9347' 9471' 7"x4-112" Baker Premier Pkr, ID=3.875" 9514' 3 1 /2" HES X Nipple ID = 2.813" ~ 9566' 3-1/2"x 7" 9Cr Unique Overshot 9591' 3-1/2" PARKER SWS NIP, ID = 2.813" --~. 961S 7" X 3-1/2" BKR SABL-3 PKR, D = 3.87" 9635' -{HES BB RBP (8120105) 9651' 3-1 /2" PA RKER SWS NIP, ID = 2.813" 9669' 3-1/2" PARKER SWN NE, ID = 2.75" 9681' 3-1/2" TBG TAIL WLEG, lD = 2.992" 9685' ELMD TT LOGGED 03/19/97 ~ PBTO H 10600' 7" LNR, 29#, L-80, .0371 t>pf, ID = 6.184" 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 091311182 ORIGINAL COMPLETION 05/13/08 Di6 RWO WELL: 06-22A 11/05/93 LAST WORKOV62 05/16!08 ITCH CORRECTIONS PERMff No: 1930570 09/19/01 RN/TP CORRECTIONS 05/17/08 RLH CORRECTIONS (JUNK CATCHER ) API No: 50-029-20806-Ot 02/14103 ITCH CORRECTIONS 05/29/08 PJGDAV GLV GO (05/24/08) SEC 2, T10N, R14E, 2386.4' FEL &2902.14' FNL 06/13/03 CMOlTLP KB ELEVATION CORRECTION 04/11/04 JLJ/KAK SWN NP ID CORRECTION BP 6cploration (Alaska) s • BP EXPLORATION Page 1 of 17 Operations Summary Report Legal Well Name: 06-22 Common Well Name: 06-22 Spud Date: 9/15/1982 Event Name: WORKOVER Start: 4/21/2008 End: 5/12/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 5/13/2008 Rig Name: DOYON 16 Rig Number: I I Date From - To Hours Task Code Description of Operations NPT I Phase 4/23/2008 00:00 - 02:00 2.00 MOB P PRE PJSM on upcoming activities. R/U Bridle lines and UD Derrick. Pull rig off of S-33 and spot on pad. Install Booster Wheels. 02:00 - 19:30 17.50 MOB P PRE Move off of S-Pad to S-Pad Access Road. Continue from Access Road to DS 6-22A. Total Distance Moved = 20.3 miles. 19:30 - 20:30 1.00 MOB P PRE Rig arrive at DS 6. Spot Rig on pad and remove Booster Wheels. Install BOPs into cellar from carrier. 20:30 - 21:00 0.50 MOB P PRE R/U Bridle lines and Raise Derrick. 21:00 - 22:00 1.00 MOB P PRE Lay Herculite, pull rig over well DS 6-22A. Spot and Shim Rig. 22:00 - 00:00 2.00 MOB P PRE Spot Cutting Tank, and #4 generator, spot #2 mud pump, R/U in cellar and R/U to meet with Pre-Spud Check list. Rig 4/24/2008 00:00 - 01:30 1.50 WHSUR P DECOMP R/U drill site maintenance lubricator and test to 500 asi. Null end UD drill site maintenance lubricator. 01:30 - 02:00 0.50 KILL P DECOMP R/U circulating lines and test surface equipment to 3,500 psi. 02:00 - 03:30 1.50 KILL P DECOMP PJSM and then Circulate 120 deg 9.8 ppg brine at 10 bpm with 2200 psi. While circulating crude oil was observed coming from the OA into the ttin t n in .Loss rate = 2 bpm. 03:30 - 04:30 1.00 KILL P DECOMP Monitor well bore, while waiting on DSM and FMC. -Static. 04:30 - 05:30 1.00 WHSUR P DECOMP Install ISA BPV and ressure test from below to 1 500- si. ' Injection rate established to be 4.8 bpm while holding pressure below BPV. 98 bbl loss while testing. 30 gallons of crude returns from OA to Slo Tan 05:30 - 06:00 0.50 WHSUR P DECOMP R/D and Blow down circulating lines. Bleed pressure off of control lines. 06:00 - 07:30 1.50 WHSUR P DECOMP N/D 5-1/8" 5K Production Tree and Adapter Flange. 07:30 - 08:00 0.50 WHSUR P DECOMP Inspect Tbg hanger threads. Appear to be in good condition. XO to Tbg hanger M/U in 9-1/2 turns. Install ISA BPV Blanking plug w/ 10 rt hand turns. Blanking plug retrieval tool requires 8 left hand turns. 08:00 - 10:00 2.00 BOPSU P DECOMP N/U BOP Stack and Choke and Kill Lines. 10:00 - 11:00 1.00 BOPSU P DECOMP R/U all equipment to test BOPE. 11:00 - 12:00 1.00 BOPSU P DECOMP Begin BOP test per BP and AOGCC standards. Low pressure test to 250-psi, High Pressure test to 3500-psi. Hold and Chart all tests for 5 minutes. AOGCC representative, Chuck Scheve, waived witness of test. All tests witnessed by BP WSL and Doyon Toolpusher. Total losses for tour = 294 bbls. 12:00 - 17:00 5.00 BOPSU P DECOMP Continue BOP test. All tests went well until attempting to test 3-1/2" test joint. Troubleshoot and discover annular element leaking. 17:00 - 21:30 4.50 BOPSU N SFAL DECOMP Hold PJSM on changing annular element. R/D and UD Riser. C/O annular element. Re-install Riser. 21:30 - 00:00 2.50 BOPSU N SFAL DECOMP Continue BOP test. Annular element not holding pressure. Adjust annular closing pressure and observe no change in pressure leak-off. Continue troubleshooting problem. Total losses for tour = 145 bbls. Filling hole hourly. Lossr rate 10-12 bbls er hr. 4/25/2008 00:00 - 03:30 3.50 BOPSU N SFAL DECOMP Hold PJSM . Pull Cap off Annular Preventer and inspect. Work on inside bowl and flush out. Re-Install Seals and Components. 03:30 - 04:00 0.50 BOPSU P DECOMP R/U & test Annular w/ 3-1/2" test jt. Good Test. BOP Test complete. 04:00 - 04:30 0.50 BOPSU P DECOMP R/D test equipment and Blow down Choke and Kill lines. Begin Printed: 6/10/2008 11:11:59 AM • BP EXPLORATION Page 2 of 17 Operations Summary Report Legal Well Name: 06-22 Common Well Name: 06-22 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task ', Code' NPT 4/25/2008 04:00 - 04:30 0.50 BOPSU~ P 04:30 - 05:00 0.50 BOPSU P 05:00 - 06:00 1.00 BOPSU~P 06:00 - 07:00 1.00 PULL P 07:00 - 08:30 I 1.501 PULL I P 08:30 - 09:00 0.501 PULL P Spud Date: 9/15/1982 Start: 4/21 /2008 End: 5/12/2008 Rig Release: 5/13/2008 Rig Number: Phase ', Description of Operations DECOMP filling hole continuously. Current loss rate = 18 bbls per hr. DECOMP M/U ISA BPV Blanking Plug Retrieval tool on 1 jt 4" DP. Screw into Blanking Plug w/ 8 left hand turns. Unscrew Blanking Plug w/ 10 rt hand turns. DECOMP R/U and pressure test DSM lubricator to 500 psi. Check IA Pressure - on Vac. Pull BPV. UD DSM Lubricator and BPV. DECOMP M/U 5-3/4" RH Acme XO to Landing Joint. Engage Hanger with 10 Turns to Full Make Up. Check IA Pressure =Vac. BOLDS on Tbg Spool. P/U and Pull Hanger Free. Hanger Po ed Free at 125 000 Ibs and Pulled to Floor with 120 000 lbs. With Hanger above Floor set slips under 5-1/2" XO Pup Jt. Visually see Leak below Hanger. Fluid coming from connection at bottom of hanger with no pump pressure and just fluid column see small -1/bin stream. B/O Hanger below 5-1/2" XO Pup and UD. UD Landing Joint. DECOMP M/U Circ Head to 3-1/2" 9.2# Tbg and R/U Clrc Hose. Circ 603 bbls at -10 bpm and 2500 psi. W Ith Leak seen at tbg hanger wanted to make sure pod Circ of hole. No as and - ve small amount of crude seen in circulation. Losses -17 bph. DECOMP R/D Clrc Head and Hose. Blow Down Lines. Spot Control Line Spooler and R/U pnuematic chisel fpr cutting SS bands. 09:00 - 11:00 I 2.001 PULL I P 11:00 - 11:30 0.50 PULL P 11:30 - 19:00 7.50 PULL P 19:00 - 19:30 0.50 PULL P 19:30 - 20:00 0.50 PULL P 20:00 - 21:30 I 1.501 CLEAN I P 21:30 - 00:00 I 2.50 I CLEAN I P 4/26/2008 00:00 - 08:00 8.00 ~ CLEAN P 08:00 - 09:00 A 1.001 CLEAN I P DECOMP ~ POOH with 3-1/2", 9.2# ~-80 TDS Tbg. POOH and UD first 66 Joints with single SS Control Line. Stainless Steels Bands seen mostly every other joint. Recovered all control line and 35 SS Bands. Control Line and Tbg was in very good shape. DECOMP UD Camco Spooler DECOMP Continue to Pull and UD 3-1/2" 9.2# L-80 TDS Tbg. UD 1 SSSV, 5 GLMs, and 298 jts of 3.5" tubing. Cut jt was 10.62' in lenght, the cut was clean and flared to 3.75", Tubing in generally good condition. DECOMP R/D tubing equipment and set wear ring. DECOMP Clear and clean rig floor and cleaned up tubing handling equipment, P/U BHA components to rig floor. DECOMP M/U dress otf assembly: BHA consists of: Shoe, 3 jts of wash pipe, 3.5" dress off mill, washover junk basket, double pin sub, junk basket, casng scraper 7", bit sub, LBS, XO, 9- 4.75" drill collars. BHA length = 316.55'. DECOMP Continue to RIH from 316' to 1,900' picking up drill pipe 1x1 from the pipe shed. DECOMP Continue to RIH P/U drill pipe from pipe shed 1x1 with dress off assembly as follows. Shoe, 3 jts of wash pipe, 3.5" dress off mill, washover junk basket, double pin sub, junk basket, casng scraper 7", bit sub, LBS, XO, 9- 4.75" drill collars. BHA length = 316.55'.' DECOMP Establish Parameters ; P/U Wt = 175,000 Ibs S/O Wt = 145,000 Ibs Rot Wt = 160,000 Ibs ~ 60rpm's and 6,000 ft-Ibs free torque. Tag Tbq Stub at 9568'. Wash and Rotate over 5 times down to a total depth of 9584' -Casing Scraper to 9555'. Dress Off Tbq Stub to 9569. Wash Over Shoe had 14.9' of swallow. Able to slide over tbg stub without rotation or pumping. Printed: 6/10/2008 11:11:59 AM • • BP EXPLORATION Page 3 of 17 Operations Summary Report Legal Well Name: 06-22 Common Well Name: 06-22 Spud Date: 9/15/1982 Event Name: WORKOVER Start: 4/21/2008 End: 5/12/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 5/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours I Task Code NPT Phase Description of Operations 4/26/2008 09:00 - 10:00 1.00 CLEAN P 10:00 - 13:30 ~ 3.50 ~ CLEAN ~ P 13:30 - 14:30 ~ 1.00 ~ CLEAN ~ P 14:30 - 15:00 0.50 CLEAN P 15:00 - 16:00 1.00 EVAL P 16:00 - 17:00 1.00 EVAL P 17:00 - 19:00 ~ 2.00 ~ EVAL ~ P 19:00 - 20:30 1.50 EVAL ~ N 20:30 - 22:00 1.50 EVAL P 22:00 - 00:00 2.00 EVAL P 4/27/2008 00:00 - 03:00 3.00 EVAL P 03:00 - 04:00 1.00 EVAL P 04:00 - 05:00 1.00 EVAL P 05:00 - 06:00 1.00 DHB P 06:00 - 07:00 1.00 DHB P 07:00 - 07:30 0.50 DHB P 07:30 - 08:30 1.00 EVAL P 08:30 - 09:00 0.50 EVAL P 09:00 - 12:30 3.50 EVAL P 12:30 - 13:30 I 1.00 I EVAL I P DECOMP Pump 20 bbl High Visc Sweep. Chase out of the hole at 10 bpm and 2850 psi pump pressure. At bottoms up saw sand, a little crude and small amount of as at surface. Sweep brought back a minimal amount of fine dark colored sand with it. Fluid Loss-10 bph while circulating. DECOMP Monitor Hole and Pump Dry job. Blow Down Top Drive. POOH and Stand Back DP. Did not see top of 7" liner while RIH attem t to locate on trip out of hole. Small small tag at -2147'. DECOMP UD 4-3/4" DC's and Dress Off BHA. Good wear marks on inside of dress off shoe and some carbide broken off rotary shoe. Boot baskets contain a very small amount of metal cuttings. DECOMP Clean and Clear off Rig Floor of subs. DECOMP Drain Stack and N/D Flow Riser. DECOMP Spot E-line unit, Load SLB tools into pipe shed and bring to rig floor. DECOMP R/U SLB E-Line equipment Lubricator extension, pump in sub, Wire Line BOPs, Lubricator, with grease tubes. DECOMP Test Lubricator and full Pressure Control Equipment to 1,500 psi. Test failed due to bad O-Ring on the lubricator. Break down the lubricator and logging tools and replace O-Ring. Make up lubricator and logging tools and re-test to 1,500 psi. good test DECOMP RIH with USIT tools SLB hit fluid at 250' well took 20 bbls to fill. DECOMP Continue to run USIT Logs in Cement and Corroision Mode. DECOMP R/D SLB E-line full pressure control equipment. DECOMP N/D Shooting Flange and N/U Flow Riser. DECOMP M/U 7" RBP. While Standing by waiting on USIT log interpretations from SLB engineer. DECOMP Waiting on interpretation of USIT logs. DECOMP UD RBP and Running Tool. DECOMP Waiting on 7" RTTS from Halliburton. DECOMP M/U 7" RTTS and Running tool. DECOMP RIH to to 8,470' , P/U Single of DP and Obtain Parameters: up weight=150,000#, down weight=130,000#, put two turns to the right and set down 15,000# to set element at 8.495'. DECOMP R/U to test Casing, pressure tested lines to 3,500 psi bleed off pressure, lined up to test casing, pressured up to 3,500 psi. 13:30 - 14:00 0.50 EVAL P DECOMP UD single of DP and rack back one stand, M/U to Top Drive at 8,360' and circulate a DP volume at 4 bpm with 360 psi. 14:00 - 15:00 1.00 EVAL P DECOMP Rotate drill string two times to right to set RTTS, set down 15,000# to confirm set. center of the element at 8,367'. R/U Test equipment and test casing to 3,500 psi. Test failed 15:00 - 16:30 ~ 1.50 ~ EVAL ~ P ~ ~ DECOMP R/U test equipment and attempt to test casing. 16:30 - 17:00 0.50 ~ EVAL ~ P ~ ~ DECOMP ~ Release RTTS and P/U 10 joints of drill pipe from pipe shed Printed: 6/10/2008 11:11:59 AM • • BP EXPLORATION Page 4 of 17 Operations Summary Report Legal Well Name: 0 6-22 Common Well Name: 0 6-22 Spud Date: 9/15/1982 Event Name: WORKO VER Start : 4/21/2008 End: 5/12/2008 Contractor Name: DOYON DRILLIN G INC . Rig Release: 5/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To i Hours Task Code NPT Phase Description of Operations 4/27/2008 16:30 - 17:00 0.50 EVAL P DECOMP and set the RTTS element at 9,538', Approx 30' above tubing stub. 17:00 - 18:00 1.00 EVAL P DECOMP R/U test a ui ment and test casin .Test failed ressure dro ed from 3 500 si to 3 000 si in 30 minutes. 18:00 - 18:30 0.50 EVAL P DECOMP CBU at at 6 bpm with 640 psi. 18:30 - 22:00 3.50 EVAL P DECOMP POOH with RTTS from 9 500 si to surface. 22:00 - 22:30 0.50 EVAL P DECOMP UD RTTS and P/U RBP. RTTS Rubber Element was in good condition when out of the hole. 22:30 - 00:00 1.50 EVAL P DECOMP RIH wit RBP to 1,473'. 4/28/2008 00:00 - 03:00 3.00 DHB P DECOMP Continue to RIH with RBP from 1,473' to 9,544'. Up weight= 170,000#, down weight=140,000#, P/U one joint DP. 03:00 - 03:30 0.50 DHB P DECOMP Set RBP with 15 000# down wt. Center of element at 9 54 ' Top of RBP at 9,544', UD 1 joint of drill pipe, rack back 1 stand dp. Complete confidence check for RBP. 03:30 - 04:30 1.00 EVAL P DECOMP Slip and Cut drilling line. 04:30 - 07:00 2.50 EVAL P DECOMP POOH with RBP Running tool. 07:00 - 07:30 0.50 EVAL P DECOMP B/O and UD RBP Running tool, P/U M/U RTTS with mule shoe. 07:30 - 11:30 4.00 EVAL P DECOMP RIH with RTTS to 9,127'. Up weight=162,000# down weight=136,000#. 11:30 - 12:00 0.50 EVAL P DECOMP M/U Top Drive and pump at 3 bpm with 300 psi, B/D T/D 12:00 - 12:30 0.50 EVAL P DECOMP RIH to 9,127', Obtain parameters up weight=162,000# down weight=132,000#, rotate drill string 2x to the right and set the center of the RTTS elements at 9 12_7'. Pressure test surface lines to 3,500 psi good test, R/U test epuiament and test casina 0 5 i f r .Tested from the RTTS at 9.127' to RBP at 9.548'. 12:30 - 14:00 1.50 EVAL P DECOMP Rack back 2 stands of DP, set center of RTTS element at 8,941' and testin to a de th of 9 548' at RBP. To f , top at 9 087'. Tested to 3 500 psi for 30 charted minutes. test... failed pressure dro ed from 3 500 si to 1 800 si in 30 minut 14:00 - 16:00 2.00 EVAL P DECOMP Safety Stand Down with Doyon Safety Rep Bob Mick, Co Man, Doyon Toolpusher, and Rig Crews. Focus of Stand Down Staying in the Moment) and doing adaquate taks hazard assements, followed by Hazard hunt on the rig, camp area and shop. 16:00 - 18:30 2.50 EVAL P DECOMP Bleed off Pressure from casing to O psi. Wait on decision from anchorage from results of RTTS test results, Clean rig and service top drive and iron rough neck. 18:30 - 21:00 2.50 EVAL P DECOMP POOH with RTTS from 8,941' to surface._ 21:00 - 21:30 0.50 EVAL P DECOMP UD RTTS and Running tool, P/U RBP running tool. RTTS in Good Shape. 21:30 - 00:00 2.50 EVAL P DECOMP RIH with RBP Retieval Tool to 6,214' 4/29/2008 00:00 - 00:30 0.50 EVAL P DECOMP Continue to RIH with RBP running tool from 6,214' to 9,534', up weight=170,000#, down weight=140,000#. 00:30 - 01:30 1.00 DHB P DECOMP P/U 1 joint of DP, Latch and release RBP. , 01:30 - 02:30 1.00 EVAL P DECOMP CBU at 6 BPM with 800 psi. While having a Safety Stand Down, Topics discussed Recent trend of incidents, Increased focus on Staying In The Moment, the use of Stop Program, Using our Lessons Learn and LOTO procedure books Daily, Increasing the usage of Task Hazard Assessment Cards, and getting back to the Basics of Safety. Printed: 6/10/2008 11:11:59 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: 06-22 Page 5 of 17 Common Well Name: 06-22 Spud Date: 9/15/1982 Event Name: WORKOVER Start: 4/21/2008 End: 5/12/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 5/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours 'i Task Code NPT Phase Description of Operations 4/29/2008 02:30 - 03:00 0.50 EVAL P DECOMP POOH from 9,534' to 7,610'. 03:00 - 03:30 0.50 DHB P DECOMP Set RBP COE at 7,610' with 15,000# down weight to confi 03:30 - 06:30 I 3.001 FISH I P 06:30 - 09:00 2.50 FISH P 09:00 - 10:00 1.00 FISH P 10:00 - 12:30 2.50 FISH P 12:30 - 14:00 1.50 FISH P 14:00 - 15:30 I 1.501 FISH I P 15:30 - 21:00 I 5.501 FISH I P 21:00 - 21:30 0.50 FISH P 21:30 - 23:00 1.50 FISH P 23:00 - 00:00 ( 1.001 FISH I P 4/30/2008 100:00 - 00:30 I 0.501 FISH I P 00:30 - 12:00 ~ 11.50 ~ FISH ~ P 12:00 - 14:00 I 2.001 FISH I P DECOMP Dump 1,200-Ibs of 20/40 river sand on top of RBP. Circulate ri pipe volume, 1-BPM at 60-psi. B/D Top Drive and RIH to DECOMP POH and S/B DP and DCs. B/O and UD RBP running tool. DECOMP PJSM. M/U Baker Multi-String Cutter BHA. DECOMP RIH with Multi-String Cutter BHA to 7,415'. DECOMP M/Uto TD and obtain parameters: P/U wt 136K, S/O wt 125K. Continue to RIH to look for collars, varying pump pressure from 280-psi to 850-psi, but, as expected, cannot find indication of NSCC collars. Calibrate depth to log and decide to UD single and P/U 10' to position Cutter at 7,500' (from D-16 Rotary Table). Start cutting operations with 70-RPM, rot wt 130K, 3K-Ib-ft torque, pump rate 4-BPM at 880-psi. Rotate for 10-minutes and pressure drops to 280-psi. Verify cut by P/U to 5K overpull and pressure increases to 2100-psi. S/O to down-weight and pressure drops to 280-psi. DECOMP Mix and pump 20-Bbl Hi-Vis sweep, 8-BPM, 1100 to 1200-psi. The loss rate while um in was 122-BPH. Stop pumping when sweep returned to surface without any signs of gas or crude during the circulation. Get static loss rate of 26-BPH. Monitor well and B/D Top Drive. DECOMP POH and S/B 4-stands of DP in Derrick to make a total of 24-stands of 4" DP in Derrick. POH and UD all remaining 4" DP, to be replaced with 5" DP as required for planned operations associated with the RIH of the new 7" Casing Tieback Liner. DECOMP UD Casing Cutter BHA. DECOMP M/U Packer millin Assembl ,BHA consists of Packer mill, 3 Junk baskets, bit sub, bumper sub, oil jar, bumper jar, XO, 12 drill collars, XO. BHA Ienght=410.33'. DECOMP Continue to RIH with 4" Ht-38 drill pipe to 2,100'. Obtain parameters: up weight=90,000#, down weight=90,000#, rotating weigtht=90,000#, 80 rpm, 2,500 ft-Ibs torque, 7 bpm with 300 psi. Tagged liner at 2,143'. DECOMP Obtain parameters: up weight=90,000#, down weight=90,000#, rotating weigtht=90,000#, 80 rpm, 2,500 ft-Ibs torque, 7 bpm with 300 psi. Tagged liner at 2,143'. DECOMP Millin Liner at 2,143' to 2 149' with 8-12,000 WOB, 80-100 RPM,3-8,000 ft-Ibs of torque. Pumped 3 sweeps with good recovery of metal shavings, 25 Ibs of metal recovered over shakers and magnets. Made 6.5' within the first 7-hours of millin and a total of 67-Ibs of metal shavings were recovered off the ditch magnets by 1200-hours. DECOMP Crew change and PJSM to discuss the possibility of trapped pas being released when the milling operation oroareccPC_- through the sealing element. Progress was very slow until 1300-hours when penetration rate picked up to about 2-3" per minute. At -1330-hours noticed a 3% pit gain at the same tim that the Pit Watcher called on the Gaitronics to inform the, Printed: 6/10/2008 11:11:59 AM • • BP EXPLORATION Page 6 of 17 Operations Summary Report Legal Well Name: 06-22 Common Well Name: 06-22 Spud Date: 9/15/1982 Event Name: WORKOVER Start: 4/21/2008 End: 5/12/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 5/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours II Task ,Code' NPT ! Phase II Description of Operations __ _ -_ 4/30/2008 12:00 - 14:00 2.00 FISH P DECOMP shakers. Removed the flexible hole cover and fluid quickly flowed out onto the rig floor. Driller S/I the Hydrill and instructed that the HCR valve be closed. SIDP was 30-psi and SICP was 60-psi. About 40-gallons of brine was captured in the rig floor sumps. AOGCC, Wells RWO Supt, ADW HSE, FS3 Operations Team Lead, ADW Engineer, and SRT Spill Tech were al^ I notified. Cummulative progress was about 10' through the Liner Hanger assembly which would put the mill right in the sealing element. 14:00 - 16:30 2.50 FISH P DECOMP Attempted to pump through the TopDrive, but DP appeared to be plugged. Pumped through Kill line to fill the hole and it took_ 28.5-Bbls, with about 100-psi on the pump. Pit Watcher said we had gained about 30-Bbls from the flowback prior to shutting in the well. S/D pump and let pressure bleed off. Start pump and pump in about 30-Bbls when pressure increased to 80-psi. Bleed off to 0-psi in less than 5-minutes. Do this one more time. Attempt to pump down DP through TopDrive and DP is clear. Circulate down DP and out through Gas Buster and get crude back after 40-Bbls pumped, continue pumping and get clean 9.7-9.8-ppg brine after 165-Bbls pumped at 3-1/2-BPM and 80-psi. Called the AOGCC to discuss the timing for retesting the Hydrill and the HCR Choke Valve. Lou Ma 1st. 16:30 - 18:00 1.50 FISH P DECOMP S/I and monitor well for 30-minutes and well is dead. Open up 18:00 - 21:30 3.50 FISH P DECOMP RIH with strin to veri to de th of fish at 2 153' fora 10' ain Burin millin o erations. Continue with millin o erations. No additional foota a made. 21:30 - 22:00 0.50 FISH P DECOMP Pump 20-Bbl Hi-vis sweep and circ it out of wellbore at 8.5-BPM with 450-psi. 22:00 - 00:00 2.00 FISH P DECOMP POOH with packer milling assembly and UD 4" HT-38 drill pipe. 5/1/2008 00:00 - 01:00 1.00 FISH P DECOMP Continue to POOH and UD Drill pipe from 1,400'to 411'. 01:00 - 01:30 0.50 FISH P DECOMP Stand back 6-1/4" Drill Collars and B/O UD Milling BHA. 01:30 - 02:00 0.50 FISH P DECOMP Clear and Clean Rig Floor, Cleaned out Junk Baskets, 1 gal of metal debris in Baskets. 02:00 - 04:30 2.50 FISH P DECOMP M/U Stack washer, Pump out stack, Driller observed a piece of casin la in dia onall in the B P k. Rigged up a sheet mete) plate clamp and retrieved a piece of metal 6' by 8"wide and concave in sha a that a e r t from th t II .Function metal on top of the blilnd rams, fished it out of the stack with th m tool. Then we used the stack washer to clean out any metal shavings in the ram bodies. Cleaned out the Drip Pan . 04:30 - 05:30 1.00 FISH P DECOMP Change out the 4" HT-38 Saver Sub for 4.5" IF Saver Sub, Change Elevators and Slips. 05:30 - 06:30 1.00 FISH P DECOMP P/U M/U S ear Assembl BHA Consists of:Bull Nose, 7" Pack Off, Itco Spear, Spear Extension, 8-3/8" OD Stop Sub, XO, Bumper Sub, Oil Jar,XO, 12-6-1/4" Drill Collars XO, Intensifier. BHA Length=420.39'. Currently losing 12-BPH using constant Printed: 6/10/2008 11:11:59 AM • • BP EXPLORATION Page 7 of 17 Operations Summary Report Legal Well Name: 06-22 Common Well Name: 06-22 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date I~, From - To ~' Hours Task Code ~' NPT 5/1/2008 05:30 - 06:30 1.00 FISH P 06:30 - 10:00 3.50 FISH P 10:00 - 12:00 2.00 FISH P 12:00 - 12:30 0.50 FISH P Spud Date: 9/15/1982 Start: 4/21 /2008 End: 5/12/2008 Rig Release: 5/13/2008 Rig Number: Phase Description of Operations DECOMP hole fill. Change-out Saver Sub to 4-1/2" IF. DECOMP RIH Spear BHA on 4-stands of 6-1/4" DCs from Derrick and 5" DP P/U from Pipe Shed 1 x 1. DECOMP Get parameters: 102K do wt, 98K up wt. Work spear into fish at 2153' and engage spear. P/U to 25K over, then slack off to 10K over. Start circulating and bring pumps up to 10-BPM, 1200-psi, but calculated fluid loss rate is 220-BPH. Reduce to 5-BPM at 600-psi and lose 147-Bbls while circulating for a 138- b 7 x 9-5 8' , 47-Ib annular volume. Do not see an as or crude in returns. Stop pumping, release spear, and P/U out of fish. Circulate 135 Bbls at 6-BPM and 110-psi and lose 1-Bbl, with no gas or crude in the returns. DECOMP POH and S/B 2-stands of 5" DP in Derrick. Blowdown Top Drive. P/U RTTS and Storm Valve and RIH and set at 98' 12:30 - 13:30 1.00 FISH P DECOMP R/U to PT and PT RTTS and Storm Valve to 3500-psi for 10 13:30 - 14:00 0.50 FISH P DECOMP P/U landing joint from Pipe Shed and M/U to Wear Ring Run/Pull tool and RIH to pull Wear Ring. 14:00 - 16:00 2.00 BOPSU P DECOMP Discuss the use of FMC Test Plug with ADW Engineer and decide that another type of barrier needs to be placed and tested in the Tubing Spool. Call FMC and ask for a Tubing Hanger, rebuilt BPV, and Blanking Plug that can be placed in the Tubing Spool. 16:00 - 16:30 0.50 BOPSU P DECOMP M/U landing joint to Blanking Plug on Tubing Hanger, RIH and set in Tubing Spool. RILDS. 16:30 - 17:30 1.00 BOPSU P DECOMP PT Tubin Han er from below to 1000- si for 10 charted minutes for ood test. Test from above to 3500- si for 10 rharted minutes for good test to ensure that the Blanking Plua. 17:30 - 19:00 I 1.501 BOPSUR P 19:00 - 19:30 0.50 BOPSUF~ P 19:30 - 00:00 4.50 BOPSU P 5/2/2008 100:00 - 02:30 I 2.501 BOPSUR P 02:30 - 03:00 0.50 BOPSUFjP 03:00 - 04:00 1.00 DHB P 04:00 - 05:00 1.00 DHB P 05:00 - 06:30 1.50 FISH P BPV, and Tubing Hanger are not leaking. DECOMP PJSM. Suck out BOP stack and change-out Lower Rams from 3-1/2" x 6" VBRs to 4-1/2" x 7" VBRs., DECOMP Rig up BOP test equipment. DECOMP Test BOPE 250 psi low test and 3,500 psi high test.All Tests e or carted minutes witnessed by BP WSL and Doyon Toolpusher AOGCC Representitive Lou Grilmaldi waived witness of BOP testing at 13:00 hrs. DECOMP Continue to test BOPE to 250 low pressure and 3,500 psi high pressure for 5 charted minutes. DECOMP R/D Test equipment, blow down surface lines. DECOMP Vacuum out BOP stack, P/U Blanking plug retrieval tool and engage false tubing hanger with BPV set in place. BOLDS pull tubing hanger to rig floor, B/O and L/D same DECOMP P/U 1-stand of drill pipe and RIH to retrieve RTTS/Storm Valve. Stop above RTTS/Storm Valve, M/U TIW Valve to string. Hold PJSM with crew, Toolpusher, Baker fisherman, and WSL. Engage RTTS, open TIW Valve, Close Annular Preventer and slowly strip up through Annular Preventer -6". Check for pressures and see no pressure. Open Annular Preventer and fill hole. Took 20-Bbls. POH and break-out and L/D RTTS/Storm Valve. Blow down choke and kill lines DECOMP Get parameters: P/U wt 102K, Dn wt 98K. RIH and enoaae spear into 7" liner top at 2153', set 5K down on fish, P/U slowly Printed: 6/10/2008 11:11:59 AM • • BP EXPLORATION Page 8 of 17 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 06-22 06-22 WORKOVER DOYON DRILLING INC. DOYON 16 Date 'From - To 'Hours Task ,Code ' NPT 5/2/2008 105:00 - 06:30 06:30 - 08:00 1.50 FISH P 1.50 FISH P 0.50 FISH P 08:00 - 08:30 08:30 - 09:30 09:30 - 15:00 15:00 - 16:30 16:30 - 17:00 17:00 - 17:30 17:30 - 18:00 18:00 - 18:30 18:30 - 22:30 22:30 - 00:00 5/3/2008 00:00 - 00:30 00:30 - 01:30 01:30 - 03:30 03:30 - 04:30 04:30 - 05:00 ~~ 05:00 - 09:30 09:30 - 10:30 Spud Date: 9/15/1982 Start: 4/21 /2008 End: 5/12/2008 Rig Release: 5/13/2008 Rig Number: Phase Description of Operations DECOMP to 150K to bleed off jars. P/U to 250K and start pump, bring up to 6-BPM at 400-psi. P/U to 325K, S/O to 200K, P/U to 350K and fish breaks fre .Continue POH with 235K. Stop to CBU, but et no returns with 6-BPM at 650- si. Continue POH and get returns as soon as start POH. Pump out one stand. S/B in Derrick and Slowdown the Top Drive. DECOMP POOH and S/B 5" DP in Derrick. Break out and L/D Intensifiers. Continue POH and S/B 4-stands of 6-1/4" DCs in Derrick. DECOMP PJSM. Release Itco Spear from fish. Breakout and L/D the 7;' liner top hanger and L/D the Itco Spear using tuaaer line. h short assemblies. 1.00 FISH P DECOMP R/U 7" handling equipment, changeout elevators. 5.50 FISH P DECOMP POOH and L/D 7" casin .Find corrosion damage to collars from joint #3 thru joint #30, but the casing did not appear to be corroded. 46-joints L/D at 1135-hours. 100-joints ~ 1330-hours. Joint #135 L/D at 1450-hours followed by the 22.78' long cut joint UD at 1500-hours. The cut was clean and the same OD as the 7" casing. A centralizer was found on the first full joint below the Liner Hanger Assembly. 1.50 FISH P DECOMP Clear and clean Rig Floor. Clean Power Tongs and clean and changeout elevators. Wash down Rig Floor. Break out and L/D oil jars 0.50 CLEAN P DECOMP M/U Watermelon Mill BHA: 6-3/8" Bullnose, 8-1/2" OD Watermelon Mill, Bumper Sub, and 12-ea 6-1/4" DCs. 0.50 CLEAN P DECOMP RIH with BHA on DP from Derrick. 0.50 CLEAN P DECOMP RIH with BHA on DP picked up from Pipe Shed. 0.50 CLEAN P DECOMP M/U T/D at 2 599' Continue to RIH to ed CSG atch t 2 609' P/U off patch and obtain parameters: 4.00 CLEAN P DECOMP Be an millin CSG atch at 2 609', up weight=110,000#, down weight=112,000#, rotating weight=110,000#, free torque=3,000 ft-Ibs, on bottom torque=3-10,000 ft-Ibs, pump rate 11 bpm with 380 psi, pumping 20 bbl hi-vis sweeps as needed, sweeps recovered cement and fine metal flakes, continued to mill to a de th of 2,649' .Back reamed through casing patch area multiple times until no torque or drag observed. 1.50 CLEAN P DECOMP Back reaming and reciprocating casing patch area between 2,609' and 2,649', pump Hi-Vis sweep around. 0.50 CLEAN P DECOMP Continue to circulate out Hi-Vis sweeps at 9 bpm with 240 psi. 1.00 CLEAN P DECOMP Slip and Cut 122' of Drilliing line, inspect brake linkage, and dyna-matic. 2.00 CLEAN P DECOMP POOH from 2,550' standing back drill pipe. 1.00 CLEAN P DECOMP UD watermelon mill BHA and P/U RCJB Assembly. 0.50 CLEAN P DECOMP M/U BOP Stack Washer and Clean out BOP Stack of metal cutting from milling operations. 4.50 CLEAN P DECOMP RIH with RCJB BHA with 24 stands of drill pipe from derrick. Picking up the remainder of the drill pipe from the Pipe Shed 1x1 to a depth of 5,100' to stop and CBU. Appear to be pushing something downhole from below the bottom setting depth of the original Homco Casing Patch of 2649'. Setting down as much as 20,000-Ibs. 1.00 CLEAN P DECOMP Circulate Bottoms Up: 80-SPM (6.8-BPM), 1310-psi. See no gas or crude in the returns, lose 15-Bbls during the CBU of Printed: 6/10/2008 11:11:59 AM C7 • BP EXPLORATION Page 9 of 17 Operations Summary Report Legal Well Name: 06-22 Common Well Name: 06-22 Spud Date: 9/15/1982 Event Name: WORKOVER Start: 4/21/2008 End: 5/12/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 5/13/2008 Rig Name: DOYON 16 Rig Number: Date ~I From - To Hours Task Code NPT Phase Description of Operations 5/3/2008 09:30 - 10:30 1.00 CLEAN P DECOMP 250-Bbls. 10:30 - 13:00 2.50 CLEAN P DECOMP Resume RIH and continue to push something ahead with -5,000-Ibs set down on it. Joint #180 RIH at 1150-hours. 13:00 - 14:00 1.00 CLEAN P DECOMP P/U 5" DP joint #224 and get parameters: P/U wt 210K, S/O wt 163K. P/U joint #225 and M/U to Top Drive. Start rotating at 50-RPM, free rotating torque at 9K-Ib-ft; pump rate 100-SPM (-9-BPM) at 1200-psi. Circulate DP volume (132-Bbls) to clear DP prior to dropping ball for RCJB. Lose 6-Bbls (24-BPH rate) during this circulation. Drop ball and chase to RCJB with 7.5-BPM at 800-psi. 14:00 - 15:00 1.00 CLEAN P DECOMP Slowly wash down at 50-RPM and 8K free torque and stack-out soft at 7,492'. Increase RPM to 80-RPM and 10-15K-Ib-ft torque. Slowly RIH and torque up with 20K-Ibs WOB. P/U until Top Drive starts rotating and slowly lower back down, gaining ~1' enetration until for uing out. Perfrom this Yo-Yo 12-14 times and make it to 7498' with the sawtooth mill. The 7" casing had been cut at 7500' MD and based on the torque-up pattern as well as the lack of progress for the last 5 "Yo-Yos", decided to P/U to circulate a Hi-Vis sweep. Lost 15-6b1s during this operation. Called ADW engineer to confirm decision. 15:00 - 16:30 1.50 CLEAN P DECOMP Circulate Hi-Vis sweep, 7-BPM, 2500-psi. S/D pumps and get static loss rate of 8.4-BPH. 16:30 - 19:30 3.00 CLEAN P DECOMP PJSM. B/O and Blow Down Top Drive. POH and S/B DP in Derrick. 19:30 - 21:00 1.50 CLEAN P DECOMP UD 6-6-1/4" drill collars, and UD RCJB BHA, Recovered several large pieces of metal completely filling junk basket. Could see clear indication of 7" liner stub on bottom shoe of 21:00 - 21:30 0.50 CLEAN P DECOMP Clear and clean rig floor and UD BHA Components, P/U Next BHA equipment. 21:30 - 22:30 1.00 CLEAN P DECOMP M/U Dress Off assembl ,BHA consists of:8-3/8" dress off shoe, wash pipe ext, inner dress off mill, drive sub, xo, bumper sub, oil jar, xo, 6- 6-1/4" drill collars, xo, double pin sub, junk basket, 9-5/8" casing scraper, bit sub. BHA length=230.10' 22:30 - 00:00 1.50 CLEAN P DECOMP Continue to RIH with dress off assembly from 230' to 3,072'. 5/4/2008 00:00 - 02:30 2.50 CLEAN P DECOMP RIH from 3,072' to 7,501' filled drill pipe at 3,548' and 6,871'. 02:30 - 03:00 0.50 CLEAN P DECOMP M/U top drive and obtain parameters: up weight=207,000#, down weight=157,000#, rotating weight=177,000#, 40 rpm, with 8,000 ft-Ibs torque. 03:00 - 05:00 2.00 CLEAN P DECOMP Be in millin at 7,500' found liner to at 7 507'. Dressed off c in stub, Picked up slid down over casing stub 3x with no rotation or pumps. Leave 7" stub top at 7,508' after swallowing. to 7513'. 05:00 - 06:00 1.00 CLEAN P DECOMP Circulate Hi-vis sweep surface to surface. 06:00 - 12:00 6.00 CLEAN P DECOMP POH and UD 5" DP to leave 2,400' available to S/B in the Derrick. 150-joints UD at 1030-hours. 12:00 - 13:00 1.00 CLEAN P DECOMP B/O and UD 6-ea 6-1/4" DCs. B/O and UD Dress-off BHA. Find 2.5' of wadded-up metal inside the wash pipe that had been forced down inside the stub. Had perfect impression of a smooth top of stub 5' up inside the washpipe. 13:00 - 13:30 0.50 CLEAN P DECOMP Clear and clean Rig Floor. 13:30 - 14:00 0.50 CASE P TIEB1 PJSM to RIH with RTTS Packer to test 9-5/8" Casina from Printed: 6/10/2008 11:11:59 AM • BP EXPLORATION Page 10 of 17 Operations Summary Report Legal Well Name: 06-22 Common Well Name: 06-22 Spud Date: 9/15/1982 Event Name: WORKOVER Start: 4/21/2008 End: 5/12/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 5/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours ~ Task Code NPT I Phase Description of Operations - -_ __ 5/4/2008 14:00 - 15:00 1.00 CASE P TIEB1 RIH with RTTS and set RTTS at 2,470' or 26-stands RIH. 15:00 - 16:00 1.00 CASE P TIEB1 Pressure test 9-5/8" casin to 3500- i - recorded on chart for solid test. 16:00 - 17:30 1.50 CASE P TIEB1 POH and S/B DP in Derrick. B/O and UD RTTS. 17:30 - 19:00 1.50 CASE P TIE61 R/U to RIH with 7", 26#, L-80, BTC-M Scab Liner. 19:00 - 21:00 2.00 CASE P TIEB1 PJSM P/U M/U 7",26#, L-80, BTC-M Liner Cement track, Baker CSG Patch, Ported Sub, 2- Float Collars, Landing jt. 21:00 - 00:00 3.00 CASE P TIEB1 PJSM Continue to P/U M/U 7", 26#, L-80, BTC-M Liner from 125' to 2,155'. Filling ever 5 jts of CSG with centralizer everyother joint. 5/5/2008 00:00 - 04:00 4.00 CASE TIE61 Continue to P/U and run 7", 26#, L-80, BTC-M Liner, using double stack casing tong, making up pipe to diamond on pin end. 04:00 - 04:30 0.50 CASE TIE61 R/D 7"CSG equipment, Change out Elevators. R/U to Run 5"drill pipe from derrick. 04:30 - 05:30 1.00 CASE TIEB1 Circulate Liner Volume (198-Bbls) at 7-BPM, 560-psi. 05:30 - 08:00 2.50 CASE TIE61 RIH with 7" Scab Liner on 5" drill pipe from derrick. 08:00 - 09:30 1.50 CASE TIEB1 M/U Baker Cementing assembly and UD in the Pipe Shed. P/U one joint of DP with 5' DP pup joint on bottom and M/U to DP and get parameters: P/U wt 200K, S/O wt 160K. Slowly RIH and taq stub at 7 508' stoo RIH and Bowen Patch rirt-lid huide dro s over stub. Slowly RIH and stack out -2-1/2' in. Slack off to 130K, P/U to 230K, S/O to 210K. Bowen Casing Patch Overshot is latched onto the Stu '. Set DP in slips. P/U Cementing Head assembly from Pipe Shed and M/U to drillpipe. P/U String and pull slips, keeping 210K on the elevators. 09:30 - 10:00 0.50 CASE TIE61 PJSM with 3-CH2MHill truck drivers, 4-Schlumberger personnel, 3-Baker personnel, rig crew, Toolpusher, and WSL to discuss all aspects of the cement job. Each person was asked for and gave their Safety input. 10:00 - 11:00 1.00 CASE TIEB1 Pressure test lines and circulate 50-Bbls of 9.8-ppg, took 30-Bbls to fill before returns came to surface. Switch over to Schlumberger to pump 5-Bbls of freshwater to test their lines to 4500-psi. Pump 161-Bbls (includes 30-Bbls excessl of 15.8- Class G ce nt avg 5-BPM at avg 840-psi. Schlumberger switch over to pump freshwater, drop pump-down plug and chase it with 5-Bbls of freshwater. Switch over to Rig Pumps to displace cement. Taking all returns to Slop Tank. 11:00 - 11:45 0.75 CASE TIEBi Displace cement out of 7" casing and into 7" x 9-5/8" annulus with 9.8-ppg brine from Pits, 6-1/2-BPM, 300-psi to 1900-psi. Don't see pump-down plug bump the Wiper Plug but see pressure begin to increase to 1900-psi with 220-Bbls pumped. Slow rate to 2-BPM within 5-Bbls of Landing Collar and see the plug bump at 226-Bbls pumped. Cement In Place at 11~~-Tiours. finer anger set at -3800-psi, continue to pressure up to 4200- si to set the ZXP Liner To Packer 11:45 - 12:15 0.50 CASE TIE61 Pressure up to 4200-psi to set Baker ZXP Liner Top Packer. Bleed pressure to 1000-psi and rotate to the right for 20-turns. P/U and increase pump rate to 10-BPM to continue to circulate out the cement returns (verified with ADW Engineer). See cement in return ft (42-Bbls) pumped. Returns Printed: 6/10/2008 11:11:59 AM n • BP EXPLORATION Page 11 of 17 Operations Summary Report Legal Well Name: 06-22 Common Well Name: 06-22 Spud Date: 9/15/1982 Event Name: WORKOVER Start: 4/21/2008 End: 5/12/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 5/13/2008 Rig Name: DOYON 16 Rig Number: Date j From - To Hours Task Code NPT Phase Description of Operations i 5/5/2008 11:45 - 12:15 0.50 CASE TIEB1 clean up after additional 46-Bbls pumped. 12:15 - 12:30 0.25 CASE TIEB1 Check for flow. Fluid in stack at top of drilling riser--not moving anywhere; nothing coming out of IA. Floats are holding. Great cement job. 12:30 - 13:30 1.00 CASE TIEB1 PJSM. POH and UD 2-singles and 5' DP pup; B/O and UD Baker Cementing Head assembly. 13:30 - 14:30 1.00 CASE TIEB1 POH and S/B DP in Derrick. 14:30 - 15:30 1.00 CASE TIEBi B/O and UD Liner Han er Runnin Tool. P/U Baker Cementing Head assembly, B/O top pup joint and UD assembly and pup through Pipe Shed. 15:30 - 17:00 1.50 CASE TIE61 P/U landing joint and M/U to wear ring run/pull tool, BOLDS, and pull wear ring. Flush out stack and kill line. Install wear ring and RILDS. 17:00 - 17:30 0.50 CASE TIEB1 WOC. UCA compressive strength at 500-psi at 1710-hours. Clean out cementing valves on IA. 17:30 - 18:30 1.00 CASE TIEB1 Pressure test Casin to 3500- si for 30 charted in solid test. UCA compressive strength at 1000-psi at 1810-hours. 18:30 - 19:30 1.00 CASE TIEB1 Load 9-ea, 4-3/4" DCs in Pipe Shed to M/U the 7" Shoe Track cleanout assembly. Gather BHA from outside, haul to rig floor and steam off. 19:30 - 20:30 1.00 CASE TIEB1 M/U Clean-out BHA: 6" Mill Tooth Bit,2-ea Boot Baskets, Bit Sub, 3-ea 4-3/4" DCs, String Mill, 6-ea 4-3/4" DCs. 20:30 - 21:30 1.00 CASE TIEB1 RIH with drill out assembly from 296' to 2,190'. 21:30 - 22:00 0.50 CASE TIEB1 P/U RTTS and set 95' below rotary table and test to 1,000 psi from above for 10 minutes. 22:00 - 22:30 0.50 WHSUR TIEB1 Pull Wear Ring. 22:30 - 00:00 1.50 WHSUR TIEB1 PJSM M/U pack-off pulling tool and pull pack off. 5/6/2008 00:00 - 01:00 1.00 WHSUR P TIEB1 Dress lock down screws and break loose, back out and re-check all lock downs, pull 9-5/8" pack off, pull loose at 60,000# up weight. 01:00 - 02:30 1.50 WHSUR P TIE61 PJSM, Nipple down BOPE and tubing spool, removed secondary IA Valve from spool. 02:30 - 03:30 1.00 WHSUR P TIEB1 R/U and Install new 9-5/8" pack off_ 03:30 - 05:30 2.00 WHSUR P TIEB1 Install new tubing spool and torque bolts to spec, Test neck seal to 5,000 psi and hold test for 30 minutes. 05:30 - 07:30 2.00 WHSUR P TIEB1 N/U BOPE, and flow line. Chan a-out 4-1/2" x 7" VBRs to 3-1/2" x 6" VBRs. 07:30 - 08:30 1.00 WHSUR P TiEB1 Wait on DSM to install VR plug in tubing head in order to remove Rig-side IA valve. 08:30 - 09:00 0.50 WHSUR P TIEBi PJSM with DSM personnel and Rig Crew on installing VR plug and removing the Rig-side IA valve. 09:00 - 16:00 7.00 BOPSU P TIE61 Pressure test the BOP stack body, 3-1/2" and 5" Test Joints, and 4"Dart~and va ves, -psi low and 3500-psi high. Troubleshoot system and also function rams while increasing Koomey pressure. RILDS to compress seal in Test Plug. Get good tests on all equipment. 16:00 - 17:00 1.00 BOPSU P TIEBi P/U landing joint and pull test plug. P/U 9" wear ring and install in tubing head. 17:00 - 17:30 0.50 BOPSU P TIEB1 P/U HES running tool for RTTS. RIH to and engage RTTS at 95'. Release RTTS and POOH. UD HES RTTS. ,.~ _._w__ 17:30 - 18:30 1.00 CASE P TIE61 #8 standing back 20 stands of 5" drill pipe in POOH with BHA derrick. UD 18 joints of 5" drill pipe 1 x 1 in pipe shed. Printed: 6/10/2008 11:11:59 AM ~ • BP EXPLORATION Page 12 of 17 Operations Summary Report Legal Well Name: 0 6-22 Common W ell Name: 0 6-22 Spud Date: 9/15/1982 Event Nam e: WORKO VER Start : 4/21/2008 End: 5/12/2008 Contractor Name: DOYON DRILLIN G INC . Rig Release: 5/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours ' Task Code ~ NPT I Phase ~~ Description of Operations 5/6/2008 18:30 - 00:00 5.50 CASE P TIEB1 P/U and RIH with BHA #8 on 4" HT-38 drill pipe 1 x 1 from pipe shead. 5/7/2008 00:00 - 01:30 1.50 CASE P TIEB1 Continue RIH picking up 222 total joints of 4" HT-38 drill pipe 1 x 1 from pipe shed. Tagged the top of 7" liner at 2347'. Ta d to of cement at 732 '. 01:30 - 07:00 5.50 DRILL P TIEB1 Establish drilling parameters of Up Wt- 147,000-Ibs; Down Wt- 120,000-Ibs; Rotating Wt- 133,000-Ibs at 40-RPM with 5000-Ib-ft free torque; Pump Pressure- 640-psi at 6-BPM on pump #1. Increase to 60-rpm while washing and reaming through soft cement with 3000-Ibs WOB. On bottom pump pressure at 670-psi at 6-BPM. Control drill through harder cement at 7390' with 3000 to 5000-Ibs WOB. Tag landing c i r with 60-80-RPM and 5000 to 6000-Ib-ft torque and 9000 to 14,000-Ibs WOB. On bottom pump pressure at 750-psi at 6-BPM. Continue to mill on landing collar with varied parameters. Drill through landing collar at 7424'. Continue to control drill through cement with 90-RPM and 4000 to 6500-Ib-ft torque, pump rate at 6-BPM with 800-psi. Maintain 4000-Ibs WOB, and drill off at 7508', top of the 7" stub. Get lots of cement and aluminum flakes across shakers. 07:00 - 07:30 0.50 DRILL P TIE61 Wash down to sand to at 7553' drill throu h 'unk and sto at 7563'. 07:30 - 08:00 0.50 DRILL P TIE61 P/U 3' and CBU at 7560' 12-BPM at 2885-psi and rotate at 20-RPM. Get some sand across shakers with flecks of aluminum. 08:00 - 08:30 0.50 DRILL P TIEB1 Dry drill to 7563' for 15-minutes, 60-RPM, 5-6000-Ib-ft free torque. 08:30 - 09:30 1.00 DRILL P TIE61 Circulate Hi-Vis sweep 12-BPM, 2890-psi for 350-Bbls and get some sand and aluminum flakes across shakers. 09:30 - 10:00 0.50 DRILL P TIEB1 Dry Drill for 15-minutes to 7567', 60-RPM, 5-6000-Ib-ft free torque. 10:00 - 10:30 0.50 DRILL P TIEB1 Circulate Hi-Vis sweep 12-BPM, 2870-psi, for 350-Bbls see some sand across shakers. 10:30 - 12:00 1.50 CASE P TIEB1 Clean Pits 3 and 4 to prepare for fluid swap to 8.5-ppg seawater. 12:00 - 15:00 3.00 CASE P TIEB1 R/U to test new 7" liner from RBP ~ 7610' to Liner To (~ 2348' and 9-5/8" casin from 2348' to surface. Chase ress r leakoff to valves in the mud manifold Conduct rock-solid test at . ~ 3 500- si for 30 chart-recorded minutes. 15:00 - 17:00 2.00 CASE P TIEB1 Finish cleaning Pits 1 and 2 and bring on 80-F, 8.5-ppg seawater to Pits. PJSM. Displace welbore to 8.5-ppg seawater 10-BPM at 2200-psi. 17:00 - 20:30 3.50 CASE P TIEBi POOH standing back 2-stands of 5" DP in Derrick, UD the remainder of the 5" DP, 39-joints, and S/B the 4" DP in the Derrick. 20:30 - 21:00 0.50 CASE P TIEBi POOH and UD drill out assembl .Stand back 3 stands of 4-3/4" drill collars. Recover 2 gallons of metal cuttings and sand from boot baskets. 21:00 - 21:30 0.50 CASE P TIEB1 Clear and clean rig floor. 21:30 - 22:30 1.00 CASE P TIE61 P/U RCJB,~BHA #9) consisting of RCJB, 7' CSG scraper, bit sub, pumpout sub, x/o sub, and 3 stands of 4-3/4" drill collars. Total length of BHA #9- 291.79' Printed: 6/10/2008 11:11:59 AM ~ • BP EXPLORATION Page 13 of 17 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date. Name: 0 ell Name: 0 e: Name: From - To 6-22 6-22 WORKO DOYON DOYON Hours VER DRILLIN 16 Task ' INC Code . NPT i Start Rig Rig Phase Spud Date: 9/15/1982 : 4/21/2008 End: 5/12/2008 Release: 5/13/2008 Number: Description of Operations 5/7/2008 22:30 - 00:00 1.50 CASE P TIEB1 RIH with RCJB on 4" HT-38 drill pipe from derrick. 5/8/2008 00:00 - 01:00 1.00 CASE P TIEB1 Continue to RIH with RCJB on 4" HT-38 and 16 stands of 5" drill pipe from derrick. 01:00 - 02:30 1.50 CASE P TIE61 Continue RIH with RCJB on 4" HT-38 from derrick. RIH with 76 stands of drill pipe and tag something on cement track at 7503'. Work scraper though area of 7416' to 7510' 2 more times Area appeared to clean up after the first time through, but hung up each time after. M/U to top drive and establish parameters of Up Wt- 162,000 Ibs; Down Wt- 133,000 Ibs; Rotating Wt- 140,000 Ibs at 40 rpm and 5000 ft-Ibs free torque; Pump Pressure- 620 psi at 5.2 bpm. Rotate through ledge at 7503' two times. Stop rotation and attempt to work through without success. P/U and set 1000 Ibs on ledge, rotate and roll off. P/U and attempt to work through without rotation. Rotation needed to work RCJB shoe through. Continue RIH 7' deeper where work string took 4000 Ibs before falling through. Continue RIH and tag top of sand at 7563'. Pump ball to activate RCJB at 5.2 bpm and 600 psi. Work RCJB through sand at 5.2 bpm and 970 psi in 5' sections to 7584'. 02:30 - 03:00 0.50 CASE P TIEB1 Drop ball and rod to open circ sub with 2300 psi. 03:00 - 04:00 1.00 CASE P TIEB1 Pump high visc sweep at 12.5 bpm with 2050 psi. Sweep brought back an increase of sand. 04:00 - 04:30 0.50 CASE P TIEB1 Pump dry job and blow down top drive. 04:30 - 08:00 3.50 CASE P TIEB1 POOH with RCJB standing back 4" HT-38 drill pipe in derrick. 08:00 - 08:30 0.50 CASE P TIEB1 ith R JB BHA stand back 3 stands of 4-3/4" drill collars. Recover 1 large thin piece of crumpled aluminum from the casing patch. Decision made to make another run with RCJB. 08:30 - 09:00 0.50 CASE P TIEBi Baker Tech redress the Pump-out sub above the RCJB. M/U to a 6-1/8" String mill to work through the obstruction at the old liner top -7503'. 09:00 - 11:30 2.50 CASE P TIEB1 PJSM. RIH RCJB BHA on DP from Derrick. 11:30 - 12:00 0.50 CASE P TIEB1 Stop above 7500' and get parameters: 6-BPM at 600-psi, 60-RPM, 5K-Ib-ft torque, P/U wt 163K, S/O wt 143K. Continue to RIH, see a slight bump on the way through, but work the string mill from 7500' to 7520', and see no obstruction. Note: The RBP was arked at 7610'. 12:00 - 12:30 0.50 CASE P TIEB1 B/O Top Drive and drop RCJB actuation ball and chase at 3-BPM, 190-psi. Pressure increased to 520-psi when the ball got on seat. Continue RIH and tag sand at 7585'. Increase rate to 6-BPM, 1340-psi and wash down to 7595'. Work pipe back up to 7545' and back down to 7595' several times. Parameters: 60-RPM, 5K-Ib-ft torque at Rot Wt 145K, P/U wt 163K, S/O wt 143K. 12:30 - 13:30 1.00 CASE P TIE61 Drop Ball to open the Circulating sub and chase at 3-BPM, 340-psi. Circ Sub opened with 2200-psi. Pump Hi-Vis sweep, 11-BPM, 1800-psi. See lots of sand come over the shakers before the sweep came to the shakers. Sand continued with the sweep, then stopped after the seawater returns cleaned up from the Hi-Vis material. 13:30 - 14:00 0.50 CASE P TIEB1 PJSM. Pump a dry job and blow down top drive., POH and S/B DP in Derrick. 14:00 - 16:00 2.00 CASE P TIEB1 POO,H_wj standing back 4" HT-38 drill pipe in derrick. Printed: 6/10/2008 11:11:59 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 5/8/2008 16:00 - 17:00 17:00 - 18:30 18:30 - 19:00 19:00 - 22:00 22:00 - 00:00 5/9/2008 100:00 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 07:00 06-22 Page 14 of 17 ~ 06-22 Spud Date: 9/15/1982 WORKOVER Start: 4/21/2008 End: 5/12/2008 DOYON DRILLING INC. Rig Release: 5/13/2008 DOYON 16 Rig Number: Hours .Task I Code II NPT Phase Description of Operations 1.00 CASE P 1.50 CASE P 0.50 BOPSU P 3.00 BOPSU P 2.00 BOPSU N 3.00 BOPSU N 1.00 BOPSU N 1.00 BOPSU N 2.00 BOPSU N 07:00 - 08:00 1.00 BOPSUF~ P 08:00 - 19:00 11.00 BOPSU P 19:00 - 20:30 I 1.501 BOPSURN TIEB1 POOH with RCJB BHA, stand back 3 stands of 4-3/4" drill collars. Recover 1 large thin piece of crumpled aluminum from the casing patch and 2 smaller pieces of metal. TIEB1 Clear and clean rig floor. Pull wear ring and set test plug. TIEB1 RILDS on test plug. R/U BOP testing equimpent. Fill stack with water. TIEB1 Test BOPE t 2 i I pressure. Each test was held for 5 minutes. AOGCC right to witness test was waived by Bob Noble. Test was witnessed by Doyon Toolpusher and BPX WSL. Test 1- IBOP and Variable Pipe Rams with 3-1/2" test joint Test 2- Choke Valves 12, 13, 14, Manual Kill, and Blind Rams Annular Preventer and Variable Pipe Rams with 5" test joint failed. RREP TIEB1 PJSM with rig crew. Discussion covered procedures and hazards for R/D flow line and flow nipple, R/D hydraulic lines, breaking loose Hydril Cap, and how to minimize the chance of a spill while draining hydraulic fluid from Hydril. Blow down choke and kill lines. Blow down top drive. R/U and break annular preventer cap. N/D and remove BOP yoke from BOPE. Remove turn buckles. RREP TIEB1 PJSM. Remove lifting yoke from BOP stack and remove from cellar. N/D pipe ram doors and remove variable pipe rams. Clean rams and send to shop to be rebuilt. Shut down accumulator and bleed off pressure. RREP TIE61 PJSM with rig crew. Discuss procedure and hazards of removing annular preventer from BOP stack. Lift annular preventer and set on rig mats in cellar. Drain hydraulic oil from annular preventer. RREP TIEB1 PJSM. Prepare new annular preventer for installation. P/U annular preventer and install on BOP stack. N/U annular preventer. RREP TIE61 Install rebuilt 3-1/2" x 6" variable pipe rams and N/U ram doors. Install riser and flow line. TIEB1 R/U BOPE testing equipment. TIEB1 Test BOPE to 250 psi low pressure and 3500 psi high pressure. Each test was held for 5 charted minutes. Test was witnessed by AOGCC inspector Jeff Jones. Test 1-Manual Choke, Manual Kill, Upper IBOP, and Annular Preventer with 5" test joint. Test 2- HCR Kill, Lower IBOP Test 3- Choke Valves 12, 13, and 14 Test 4- Choke Valves 9, 11, and 4" TIW Valve Test 5- Choke Valves 5, 8, and 10 Test 6- Choke Valves 4, 6, 7, and 5" Dart Valve Test 7- Choke Valve 2 and 5" TIW Valve Test 8- Choke Valves 1 and 3 Test 9- HCR Choke Valve Test 10- Annular Preventer with 3-1/2" test joint Accumulator Test- Starting Pressure- 3000 psi. After Actuation- 1900 psi. First 200 psi Recovery- 14 seconds. Full Recovery- 73 seconds. 5 Nitrogen Bottles ~ 2150 psi. RREP TIE61 Drain stack. Open pipe ram doors and examine ram components. Wear plate looked to be misaligned. Replaced Printed: 6/10/2008 11:11:59 AM • • BP EXPLORATION Page 15 of 17 Operations Summary Report Legal Well Name: 06-22 Common Well Name: 06-22 Spud Date: 9/15/1982 Event Name: WORKOVER Start: 4/21/2008 End: 5/12/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 5/13/2008 Rig Name: DOYON 16 Rig Number: Date II From - To Hours Task 'Code NPT ' Phase Description of Operations 5/9/2008 19:00 - 20:30 1.50 BOPSU N RREP TIEB1 top seal on wear plate. Adjust to proper placement of wear plate and close up ram door. Retest variable pipe rams without success. 20:30 - 21:30 1.00 BOPSU N RREP TIE61 Drain stack. Open pipe ram doors and change out variable pipe rams from 3.5" x 6" to 2.875" x 5". Close up ram doors. 21:30 - 23:30 2.00 BOPSU P TIEB1 Test 2-7/8" x 5" VBRs to 250 psi low pressure and 3500 high pressure with 5" and 3-1/2" test joints for 5 charted minutes. Test witnessed by AOGCC inspector Jeff Jones. Get good tests. 23:30 - 00:00 0.50 BOPSU P TIEB1 R/D BOP Test equipment. R/U to RIH. 5/10/2008 00:00 - 01:00 1.00 DHB P TIEB1 P/U HES RBP retrievin t Ion 3 stands of 4-3/4" drill collars from derrick. Total length of BHA- 286.51' 01:00 - 03:30 2.50 DHB P TIEB1 RIH with HES RBP retrieving tool on 61 stands of 4" HT-38 and 15 stands of 5" drill pipe from derrick to 7506'. 03:30 - 05:00 1.50 CASE P TIE61 PJSM. Gather tools and R/U to cut drill line. Slip and cut 344' of drill line to get rid of bad line. 05:00 - 06:00 1.00 DHB P TIEB1 Establish parameters of Up Wt- 170,000 Ibs; Down Wt- 132,000Ibs. Continue RIH with 2 stands of 5" drill pipe from derrick. Tag top of sand at 7595'. Wash down to tag HES RBP at 8 b m wit 910 si to 7613'. Line up to reverse circulate hole clean. 06:00 - 07:00 1.00 DHB P TIEBi R/U to reverse circulate and wash sand. Sand fell back on top of RBP while R/U. 07:00 - 09:00 2.00 DHB P TIEB1 Reverse circulate through sand while stripping through annular preventer at 4 bpm with 450 psi to the top of PBR at 7613'. 09:00 - 10:30 1.50 DHB P TIEB1 Latch onto HES RBP. Unseat RBP and confirm. CBU at 9 bpm with 1170 psi. Bottoms up brought gas and crude to surface. Allow gas and crude to clear up and monitor well static. Pump dry job and blow down top drive. 10:30 - 18:00 7.50 DHB P TIEB1 POOH and UD 4" HT-38 drill pipe and 5" drill pipe in pipe shed 1x1. UD (9) 4-3/4" drill collars. Examination of HES RBP showed that one of the rubber elements ripped in half leaving half of the rubber element downhole. 18:00 - 19:30 1.50 DHB P TIE61 Clear and clean rig floor. PJSM. Change out top drive savor sub to 4" HT-38 19:30 - 21:00 1.50 DHB P TIE61 PJSM. N/D riser and flow line. N/U Shooting flange. 21:00 - 00:00 3.00 DHB P TIE61 PJSM with rig crew and SWS. Discussion covered R/U procedures, hazards involving slick line operations, stay clear of loads, and R/U safety slings. Spot SWS, bring tools and equipment to rig floor. R/U full pressure control equipment and tools. 5/11/2008 00:00 - 02:00 2.00 FISH N DPRB RUNCMP PJSM with new rig crew and SWS. Discussion covered same issues as earlier along with R/U and testing full pressure control testing and well control situations. Continue to Rig Up Slickline Equipment and Lubricator. PT Lub to 3500 psi. 02:00 - 04:00 2.00 FISH N DPRB RUNCMP RIH 7" braided line brush with 5.5" wire grab to 9574' SLM. Encountered obstruction at~7113'. Worked obstruction free and continued RIH free of obstruction to 9119'. Set down weight at 9119' and worked obstruction to 9424'. Tools fell free from 9424'to - 04:00 - 05:00 1.00 FISH N DPRB RUNCMP POOH with 7" braided line brush and 5.5" wire grab from 9574' SLM. Recovered nd half of RBP rubber element. full rubber spacer ring, and 3 pieces of junk metal from casing patch. Printed: 6/10/2008 11:11:59 AM • • BP EXPLORATION Page 16 of 17 Operations Summary Report Legal Well Name: 06-22 Common Well Name: 06-22 Spud Date: 9/15/1982 Event Name: WORKOVER Start: 4/21/2008 End: 5/12/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 5/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To ' Hours Task ', Code I NPT Phase Description of Operations 5/11/2008 05:00 - 06:00 1.00 FISH N DPRB RUNCMP M/U Slick Line 6" Gau a Rin Junk Baskett and RIH. Able to run to bottom at 9574' SLM: Did see tight spot at 7508' SLM - Correlates to Tight spot that was milled with DP. 06:00 - 08:00 2.00 FISH N DPRB RUNCMP POOH with Slick Line Gauge Ring Junk Basket. Recovered -1/4 cup worth of small metal pieces and shaving. Decide to run GR/JB a ain for added insurance. 08:00 - 09:00 1.00 FISH N DPRB RUNCMP RIH with Same 6" Gauge Ring and Junk Basket Configuration. Run to bottom without Seeing Tight Spot at -7508' SLM. 09:00 - 10:00 1.00 FISH N DPRB RUNCMP POOH with GR /JB. Recovered 3 small pieces of metal like the run prior. 10:00 - 11:30 1.50 FISH N DPRB RUNCMP PJSM with SWS and Rig Crew on Rigging Down Tools and Equipment. R/D Slickline Tools and Equipment. N/D Shooting FLange and N/U Flow Riser. 11:30 - 13:00 1.50 BUNCO RUNCMP Pull Wear Ring, R/U Power Tongs and Torque Turn for Tubing. R/U Compensator and Single Jt P/U Sling. Organize Jewlery. Found Bad Collar on "B" Packer, collar flagged to be changed out when picked up. 13:00 - 13:30 0.50 BUNCO RUNCMP PJSM with Rig Crew, Doyon Casing Crew, and Baker Completions. Review Tbg Running Procedures, Keeping Head in Game while Running Tubes, and other possible errors that can be made. 13:30 - 00:00 10.50 BUNCO RUNCMP P/U and Run 3-1/2" 13Cr80, 9.2#, VamTog Tbg Completion with 7"x3-1/2" Unique Overshot and Dual 7"x4-1/2" Baker Premier Packers- crossed back over to 3-1/2" tbg. Average M/U Torque 2900 ft-Ibs, all connections made up with Torque Turn using Jet Lube Seal Guard Thread Compond. 5/12/2008 00:00 - 03:30 3.50 BUNCO RUNCMP Continue RIH with a total of 294 joints of 3-1/2" tubing to 9527'. 03:30 - 06:00 2.50 BUNCO RUNCMP Establish parameters of Up Wt-116,000 Ibs and Down Wt-102,000 Ibs. P/U joint #295 and continue RIH to 9541' where completion string took weight. P/U and S/O again at 9541' with 3000 Ibs. P/U and confirm measurements and count tubing. R/U circulating head to joint #295 and continue RIH at 0.75 bpm with 130 psi. Worked joint #295 down without takin wei ht. R/U circulating head to joint an Break circulation with 1 bpm and 140 psi. Tag top of tubing stub at 9572'. Tag upper set of shear pins at 9575' and shear with 7000 Ibs. Tag lower set of shear pins at 9583' and shear with 5000 Ibs. No go out at 9586' and S/O 10,000 Ibs. P/U 7' and confirm no-go at 9586'. P/U 7" and RIH to top of no-go. 06:00 - 07:30 1.50 BUNCO RUNCMP P/U 4' pup joint and reconfirm no-go. POOH and UD joints 296, 295, and 294. M/U 3 Space Out Pups, total 27.58 ft. M/U Joint 294. 07:30 - 08:00 0.50 BUNCO RUNCMP M/U FMC Tbg Hanger and 4-1/2" TC-II Landing Joint. M/U to Tbg String and Land Hander in Tbg Spool. 08:00 - 08:30 0.50 BUNCO RUNCMP FMC „and Torque to 450 ft-Ibs. M/U Hoses and R/U to Circ. 08:30 - 09:00 0.50 BUNCO RUNCMP PJSM with Rig Crew, Vac Truck Drivers, and BOT. 09:00 - 12:30 3.50 BUNCO RUNCMP Reverse Circulate in 85 bbls of Clean 140 degree SW followed by 340 bbls of 140 deg SW with Corrosion Inhibitor. Circulate in at 3 bpm and 570 psi. 12:30 - 15:30 3.00 BUNCO RUNCMP Dro B Let Fall 20 mins. Pressure u on T to 420 si for 1 mins while res Printed: 6/10/2008 11:11:59 AM • • BP EXPLORATION Page 17 of 17 Operations Summary Report Legal Well Name: 06-22 Common Well Name: 06-22 Spud Date: 9/15/1982 Event Name: WORKOVER Start: 4/21/2008 End: 5/12/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 5/13/2008 Rig Name: DOYON 16 Rig Number: Date ', From - To ~, Hours Task ;Code NPT I Phase Description of Operations 5/12/2008 12:30 - 15:30 3.00 BUNCO RUNCMP up saw all 4 shear points for Packers. Found slight leak on Landng Joint. Bleed Down and Tighten up. .Pressure Up on Tb to 3500 si and ressure test tb for 30 mins on chart -_ ood test. Bleed Down Tubin Pressure to 1500 psi. Shut-in Tb and Pressure U~ on IA to 3500 psi. Pressure Test Casing to 3500 si for 30 charted mins -good test. No pressure was '~ - seen on OA during pressure Testing. 15:30 - 16:00 0.50 BUNCO RUNCMP~ Wlth 3500 psi on IA, Bleed Down Tbg Pressure to Shear out Valve in Top GLM. Valve went at -2400 psi differential. Pump 3 bpm ~ 300 psi both ways through valve to confirm open. 16:00 - 17:00 1.00 BOPSU P RUNCMP Pull Landin Joint from Han er and L/D. FMC Set TWC in Han er. Pressure Test TWC from Above to 3500 psi for 10, C from Below for 10 mins to 1000 psi. mins and then Test TW _ Both Test Charted. ~~ ____ 17:00 - 20:30 3.50 BOPSU P RUNCMP Blow down circulating lines. R/U and install BOP lifting ring around Hydril. N/D BOPE and stand back on stump. 20:30 - 21:30 1.00 WHSUR P RUNCMP Clean and inspect tubing spool ring groove and flange for damage. P/U 13-5/8" x 4-1/16" adapter flange. N/U adapter flange. 21:30 - 22:30 1.00 WHSUR P RUNCMP R/U and test adapter flange and hanger to 5000 psi for 30 min. Good test, test witnessed by BPX WSL. 22:30 - 23:30 1.00 WHSUR P RUNCMP P/U and N/U 4-1/16" production tree. 23:30 - 00:00 0.50 WHSUR P RUNCMP R/U and test tree to 5000 psi for 30 charted minutes. Test witnessed by BPX WSL. 5/13/2008 00:00 - 02:00 2.00 WHSUR P RUNCMP Continue testing tree to 5000 psi for 30 charted minutes, good test. Test witnessed by BPX WSL. R/D testing equipment. 02:00 - 03:00 1.00 WHSUR P RUNCMP Spot LRHOS. P/U DSM tools and equipment. M/U DSM - TV1/C. lubricator to tree and test to 500 psi, good test. Pull`` ec or pressure. D M tools and equipment. 03:00 - 05:00 2.00 WHSUR P RUNCMP R/U LRHOS. Pressure circulating lines to 3500 psi. Reverse circulate 160 bbls diesel freeze protection at 2 bpm with 700 psi. R/D LRHOS 05:00 - 06:00 1.00 WHSUR P RUNCMP Line up and allow freeze protection to U-Tube from the annulus to the tubing. Diesel freeze protection set at 2280'. 06:00 - 07:00 1.00 WHSUR P RUNCMP P/U DSM lubricator and tools. Set BPV and test to 1000 psi for - _...m_..._ ~ -. ... m, ......-....._. 10 charted minutes,„good test.. 07:00 - 08:00 1.00 WHSUR P RUNCMP Secure well and cellar. Remove double annulus valves. Prepare to move off DS 6-22A. Release riq at 08:00 hrs, May 13, 2008. Printed: 6/10/2008 11:11:59 AM .] SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE,A~ASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 David Reem Engineer Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 • F~ yb'@9Cl6tl~l~ `~"/"~` ~ e9 CQ~GY Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06-22A Sundry Number: 308-170 ~ ®`"7 ~C~3 Dear Mr. Reem: ~. Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Comrriission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Encl. STATE OF ALASKA ,S ~ ~ ~ ~' t~' AL~4 OIL AND GAS CONSERVATION COM~ION f ~ MAY 0 ~~b APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.2so Alaska Oil & Gas Cons. Commission 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensic~ilnChO(age ® ter Casing ~ ®Repair Well . ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ Ch A ®P ll T ^ ^ 1~ ange pproved Program u ubing - Perforate New Pool ^ Waiver Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 193-057 / 308-140 3. Address: ^ Service ^ Stratigraphic 6. API Number: - P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20806-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or -andownership changes: PBU 06-22A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): - ADL 028311 63.0. Prudhoe Bay Field / Prudhoe Bay Pool 12_ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10681 9237 ~ 10600 9159 9635' N/A C sin n h Si a MD TVD Burst Colla se r ct ral n u r 7' 2 79' 79' 14 470 rface 2519' 1 -3/8" 2519' 2519' 493 2670 Intermedia e Pr ction 2 7' - / " 297' 791 7 7 Liner 8538' 7" 2143' - 10681' 2143' - 9237' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10451' - 10502' 9016' - 9065' 3-1/2", 9.3# L-80 9681' Packers and SSSV Type: 7" Xx 3-1/2" Baker SABL-3 Packer Packers and SSSV MD (ft): 9615' 3-1/2" CAM TRDP-2A SSSV 2107' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 1, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: ~; c~ro;.\ Cs.~c.C. Date: 5/2/2008 ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: Jim Regg 18. I hereby certi that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564-4102 Printed Na a avid Reem Title Engineering Team Leader Prepared By NamelNumber: Signature Phone 564-5743 Date .S~S~QQ Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form R . uired: ~ ~ ~'` ,r ~~ ~o~ , ~~ ~.~c~,~~w©r~t ~~c 3~~~ \~-~,® QQ ~~ ~ APPROVED BY ~ A roved B : COMMISSIONER THE CO MISSION Date Form 10-403 Ffevised 0/2066 oRicin~A~ ~?~~~ ~ ~~ ~~~ Submit In Duplicate FW: 06-22A Proposed Plan Forward Page 1 of 2 • • Stewman, Sondra D Subject: FW: 06-22A Proposed Plan Forward From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, May 02, 2008 1:50 PM To: Worthington, Aras J Cc: Maunder, Thomas E (DOA); Foerster, Catherine P (DOA) Subject: RE: 06-22A Proposed Plan Forward You are approved to move forward with the proposed change, i.e., straddle the leak in 7" liner lap with 2 packers as part of final completion. Please follow this approval with a 10-403 within 3 days as required by 20 AAC 25.507(b). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Worthington, Aras J [mailto:Aras.Worthington@bp.com] Sent: Friday, May 02, 2008 10:52 AM To: Regg, James B (DOA) Subject: FW: 06-22A Proposed Plan Forward From: Worthington, Aras J Sent: Friday, May 02, 2008 9:56 AM To: 'Maunder, Thomas E (DOA)' Cc: Reem, David C Subject: 06-22A Proposed Plan Forward Hi Tom, Doyon 16 is currently working on 06-22A rig workover. After we pulled the completion tubing we did some testing on the existing 7" liner and found that the liner lap @ -9090' and was leaking. We plan to cut and pull the existing 7" liner @ -7500' and tie back into it with our new 7" scab liner and cement same (all as per previously approved plan Sundry # 308-140). What we propose to change (and are asking approval for) is to straddle the leak in the 7" liner lap with two packers in the final completion: Upper packer at 7400' and and the bottom one -9400' and (see attached schematic for detail). Thanks, Aras Worthington Well Intervention Engineer BP Alaska Inc. (907) 440-7692 «6-22A Proposed.tif» 5/5/2008 TREE = FMC GEN 3 WELLH D = FMC ACTUATOR = AXELSON KB. ELEV = 63.0' BF. ELEV = KOP = 2900' Max Angle = 48 ~ 6800' Datum MD = 10355' Datum TV D = 8800' SS SAFETY NOTES: CSG SPEED NIP HAS BEEN ~6-22~ Proposed `"E` ITOPOFT'LNR I • I 13-3/8" CSG, 72#, L-80, ID =12.34T' Minimum ID = 2.760" ~ 9669' 3-1 /2" PARKER SWN NIPPLE 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 MMG RK 2 MMG RK 3 MMG RK 4 MMG RK 5 MMG RK 7400' H T' X 4112" BKR Rerr>iere PKR ~ T' LNR, 2911, L-80, .0371 bpf, ID = 8.184" ~ TOP OF T' LNR H 9106' 9-5/8" CSG, 47f1, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: BRCS ON 05/03/93 ANGLE AT TOP PERF: 91 ° ~ 10451' Note: Refer to Roduction OB for historical pert data S2E SPF INTERVAL OpNSgz DATE 2-1/8" 4 10451 - 10461 C 07!04/94 2-1/8" 4 10461 - 10466 C 05!14/94 2-1/8" 4 10466 - 10474 C 04/27/94 2-1 /8" 6 10474 - 10482 C 03/03/94 2-1/8" 4 10482- 10502 C 11/16/93 3-1/2" TBG-IPC, 9.3#, L-80,.0087 bpf, ID = 2.992" X81' I~H 1~' 7" LNR, 29A1, L-80, .0371 bpf, ID = 6.184" 1 2200' -{3 1R" HF.S X Nipple ~ = 2.813" Liner Too Psrclo3r H CSG PATCH 9087' TNV TYPE LG SEAL ASSY, ID = 6.200" MLLOUTIMNDOW 9-5/8" ~ 929T - 934T 31 /7' HES X Nipple ID = 2.813" 7" X 41/2" BKR Plemiere PKR 31 /2" HES X Nipple O = 2.813" 3-1/2" x 7" Cr Unique Overshot ~1b' T' X 3-1/2" BKR SABL-3 PKR, ID = 3.87" 8636' HES BB RBP (820l15Q5~ 8661' 3-112" PA RKFJZ SW5 NIP, ID = 2.813" 8668' 3-1/2" PARKERSWN NIP, ID = 2.75" 8681' 31/2" TBG TAIL WLEG, O = 2.992„ \ 968&' ELMD TT LOGGED 03/19/97 DATE REV BY COMMENTS DATE REV BY COATIENTS 88130182 ORIGINAL COMPLETION 06!13/0.3 CMO/TLP KB ELEVATION CORRECTION 11/05!93 LAST WORKOVER 04/11 /04 JLJ/KAK SWN NIP ID CORRECTION 02/20/01 SIS-MD FINAL 12120/04 RDJ/PAG WANER SAFETY NOTE REV 09/19!01 RNlTP CORRECTIONS 02/14/03 /tlh CORRECTIONS 03/26/03 JRGKK WANER SAFETY NOTE PRUDHOE BAY UNR WELL: 06-22A PERMIT No: 1930570 API No: 50-029-20806-01 SEC 2, T10N, R14E, 2386.4' FEL 82902.14' FNL ~ Exploration (Alaska) 05!08/08 3chlumb~rger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well _Inh et NO. 4690 %.~R::r~"3111il~~li~ MA~ ~ cy 2008 Company: State of Alaska ~"dATf1'~ l~ a~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave., Suite 100 Anchorage, AK 99501 i n.. P1-18A GNI-04 12014006 12057606 PRODUCTION PROFILE _ RST/WFL ~ ~ _ I r 04/05/08 04/24/08 1~ 1 vv~v~ iV 1 MPL-15 12021153 MEM INJECTION PROFILE ~~ 3:G~a~-0~~ ~~~ 04/19/08 1 1 03-09 11999005 PRODUCTION PROFILE WlFSI ~ 04/29!08 1 1 6-22A 11970825 USIT - ~ 04/27!08 1 i W-45 11978456 MEM TEMP & PRESS SURVEY - V~_ / ~ - ac~~ 04/28/08 1 1 X-06 12071852 INJECTION PROFILE _ ~ G 04/30/08 1 1 L5-32 11975767 PRODUCTION PROFILE W/FSI ' ~~- 04/27/08 1 1 DI GACC Af`VGIA~nn en2o o~ nonr ew n __ ___ _. _.___.._~._.-_..~. ~......._. ....~..... ~....., .v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 '(1f ~2 Date Delivered: ~~~ }`' ,~ ~ Alaska Data & Consulting S rvices 2525 Gambell Street, Sui 4 Anchorage, AK 99503-2 8 ATTN: Beth Received by: • FW: 06-22A Proposed Plan Forward Page 1 of 1 • • Regg, James B (DOA) From: Regg, James B (DOA) ~ ~ ~~~ ©~ Sent: Friday, May 02, 2008 1:50 PM To: 'Worthington, Aras J' Cc: Maunder, Thomas E (DOA); Foerster, Catherine P (DOA) Subject: RE: 06-22A Proposed Plan Forward ,~ l~ ~--°- d5~ You are approved to move forward with the proposed change, i.e., straddle the leak in 7" liner lap with 2 packers as part of final completion. Please follow this approval with a 10-403 within 3 days as required by 20 AAC 25.507(b). Jim Regg Ao~cc 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~t~a!~9~E~ MAY Q ~ 2008 From: Worthington, Aras J [mailto:Aras.Worthington@bp.com) Sent: Friday, May 02, 2008 10:52 AM To: Regg, James B (DOA) Subject: FW: 06-22A Proposed Plan Forward From: Worthington, Aras J Sent: Friday, May 02, 2008 9:56 AM To: 'Maunder, Thomas E (DOA)' Cc: Reem, David C Subject: 06-22A Proposed Plan Forward Hi Tom, ~ tfi,r~~ ~~._ j ~ Doyon 16 is currently working on 06-22A rig workover. After we pulled the completion tubing we did some testing on the existing 7" liner and found that the liner lap @ 9090' and was leaking. We plan to cut and pull the existing 7" liner @ 7500' and tie back into it with our new 7" scab liner and cement same (all as per previously approved plan Sundry # 308-140). What we propose to change (and are asking approval for) is to straddle the leak in the 7" liner lap with two packers in the final completion: Upper packer at 7400' and and the bottom one 9400' and (see attached schematic for detail). Thanks, Aras Worthington Well Intervention Engineer BP Alaska Inc. (907) 440-7692 «6-22A Proposed.tif» 5/2/2008 TREE = FMC GE WF1LH FAD= F'MC _ _ ACTUATOR= _ ~ AXELSON KB. FlEV = 63.0' BF. F1EV = KOP = 2900' Ibfaax Angle = -_. 48 ~ 6800'; _------ Datum MD = 10355_ Datum TVD = 6800' SS 5~1'Y NOTES: CSG. SPEED NIP HAS BEEN 16-2~A P ro posed E°- ,~ J~ S~Z~ ~ ITOPOF 7" LNR I I 2200' i [3 1/2" EiES X Nipple ID = 2.813" Liner Ton Paolcer 13-3/8" CSG, 72#. L-ga, ID = 12.347" ~-{ 2599' ~_._._.~^ Minimum #D = 2.760" ~ 9669' 3-1 /2" PARKER SWN N#PPLE 7" LNR, 26#, L-60, 0.0383 bpf, ID = 6.276" ~ ,r~~ 7" LNR, 28#, L-80, .0371 bpf, ID = 6.184" 90$7' -~._` ~ ~ r~er- I ~ '~ ~~~k- TOPOF 7" LNR 990$' 9-5/8" CSG, 47#, L-80, EO = 8.681" - 9297' PERFORATION SUMMARY RFF LOG: BRCS ON 05/03/93 ANGLE AT TOP PERF: 91 ° ~ 10451' Nate: Refer to Production DB for historical pert da#a SIZE 5PF INTERVAL Opn/Sqz DATE 2-118" 4 10451 -10461 C 07!04!94 2-1 /8" 4 10461 -10466 C 05114!94 2-118" 4 10466 - 10474 C 04/27/94 2-1/S" 6 10474 - 10482 C 03/03/94 2-118" 4 10482 - 10502 C 11/16/93 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 MMG RK 2 MMG RK 3 MMG RK 4 MMG RK 5 MMG RK ' 7" X 4-112" BKR Prerriere PKR --~CSG PATC]-I 9087' TMI TY PE LG SEAL ASSY, tD = 6.200" MILLOUTIMNWW 9-Sl8" ~ 9297' - 9347' 3112" HES X Nipple ID ~ 2.813" tiq~ ~ 7"X4-1/2" 8KR Remiere PKR 3112" HES X Mpple ID = 2.813" ~~ 3-112" x 7" Cr Unique Overshat 9$95' ~7" X 3-112" BKR SABL-3 PKR, ID = 3 $638' -{HES BB RBP (8!20/05) 9$51' 3-112" PARKER SWS NIP, ED = I~ 3-1/2" PARKER SWN NIP, ID = 2.75" 9$$1' 3~1l2" TBG TAIL WLEG, fD = 2.992" 9$$5' ELMDTT LOGGf 03/19/97 3-1l2" TBG-IPC, 9.3#, L-80,.0087 bpf, ID = 2.992" 9$$9' PBTD 90$00~~- 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10$81' DATE REV BY CONMENFS DATE REV BY COtNIV1ENTS 08!30!82 ORIGINAL COMPLETION OS/13!03 CMOl1'LP KB ELEVATION CORRECTION 11f06/93 LAST WORKOVQ2 04li t /04 JLJ/KAK SWN NIP ID CORRECTION 02/20!01 SIS-MD FINAL 12/20/04 RQUPAG WAIVER SAFETY NOTE REV 09!19!01 RN/TP CORRECTONS 02114/03 ttpt CORRECTIONS 03/26/03 JRGKK WAIVER SAFETf NOTE PRUDI-fOE BAY UNIT WELL: 06-22A PERtYaT' No: °1930570 APE No: 5Q-029-20806-01 SEC 2, T10N, R14~ 2386.4' FEL 8 2902.14' FNL 13P Exploration (Alaska) • • ALASKA OIL A1~TD G~5 CO1~TSkRVATIOlY COMI~'II55ION David Reem Engineering Team Leader BP Exploration Alaska., Inc. SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PO Box 196612 Anchorage, AK 99519-6612 ~~3 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06-22A Sundry Number: 308-140 5~~~1~~ APR ~ 3 200 Dear Mr. Reem: .05'~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~~~~ Cathy P. Foerster Commission L DATED this ~ day of April, 2008 Encl. ~;~~. ,~ -~~ ~,,- RECEfVED ' ~ ~ STATE OF ALASKA ° ~ ALA OIL AND GAS CONSERVATION COM ION ~,~ t~ APR 1 5 2008 ' ' ~ APPLICATION FOR SUNDRY APPROVA ~ 2 LAlaska Oil & Gas Cons. COmmission 0 AAC 25.280 ,,,,,,~,,,,,,,,~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ® Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 193-057 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20806-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 06-22A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): , ADL 028311 " 63,0 ' Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10681 9237- 10600 9159 9635' N/A Casin Len th Size MD TVD Burst Colla se Structural Cond ctor 79' 20" 79' 79' 1490 470 Surface 2519' 13-3/8" 2519' 2519' 4930 2670 Intermediate Produ i n 9297' 9- !8" 9297' 7915' 6870 47 Liner 8538' 7" 2143' - 10681' 2143' - 9237' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10451' - 10502' 9016' - 9065' 3-1/2", 9.3# L-80 9681' Packers and SSSV Type: 7" Xx 3-112" Baker SABL-3 Packer Packers and SSSV MD (ft): 9615' 3-1/2" CAM TRDP-2A SSSV 2107' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 1, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564-4102 Printed Name Da ' Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date ff ~ Sondra Stewman, 56a-4750 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~ .~®~ ~ t `7®~ ,~...CS Subsequent Form Required: ~~~ n ~ A roved B : COMMISSIONER THE OMMISSION Date Form 10-403 Revised 06r/200fi ~ Submit In Duplicate / '~'~' DIAL • by c,~,r~ 06-22A Rig Workover • Scope of Work: Cut & Pull 3-1/2" L-80 completion, Cut & Pull 7" scab liner, run and cement new 7" scab liner, change out 9-5/8" casing packoffs, Run new 3-1/2" 13Cr-80 completion. MASP: 2770 psi Well Type: Producer Estimated Start Date: May 1st, 2008 Intervention Engineer: Aras Worthington Pad Engineer: Ana Seltenright Pre-rip. prep work: O 1 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. S 2 Drift down to HES RBP @ 9626' md. Set Junk catcher on to of RBP. E 3 Jet cut C~ 9560', 10' from the top of 1S full joint above the packer (Ref: 11/4/93 tubing summar F 4 MITOA to 2400 si. F 5 Circulate/bullhead seawater thru the cut. Load wellbore with 9.8 ppg Brine. Bleed WHP's to 0 si. W 6 Set BPV O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU Doyon 16. Pull BPV. Circulate out freeze protection through the cut and load wellbore with 9.8 ppg brine. Run TWC. ND tree. NU and test BOPE to 250 psi low, 3500 psi high. 2. Pull and LD 3-1/2" tubing string. 3. Cut and pull 7" liner. _ 4. Run new 7" L-80 liner with casing patch and cement same. 5. Change out 9-5/8" Casing packoffs. 6. Run new 3-1/2" 13Cr80 tubing stacker packer completion with packer at 9550' MD. 7. Displace the IA to packer fluid and set the packer. 8. Test Tubing & IA to 3500 psi. 9. Set TWC. ND BOPE. NU and test tree. Pull TWC, Freeze protect tbg and IA with diesel and Set BPV. RDMO. TREE = FMC GEN 3 WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 63.0' BF. ELEV = KOP = 2900' -Max Angle = 48 @ 6800' Datum MD = 10355' Datum TV D = 8800' SS • os-ii Q 2107' 3-1/2" CAM TRDP-2A SSSV NIP, ID = 2.813" 2138' TNV HLP PKR, ID = 6.19" TOP OF 7" LNR ~ 2143' 7" LNR, 29#, 13-CR, .0371 bpf, ID = 6.184" 2461' 13-3/8" CSG, 72#, L-80, ID = 12.347" ~--~ 2519' Minimum ID = 2.760" @ 9669' 3-1 /2" PARKER SWN NIPPLE 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ 9087' TOP OF 7" LNR 9106' 9-5/8" CSG, 47#, L-80, ID = 8.681 " 9297' PERFORATION SUMMARY REF LOG: BHCS ON 05/03/93 ANGLE AT TOP PERF: 91 ° @ 10451' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 10451 - 10461 C 07/04/94 2-1/8" 4 10461 - 10466 C 05/14/94 2-1/8" 4 10466 - 10474 C 04/27/94 2-1/8" 6 10474 - 10482 C 03/03/94 2-1/8" 4 10482 - 10502 C 11/16/93 2609' ~ TOP OF HOMCO CSG PATCH, ID = 8.375" CSG PATCH ' BTM OF HOMCO 2649 (;AS I IFf MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3114 3106 16 MMG2 RK 2 5775 5268 37 MMG2 RK 3 7996 6870 43 MMG2 RK 4 9154 7787 29 MMG2 RK 5 9530 8132 17 MMG2 RK 9087' I~TMJ TYPE LG SEAL ASSY, ID = 6.200" MILLOUT WINDOW 9-5/8" @ 9297' - 9347' I 9591' 3-1/2" PARKER SWS NIP, ID = 2.813" 9615' 7" X 3-1/2" BKR SABL-3 PKR, ID = 3.87" 9635' HES BB RBP (8/20/05) 9651' 3-1/2" PARKER SWS NIP, ID = 2.813" 9669' 3-1/2" PARKERSWN NIP, ID = 2.75" 9681' 3-1/2" TBG TAIL WLEG, ID = 2.992" 9685' ELMD TT LOGGED 03/19!97 3-1/2" TBG-IPC, 9.3#, L-80,.0087 bpf, ID = 2.992" I-~ 9681' ~ PBTD 10600' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10681' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/30/82 ORIGINAL COMPLETION 06/13/03 CMO/TLP KB ELEVATION CORRECTION 11/05/93 LAST WORKOVER 04/11/04 JLJ/KAK SWN NIP ID CORRECTION 02/20/01 SIS-MD FINAL 12/20/04 RDJ/PAG WAVER SAFETY NOTE REV 09/19/01 RWTP CORRECTIONS 09/24/05 KDGPJC HES BB RBP (SET 8/20/05) 02/14/03 /tlh CORRECTIONS 03/26/03 JRGKK WANERSAFETY NOTE PRUDHOE BAY UNIT WELL: 06-22A PERMfr No: 1930570 API No: 50-029-20806-01 SEC 2, T10N, R14E, 2386.4' FEL & 2902.14' FNL BP F~cploration (Alaska) TREE = FMC GEN 3 WELLHEAfl = FMC ACTUATOR = AXELSON KB. ELEV = 63.0' BF. ELEV = KOP = 2900' Max Angle = 48 ~ 6800' Datum MD = 10355' Datum TV D = 8800' SS 8-22~ Propose 1TOPOF7" LNR I • 13-318" CSG, 7Z#, L-S0, ID =12.34T' ~--{ 2b19' Minimum ID = 2.760" ~ 9669' 3-1 i2" PARKER SWN NIPPLE 7" LNR, 261, L-80, 0.0383 bpf, ID = 6.276" T' LNR, 29N, L-80, .0371 bpf, 1D = 6.184" 9057' STOP OF T' LNR I1 8106' 9-5/8" CSG, 470, L-80, ID = 8.681" 8297' PERFORATION SUMMARY Rff LOG: BRCS ON 05/03/93 ANGLE AT TOP PERF: 91 ° ~ 10451' Note: Refer to Roduction DB for historical pert data S¢E SPF INTERVAL OpNSgz DATE Z-1/8" 4 10451 - 70461 C 07/04/94 2-1/8" 4 10461 - 10466 C 05/14/94 2-118" 4 10466 - 10474 C 04/27/94 2-1/8" 6 10474-10482 C 03/03/94 2-1/8" 4 10482- 10502 C 11/16/93 L- T' LNR, 29M, L-80, .0371 bpf, ID = 2200' -{3 1/2" HES X N~ple ~ = 2.813" Liner Top Packer 2608' HTOP OF HOMCO CSG PATCH, ID = 8.375" 2849' 8TM OF HOMCO CSG PATCH ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 MMG RK 2 MMG RK MMG RK 4 MMG RK 5 MMG RK H CSG PATCH 9087' TM1 TY PE LG S EA L ASSY, O = 8.200" MLLOUT WINDOW 9-5/8" ~ 929T - 934T 3112" HES X Fipple ID = 2.813" 7" X 41/2" BKR S3 PKR 31 /2" HES X Nipple ID = 2.813" 3-112" x 7" G Unique Overshot 9616' T' X 3-112" BKR SA BL-3 PKR, ID = 3.87" 8636' HE5 BB RBP (8/20/05) 96b1' 3-1/2" PA RKER SWS NIP, O = 2.813" 9668' 3-1/2"A4RKERSWN NIP, tD = 2.75„ 9681' 3-1/2" TBG TAIL WLEG, O = 2.992" \ 9686' ELMD TT LOGGED 03/19/97 10600' 1-r 1 DATE REV BY COMMENTS DATE REV BY CONVENTS 08/30182 ORIGINAL COMPLEnON 06/13/03 CMOliLP KB ELEVATION CORRECTION 11/05/93 LAST t1VIORKOV6t 04/11/04 JLJ/KAK SWNN~IDCORRECTiON 02120!01 SIS-MD FINAL 12/20/04 RDJ/PAG WAVER SAFETY NOTE REV 09/19/01 RN/TP CORRECTIONS 02/14/03 Rlh CORRECTIONS 03/26/03 JRGKK WAVER SAFETY NOTE PRUDHOE BAY UNfT WELL: 08-22A PERMff No: 1930570 API No: 50-029-20806-01 SEC 2, T10N, R14E, 2386.4' FEL 82902.14' FNL BP f5cploration (Alaska) ~ 3-1/2" TBG-IPC, 9.3#, L-80,.0087 bpf, ID = 2.992" ~ 6-22A RWO and 7" casing Rams (Sundry # 301-840) Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 22, 2008 9:19 AM To: 'Reem, David C' Cc: Worthington, Aras J Subject: RE: 6-22A (193-057) RWO and 7" casing Rams (Sundry # 301-840} Dave and Aras, Your proposal will meet the regulatory requirements. I will place a copy of this message in the file. Good luck with the work. Tom Maunder, PE AOGCC om: Reem, David C [maiito:ReemDC@BP.com] Se • Monday, April 21, 2008 4:43 PM To: M nder, Thomas E (DOA) Cc: Wort " gton, Aras J Subject: 6- RWO and 7" casing Rams (Sundry # 301-840) Tom, I went through i etail Aras Worthington's Well Plan for the workover on 6-22A. plan on maintaining a 2-ram, 1-annular preven stack throughout the workover as follows: 1) Upon rig-up, Doyon 16's P pipe ram will be equipped with 3-1/2" x 6" v able bore rams. We will test this BOP stack with 3-112" and 4" st joints to 250 psi (low)/3500 psi (hi per BP/AOGCC regs. 2} We will pull the 3-V2" completion the pre-RWO tubing cut dep We will dress pff the tubing stub, cut the 7" scab liner, mill up the 7" liner-top pa er all on 4" drill-pipe. is work is all done over-balanced to the Cretaceous with 9.8 ppg NaCL brine. We'll s d back the 4" dP ' the derrick. 3) We will set a wellhead test plug and run in loc own rews. We will pressure test this test plug to 2000 psi and use it as a mechanical barrier to the Creta s. Well will be full of 9.8 ppg brine. 4) At this time we'll swap the 3-1/2" x 6" VBRs r 4-1/2" x "VBRs and test with a 5" and a 7" test joint to 250 psi (low)/3500 psi (high) per BP/AOGCC regs. 5) We will pick up 5" drillpipe to fish t 7" scab liner, dress off the "stub, run and cement the new 7" scab liner. This liner will be PT'd to 3500 p once the cement builds adeq to compressive strength. 6) We will set a wellhead to plug and run in fockdown screws. We will pre ure test this test plug to 2000 psi and use it as an addition mechanical barrier to the Cretaceous. Well will full of 9.8 ppg brine. 7) The 4-1J2" x 7" Rs will be swapped back to the 3-1/2" x 6" VBRs. Similar BOP t ling as before. 8) 4" drill-pi and 3-1/2" completion tubing will be the remaining pipe sizes run in this well a will be covered by the 3-1/2" 6" VBRs. lease review this plan as an addendum to the plan attached in the Sundry application (#301-840) and, if you 4/22/2008 6-22A RWO and T' casing Rams (Sundry # 301-840) Page 1 of i Maunder, Thomas E (DOA) From: Reem, David C [ReemDC@BP.com] Sent: Monday, April 21, 2008 4:43 PM To: Maunder, Thomas E (DOA) Cc: Worthington, Aras J Subject: 6-22A RWO and 7" casing Rams (Sundry # 301-840) Tom, I went through in detail Aras Worthington's Well Plan for the workover on 6-22A. We plan on maintaining a 2-ram, 1-annular preventer stack throughout the workover as follows: 1) Upon rig-up, Doyon 16's BOP pipe ram wilt be equipped with 3-112" x 6" variable bore rams. We wilt test this BOP stack with 3-112" and 4" test joints to 250 psi (low}13500 psi (high) per BP/AOGCC regs. 2) We will pull the 3-112" completion to the pre-RWO tubing cut depth. We will dress off the tubing stub, cut the 7" scab liner, mill up the 7" liner-top packer aU on 4" drill-pipe. This work is a!1 done over-balanced to the Cretaceous with 9.8 ppg NaCL brine. We'll stand back the 4" dP in the derrick. 3) We will set a wellhead test plug and run in lockdown screws. We will pressure test this test plug to 2000 psi and use it as a mechanical barrier to the Cretaceous. Well will be full of 9.8 ppg brine. 4) At this time we'll swap the 3-112" x 6" VBRs for 4-1/2" x 7" VBRs and test with a 5" and a 7" test joint to 250 psi {low)l3500 psi (high) per BP/AOGCC regs. 5) We will pick up 5" drillpipe to fish the T' scab liner, dress off the 7" stub, run and cement the new 7" scab liner. This liner will be PT'd to 3500 psi once the cement builds adequate compressive strength. 6) We will set a wellhead test plug and run in lockdown screws. We will pressure test this test plug to 2000 psi and use it as an additional mechanical barrier to the Cretaceous. Well will be full of 9.8 ppg brine. 7) The 4-1/2" x 7" VBRs will be swapped back to the 3-112" x 6" VBRs. Similar BOP testing as before. 8) 4" drill-pipe and 3-112" completion tubing will be the remaining pipe sizes run in this well and will be covered by the 3-1/2" x 6" VBRs. Please review this plan as an addendum to the plan attached in the Sundry application (#301-840) and, i# you approve, we will proceed as outlined above to address the 7" casing rams. Thank You. Dave Reem 4/2212008 ?~-:'{-:~'l tl L:O Schlumberger t:ï:'O' rJ 7 '~~ 11 ~u t....... ¡Ø.r'U~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth A;¿~~~~~-';J; ¡ 11 f H~-S!O: , Well Job # Log Description Date BL 13-31 A .:)05- ¡IoO 11162828 MEM JEWELRY & PRESSURE SURVEY 01/07/06 1 DS 18-03B ;JoS ~Of·,((, 11057071 SBHP SURVEY 12/02/05 1 NK.A3 rQ6/-CCJ ) 10987562 SBHP W/SPINNER PASSES 01/07/06 1 B-13A /C¡C¡ - 057 11183463 LEAK DETECTION LOG 01/28/06 1 DS 06-22A Iq.~,~c 5"7 N/A SENSAlMEM LDL 01/28/06 1 DS 11-26 /ß(ç.·~ 134- 11183462 INJECTION PROFILE 01/28/06 1 P1-09 J 9tt·,¡51- 11098756 PROD PROFILE W/DEFT & GHOST 01/30/06 1 L5-05 1f:.7-C(cC¡' 11058541 RST 11/11/05 1 Z-29 ¡eft -C(r.Ç" 11051081 RST 08/10/05 1 L5-09 I G¡C .- I ~ 11090725 RST 11/11/05 1 15-44 I'1Lt - I (() 11194155 RST 01/15/06 1 C-20B "';;01-1 [4- 11075913 MCNL 08/29/05 1 02-14A .QO;-') ~ I';¡S 11075901 MCNL 07/29/05 1 Z-21A Ro [- iO f 11076449 RST 06/30/05 1 F -27 A dOS-¡a4- 10928641 MCNL 09/01/05 1 MPH-15 .f)c6 -- 15'1 11076486 USIT 12/15/05 13-31A "QC5- Ißb 11133211 SCMT 12/23/05 WGI-04 I 7'1 - eSt.; 11183461 USIT 01/26/06 WGI-04 }')'1 -cst), 11211566 USIT 02/03/06 WGI-08 I <-«() - O¥=1 10987559 USIT 01/02/06 WGI-08 ¡C,o-c4Q 11058259 USIT 01/12/06 BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ð 2DGB ~GÅNNEL FE B ." = Date Delivered: .?-I <~? (00 I 02/09/06 NO. 3677 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhc2 3;;\:; Color CD ~' 1 1 1 1 1 1 1 1 1 1 1 1 1 1 '-" Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Received by tfþQOð ) GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9958 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 1/2/96 Field: Prudhoe Bay Floppy Well Job # Log Description Date BI_ RF Sepia DIR MWD Disk O.S. 02-24 ~c~,--'7 I PRODUCTION PROFILE 951127 1 1 D.S. 3-24 ~3- J~7~ PRODUCTION PROFILE . 951126 1 1 D.S. 5-17A c.~__~_ _ ~l PRODUCTION PROFILE 951 125 I 1 D.S. 6-16 ~'~-,-~_~' TDT-BORAX !951208 I 1 ,, D.S. 6-19 ~,-q- I ( ~ LEAK DETECTION 951 205 I 1 D,S. 6-21_ _ ~-/c~ PRODUCTION PROFILE 951208 1 1 D.S. 6-22A_ c~ 3 -..,.~'-7 PRODUCTION PROFILE 9511 28... I 1 D.S. 15-2__ ~-' ~-~' TDT. BORAX 951207 1 I .. ,, SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. PERMIT 93-057 9~-0~7~ ~ 93-057 93-057 93-057 93-057 93-057 93-057 93-057 93-057 93-057 93-057 93-057 bAT.e AOGCC individual Geological Materials T DATA_PLUS 5'/~7 407 {07 DAILY WELL OP DAILY WELL OP SURVEY SURVEY BHCA/GR BHP Well Inventory CNL/GR CNL/GR 9290-10667 DLL/MLL/AC/CN/ COMP DATE:05~09~93 COMP DATE: 11/16/93 04122/93-05/09/93 04/22/93~11/06/93 9300-9914 ANADRILL 9300-9914 ANADRILL ~L-~"9150-10667 9150-10667 9150-10667 9480-10523 GR/CL DLL/MLLiGR/SP/CA~ 9150-10667 PL'"-2435-2690 93-057 LEAK '~ 2000-3100 93-057 LEAK ~L 0-10550 93-057 PERF ~' 10090-10550 PERF ~' 9478-10487 PERF ~ 10465-10473 PERF ~/L 9570-10480 93-057 93-057 93-057 93-057 PERF ~A~ 10100-10460 93-057 SSTVD ~ 9150-10667 93-057 93-057 93-057 USIT(CEMENT) ~ 1245-10454 USIT(CORROSION) cL 1245-10454 VTL ~ 1500-4100 Page' 1 Date~ 01/i3/9~ RUN DATE._RECVD 1 08/'31/93 09/13/93 01,/21/94 09/13/93 01/21/94 01/21/94 09/13/93 1 06/28/93 1 06/28/93 1 06/28/93 ! 06/20/94 1 06/28/93 1 06/28/93 1 07/30/93 1 07/30/93 1 01/14/94 i 03/18/94 1 05/13/94 1 05/27/94 1 08/06/94 1 06/28/93 1 10/19/93 1 10/19/93 1 06/28/93 A©GCC Ind, ividuai Well Geological ~aterials Inventory Page · 2 Date · 01/13/95 PERMIT DATA T DATa_PLUS RUN DATE_RECVD Are dry ditch samples required? yes ~ And received? ~.. no Was the well cored'? yes ~ Analysis & description rece ? yes Are well tests required? Well is in compliance Initial _Received? yes ~o COMMENTS no GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9139 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 12/30/94 Field: Prudhoe Bay Floppy Well Log Description BL RR Sepia RF Sepia Mylar Disk D.S. 6-7 '7~'~' O,~---~ DUAL BURST TDT-P (7-13-94) D.S. 6-8 _'~ O-~-~7-, DUAL BURST TDT-P (6-15-94) ~ ~, ~ 1 D.S. 6-12A ~' ~-~ ? DUAL BURST TDT-P (5-29-93) (~ ~ ~ 1 D.S. 6-13 ~3 ~~ DUAL BURST TDT-P (4-27-93)~~ 1 D.S. 6-14A~ ~ ~ ,~ DUAL BURST TDT-P (5-7-93) 1 D.S. 6-14A ~-/~'~ ~ DUAL BURST TDT-P (4-8-94) ~ ~ ~~ 1 D.S. 6-14A/ CNTD (2-14-93) ~~~ ~ 1 D.S. 6-22A ~ ~.-~3~7 CNTD (5-22-94) ~ ~/ 1 D.S. 7-17 . -~G~ DUAL BURST TDT-P (8-5-94)~ "~~ ~ 1 D.S. 7-18 ~ ~- ~ CNTD (5-21-94) ~ ~ ~O 1 .. ~ ~ CNTD (5-10-93) ~p~( 1 ..s. K . D.S. 9-32 DUAL BURST TDT-P (7-7-94) ~¢'~ ~ 1 D.S. 9-37i~ ~/'~j -~1~ CNTG (8-27-94)~~.' ' ( ~ 1 D.S. 9-37i 0 /~7~ DUAL BURST TDT-P (8-31-94) ~,~~_ 1 D.S. 11-29i ~ ~~ CNTG (5-31-94)~n~~ 1 D.S. 11-29i ~ 7 ~~ DUAL BURST TDT-P (5-31-94) D.S. 11-33 ~~~ DUAL BURST TDT-P (8-25-94) ~z~ ~q/ P~~I~I~ 1 D.S. 12-26 ~~O~ CNTD (6-22-93) ~ ~~ '' ~ ~ L J V ~ U I .. D.S. 14-3 7 ~-~'~~_ CNTD (3-28-94) ~ ~' ~ v~,,~ ,, ,~.~-~ ,one I _ Please sign and retrun one copy DATE: AJaska Oil & Gas Cons. Commission Anchorage Page 3 STATE OF ALASKA ALASKA ~, .AND GAS CONSERVATION CO' ~ISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Pull tubing Alter casing Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 584' NSL, 985' WEL, Sec. 2, T10N, R14E, UM At top of productive interval 2382' NSL, 2725' EWL, Sec. 1, T10N, R14E, UM At effective depth At total depth 2382' NSL, 2891' EWL, Sec. 1, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 63 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-22A 9. Permit number/approval number 93-57 10. APl number 50 - 029-20806-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10681 feet 9236 feet Plugs(measured) PBTD Tagged @ 10550' MD (6/13/94) Effective depth' measured 10550 feet true vertical 9110 feet Junk(measured) Casing Length Size Cemented Conductor 79' 20" 1910 # Poleset Surface 2456' 13-3/8" 2200 sx Fondu & 400 sx PFC Production 9897' 9-5/8" 500 sx G & 300 sx PFC Liner 8533' 7" 543 cu ft G Measured depth True vertical depth 79' 79' 2519' 2519' 9297' 7915' 2148-10681' 2148-9236' Perforation depth: measured 10451-10502' true vertical 9016-9064' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, IPCT @ 9681' MD RECEIVED AUG 50 1994. (~i & 6as cons. commission Aritho:, ~ Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 9615' MD; camco TRDP-2A-SSSV @ 2107' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 50 148 0 1188 3478 0 Tubing Pressure 241 238 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas , Suspended Service 17. I herel~ certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor V ~ Form 10-404 Rev 06/15/88 1191/13 CC: KZ, JWP Date SUBMIT IN DUPLICATE ~ ' 6-22A DESCRIPTION OF WORK COMPLETED ACID PERFORATION BREAKDOWN TREATMENT & ADD PERFORATING 12/16/93: RIH & tagged PBTD at 10573' MD. I 2/20/93: A Fullbore Perforation Breakdown / Acid Stimulation Treatment was performed as follows: MIRU CTU & PT equipment to 7700 psi. Loaded the wellbore w/1% KCI Water, then pumped the treatment fluids through the open perforation interval located at: 10482 - 10502' MD (Z2) Ref. Log: BHCS 5/3/93. Pumped: a) 50 bbls 40# Crosslinked Gel @ 18 bpm, followed by b) 10 bbls Saturated Rock Salt Diverter Slug @ 8 bpm, followed by c) 25 bbls Xylene @ 10 bpm, followed by d) 75 bbls 15% HCl w/10% Xylene @ 10 bpm, followed by e) 380 bbls 1% KCI Water Overflush @ 2 - 12 bpm, followed by f) Shutdown. Rigged down. 3/1/94: Added Perforations: 10474 - 10482' MD (Z2) Ref. Log: BHCS 5/3/93 4/27/94: Added Perforations: 10466 10474' MD (Z2) Ref. Log: BHCS 5/3~93 5/1 4/94: Added Perforations: 10461 - 10466' MD (Z2) Ref. Log: BHCS 5/3/93 6/1 3/94: RIH & tagged PBTD at 10550' MD. 7/4/94: Added Perforations: 10451 - 10461' MD (Z2) Ref. Log: BHCS 5~3/93 RECEIVED AU0 5 0 199-/I, .~i?,ska Oi! & Gas Cons. Commission Returned well to production w/lift gas & obtained a valid production welltest. Anchor: sf~ ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: August 3, 1994 ARCO Cased Hole Finals Karla Zuspan/ATO- 1529 (907) 265-6547 Distribution P.O. Box 100360, A, ,~orage, AK .. Transmittal #: 94068 99510.~ ~, Well Log Date Tool Type Contractor Number (M-D-Y) 01-03 7-4-94 Leak Der 1 SCH 03-12 7-2-94 Inj Pmf 1 SCH 03-19 7-7-94 Prod Prof I SCH 03-25A 7-7-94 Perf Record 1 SCH 04-02 7-3-94 Leak Det 1 SCH *04-07 ST1 7-8-94 Perf Record 1 SCH 05-01 7-9-94 Tubing Cutter 1 SCH 05-11 7-9-94 Perf Record 1 SCH 06-11 7-2-94 Dual Burst TDT-P 1 SCH 06-21 7-1-94 Prod Prof 1 SCH 06-22A, 7-4-94 Perf Record 1 SCH 07-02 7-4-94 Prod Log 1 SCH 09-31A 7-8-94 G R/Collar 1 SCH 09-32 7-7-94 Dual Burst TDT-P 1 SCH 15-01 7-2-94 Prod Prof 1 SCH 16-02 7-5-94 Inj Prof 1 SCH 16-10 7-6-94 Inj Prof 1 SCH 16-24 7-3-94 Perf Record 1 SCH 17-07 7-5-94 Leak Det 1 SCH *The correct APl number for 04-07 ST1 is 50-029-20189-00. Number of Records: 19 '---.--I / ^ ? ~ . KaHa Zuspan Distribution: Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil ? Pleas y signing and returning ARCO Alaska, Inc. Is a Subsidiary of AtlanflcRIchfleldCompany ARCO Alaska, Inc. Date: June 14, 1994 P.O. Box 100360, Subject' From/Location' Telephone: To/Location- ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution i Well Log Date !Number (M-D-Y) 1-10A 3-18A 3-27 4-07ST 4-19 5-3A 6-10 6-16 7-4A 7-18 7-23 7-26 7-28 9-13 9-44 / ff 9-50 11-291 11-35 11-35 11-36 14-3 14-12 14-12 [ 14-20 4-34 16-13 17-12 Tool Type i Run, ,J Gas Cons. Commission ~age~ Contractor i 06-02-94 j/ USlT i 1 5" ]~ CNL 05-22-94 05-19-94 i-- CCL SCH 05-24-94 SCH !'/BAKER IBP REC 05-26-94 J/ PERFREC j~' INJ PROFILE SCH SCH i 5" 5" 5 ii 5" 5" 5" SCH 06-04-94 SCH 05-25-94 t~' USIT SCH O6-O4-94 SCH ?Production Profile i ' 1, 1" 5" , 06-02-94 !/ CCL ! 1 5" 06-03-94 i/ PERFREC 05-22-94 ~Patch Setting Rec 06-05-94 u ng Puncher 05-22-94 !/" CNL 05-21-94 k,,'/ CNL 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" ivProduction Profile 05-21-94 , 05-20-94 i / Pref Rec ~ 1 5" 05-21-94 t-' CNL ~ , 05-24-94 05-21-94 05-26-94 05-25-94 05-20-94 05-20-94 05-31-94 05-30-94 05-31-94 05-30-94 05-31-94 05-31-94 05-23-94 06-03-94 05-28-94 -/ CCL j 1, 1"5" v Prod Profile j 1, 5" 'v/' Perf Rec ! 1, 5" ,-' Bridge Plug ! 1, 5" ¢Production Profile i 1, 5" ,'Production Profile i 1, 1" 5" '/ CNL i 1 5" -- USlT TDT-¢ i CBT j / USIT --" CBT / CBT -- PERF REC j / GR LOG 'Production Profile ,-/' PERF REC PERF REC j Baker IBP Rec j 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1.5" 1 5" 1 5" 1 5" 05-28-94 I~'~ Leak Detection ~ 1, 1" 2" 5" 06-01-94 06-01-94 05-24-94 P' Pack Off Gas Lift j t/Tubing Puncher i 1, 5" 06-05-94 SCH SCH · SCH SCH SCH SCH SCH SCH j SCH SCH SCH SCH SCH SCH ., SCH SCH SCH SCH SCH SCH SOH SOH SCH SCH SCH SCH SCH SCH SCH 17-19 05-26-94 ]/ PERF REC ! 1, 5" SCH 18-1 06-04-94 1, 5" SCH 18-1 06-04-94 SCH ARCO Alasi(a, Inc. Is a Sui3sldiary of AflaztflcRIchfleldCompany ARCO Alaska, Inc. Date: May 24, 1994 P.O. Box 100360, horage, AK Transmittal #: 94040 99510 ,2 J Subject: ARCO Cased Hole Finals From/Location: Telephone: To/Location: ~--- i 6-22A i ~-. 7-3 ~1~ 7-3 ;~ ~ 7-23 7-23 ~"1-- 9-13 ~c(.- 9-26 RO- 9-42 c~O 9-47 11-36 ~- 12-8B John E. DeGrey/ATO-1529 (907) 263-4310 Distribution Well iLog Date Number i (M-D-Y) OWDW- ~ 4-29-94 1-9A i 5-14-94 Tool Type v// PITS ,/'/Perf Rec 1-20 i 5-7-94 v/ PerfRec 2-4 i 5-11-94 v/ Prod Prof 2-4 ! 5-11-94 ¢"' CNL 2-5 ! 5-7-94 ProdProf 2-5 ! 5-7-94 !~" CNL 2-18 i 5-8-94 ¢,/ ProdProf 2-20 ! 4-30-94 ,.,/× Prod Prof 2-20 i 5-13-94 ,/ CNL ; 4-4-94 3-19 :. iv,"~ Bridge Plug 3-29 i 5-3-94 iv"' Bridge Plug 3-32A i 5-9-94 ~[,z, JSIT (Cern & Corr). 3-32A ! 5-12-94 iv" PerfRec 4-5A ! 5-17-9441v' PerfRec 4-5A i 5-17-94 i V"~ USlT 5-6 i 4-30-94 l,/ Prod Prof ct~..-~.f.¢~ i 5-35 i 5-3-94 l v," TDT-P 6-10 t 4-5-94 v/' Leak Detect 6-11 f 5-14-94 v,PackerSet Bec 5-14-94 v' PerfRec 5-8-94 Prod Prof Run, Scale ! 5II 511 511 ! 5II 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" ! 5II SCH SCH SCH SCH SCH SCH ~ SCH ~ SCH SCH SCH : SCH : SCH SCH SCH SCH SCH I 5" SCH 1 5" SCH 1 5" 1 5" I 5" 5-7-04 Perf Rec I 5" 5-10-94 Set Rec I 5" 5-15-94 Rec 1 5" 5-16-94 1 5" 4-6-94 Perf Rec I 5" 5-15-94 ~ Leak Detect 1, 1" 2" 5-16-94 Packer Set Rec 1, 5" SCH SCH SCH SCH SCH SCH SCH SCH 5" SCH SCH 5-18-94 USIT 1, 5" SCH 5-4-94 ,,/ Prod Prof ~1 13-8 5-2-94 v~ Inj Prof ~-I z-'O', O 13-31 5-2-94 ! v" USIT ~'L(--tz-// ! 13-35 5-10-94 1,,/ USIT :~¢-1~ ! 14'7 i 5-13-94 t'¢Tubing Patch ~,I-f,~/'J ! 14-15 5-17-94 ~ CNL ~2..- t~L~ i 14-41 i 5-8-94 ~,P'Dual Burst TDT-P E2--ivy i 16-26 ~i 5-6-94 i~,"" Perf Eec EZ-l/[I { 17-19 5-12-94 ~ RedRec 1, 1" 5" SCH 1, 5" SCH: 1, 5" SCH 1, 5" SCH '~, 5" SCH 1, 5" SCH 1, 5" SCH 1' 5" SCH 1, 5'" SCH 1, 5" SCH ARCO Alast$, Inc.. Is a Subsiclar/of Allantlcl:lichfleld~ ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location' P.O. Box 100360, Anchorage, AK May 10, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Transmittal #: 94037 99510~ ~, Gas Cons. Distribution i Well {Number i OWDW- CO- ~_q 0 ---------i-~ NW .___~; OWDW- (Z) - 2.-'~q -- ' S E fcc~-~\°t~- -i- 1-2 -'¢O- 2_~, - __.----4-_ 1-4 -¢~-oct - ';- 1-17 ~ 2-139- - --'--'+ 1-24A ~-;z~ -----------~ 2-18 ~'~--~ ~ 2-25 c(t-!~c~ - =.-2-34 q, t- ~.~ ~ 2-35 i 3-17 -~/o2_ i 3-17 9%-t tZ ~--~/,: 3-21 [ 3-29 qq-lO< 4-29 4-44 4-44 4-45 i 4-45 4-46 5-10 ! 5-15A- i 5-15A 5-35 6-6 Log Date Tool Type Run, (M-D-Y) Scale · 04-30-94 Pump-in Temp I 1, 5" 04-30-94 Pump-in Temp 1, 5" 04-19-94 ~ CNL : 1, 5" 04-20-94 / TDT-P , 1 5" 04'07-94 ~ TDT-P ! 1 5" 04-08-94 -- Perf Record ~ 1 5" 04-16-94 .- Perf Record : 1 5" 04-17-94 ~ Prod Profile i 1 5" 04-18-94 .-- Brid~e Plu~ ! 1 5" 04-19-94 ~- Prod Lo9 -'1, "&5" · 04-12-94 /' Prod Profile : 1, 5" 04-27-94 -/Injection Profile . 1, 5" 04-19-94 ~ Perf Record : 1, 5" 04-20-94 ~' Perf Record i 1, 5" .. 04-14-94 ~ Leak Detect ~ 1, '- 1 "&2"&5" 04-29-94 i--lniection Profile : 1, 5" 04-12-94 ~ USlT 1 5" 04-14-94 ~'~ TDT-P ~ 1 5" 04-14-94 /' CNTG , -1 5" ,. 04-24-94 / CNTG 1 5" : 04-24-94 ~ TDT-P I 5" 04-22-94 ~' Perf Record 1 5" 04-13-94 ~ Leak Detect 1,2"&5" 04-25-94 !/CTU Prod Lo~ : 1 5" 04-26-94 / TDT-P 1 5" 04-16-94 -'~ Leak Detect I 5" · 04-17-94 ./ Completion : 1 5" Contractor Sch Sch Sch Sch Sch Sch Sch Sch , Sch : Sch Sch Sch Sch Sch Sch Sch Sch : Sch Sch Sch Sch , Sch Sch Sch Sch Sch Sch · Sch / h 6-14A, · i 6-14A !. 6-22A ~ 07-23 04-08-94 04-19-94 ~ TDT-P i ~-- Completion /Peri Record Sch 04-27-94 i Sch 04-13-94 ----Patch Record Sch ~ 07-23 04-16-94 ..-"Leak Detect Sch 12-09-93 04-18-94 04-12-94 7-24 7-24 - -~- 9-9 ** ~ 9-19 : TDT-P : -'~ Inj Profile · Patch --"Patch Record --'Inject Profile 1 5" 1 5" 1 5" 1, 2"&5" 1,5" 1~ 511 ! 5II 1~ 5II 1 511 04-23-94 04-20-94 Sch Sch Sch Sch Sch ARCO Alaska, inc. Is a Subsidiary of AtJantlcRIchfleldCompany ARCO Alaska, Inc. Date' Subject: From/Location: Telephone: To/Location: P.O. Box 100360, ~---horage, AK Mar 15,' 1994 Transmittal #: 94029 John E. DeGrey/ATO-1529 (907) 263-4310 Distribution i Well !Log Datei Tool Type i Run, Contractor · Number. (M-D-Y) Scale (~q.-ttc~ i 01-02 ! 2-26-94 t Prod/Spin/Temp/~5 1, 5" Schlumber -f~'-t[(¢ I 01-03 i 2'19'94 I Prod~BS/Temp~4.¢'~ 1,5" Schlumber I-5-1~ i 01-09 l 3-01-94 I Tubing Cutter ~ 1, 5" Schlumber ~r"~t$"{' ! 01-11 i 2-27-94 i Prod Prof/Spin ! 1, 5" Schlumber · ~5"~¢.5 ! 01-18 i 2-23-941 Leak DetectionI 1,1"&5" Schlumber (~7..- i 01-25 I 3-06-94 CNL ! 1, 5" Schlumber ~'z~-.-~L~ ..~3-20A i 2-17-94 Perf I 1, 5" Schlumber .,~03-20A i 3-03-94 Dual Burst 'W~'-~' 1, 5" Schlumber ~- !C>"J¢ i 03-32 i 2-26-94 Leak/Press/Tempi 1, 2" Schlumber; ~.?.-.- L<~ i 03-34A I 2-24-94 Prod/Press/Tempi 1, 2"&5" Schlumber 150-fl~5~% '~o-H'7-. i 04-01 I 2-19-94 Prod i 1, 5" Schlumber ~%-~\* ! 04-24 I 2-22-94 Prod i 1,5" Schlumberj [t. bbo"t\'2--~U~ ct\-t'~q ! 04-40 i 2-22-94 Perf i 1,5" Schlumber cFS-- ~_?'J¢i 04-46 i 2-16-94 Rope Perf I 1, 5" Schlumber (::;1 ~- t~ i/04-47 ! 2-18-94 v Perf , 1,5" Schlumber I0447 2-15-94 ." CBT-GR i 1, 5" Schlumber !~,04~47 I 2-15-94 v CET-GR i 1, 5" Schlumber -~'-~- 50 i 05-06 I 2-11-94 Perf I 1, 5" Schlumber l'~(~o- ct'5-- ~7.. I 05-14A~ 7-11-93 USIT/Cem&Corr ~"jl, 5" Schlumber ~5-'~ ! 05-15A i 05-15A ~ GND/GR-L.~C. 1, 5" Schlumber ~-- I('5 I 05-26 3-02-94 Dual Burst '['cr~,' 1, 5" Schlumber ~- 5'7.. ~/06-15 2-21-94 Prod I 1, 5" Schlumber t\06-15 2-22-94 Comp Neutron ~ 1, 5" Schlumber ~'5-5'~ i 06-22A i 3-01-94 Perf 1, 5" Schlumber ~-~5-- ~ 07-08 3-02-94 Prod~'~ ~ 1, 5" Schlumber ~(~- IL~ 07-23 3-07-94 Leak/SpinfTemp/~i~ 1, 5" Schlumber ~-~ 09-34 2-21-94 Tubing Cutter ~.~ 1, 5" Schlumber 8)~.- ;r'/.~11-02 2-10-94 Inj Prof/Scw, .~,. ~f~, 5" Schlumber ,~0- ¢~:::~ '_~/1-04 2-20-94 Tubincj Cutter ¢~ 1, 5" Schlumber 1-04 2-17-94 Tubing {>~ ~b~, 5" Schlumber ~/- ~"'+,~ t 11-7ST 3-06-94 InjProf/Spin~-.¢(¢._ 1,5" Schlumber F ll- 2-25-94 keak/Press/Temp I 1, 1"&5" Schlumber ~(~- ~r~ 16ST /Spin/~¢, ~--'l\ l~?.~.~ '1'est 3-08-94 Comp/l~l~tablei I~:o~----,'z.\(~1'5" oSChlumber I~(~-- q'cl ' ,11-17 i .2-20-94 Leak i 1, 5" Schlumber ?..i1-17 i 3-08-94 Prod 1 1,5" Schlumber iq"~rO°'-[~'5(~ Halliburton ~(o-i11% ! 111-23 I 8-09-91 TMD I 1, 5" ?.Cu¢ j/' 1-24A i 3-05-94 I Perf/GR/CCL I 1, 5" Schlumber M 1-24A l 2-22-94] Comp/Perf i 1, 5" Schlumber ARCO Alaska, Inc. Is a Subsidiary of Al~antlcRlchfi~clComlaany 12-01 ! 13-10 14"2B 14-2B 14-2B 14-2B 14-2B 14-2B .14-2B 14-24 14-28 14-34 16-08 17-21 PWDW 02-01 * Well 4-24 the 2-24-94 ~ Perf i 1 5" 1-16-94 ! CNL/GR ! 1, 2"&5" 1-16-94 i Sub-Sea i 1, 1"&2" 1-16-94 i BH~ Acoustilog/4~l, 2"&,,5" 116-94 ! DualLatedoCGR/,~ 1, 5 ! Seg Bond/GRfcC{L., 1, 5" 3-06-94 Prod i 1, 1"&5" ! 1-19-94 ;f 1-23-94 i PFC/GR/CCL .i 1, 5" PFC/Collar i 1, 5" 1-23-94 i 2-19-94 i Lea~, ! 1, 5" 3-05-94I Leak ! 1, 1"&5" 2-15-94 i Prod/Press/Temp! 1, 2"&5" i 3-07-94 I Prod Prof/Spin i 1, 2"&5" Schlumber i .~Co 0 - t Cc'lO0 Schlumber i ~ 2--~O Schlumber Schlumber i lo55o-(t Schlumber i (bS~,O-\ \~%Ut Schlumber i Io$ 5o --'tL ~d, Schlumber i I b"~¢o- Il. Schlumber ! Schlumber i ~b~7o-L t. ~o Schlumber i(O Schlumber i , Schlumber ~ ~'n / t-m~ ~r.¢~ Schlumber ! 'FE~ ~' I ¢'¢¢--~dm Schlumber Schlumberi 2-24-94 I Perf i 1, 2"&5" · Water Inj/FBS/Temp/~ 2-09-94 1, 5" correct APl # is 50-029-21508-00 Number of Records: eGrey Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon State of Alaska" Mobil ... Please acknowledge receipt by signing and returning a copy of transmittal. By: ~~v~ Date: RECEIVED PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page: 1 Date: 03/07/94 RUN DATE_RECVD 93-057 BHCA/GR 93-057 BHP 93-057 CNL/GR L 9150-10667 L 9150-10667 L 9150-10667 93-057 DLL/MLL/GR/SP/CA L 9150-10667 1 L 2435-2690 93-057 GR/CL 93-057 LEAK L 0-10550 1 93-057 LEAK L 2000-3100 1 93-057 93-057 PERF L 10090-10550 1 SSTVD L 9150-10667 1 USIT(CEMENT) L 1245-10454 1 93-057 93-057 USIT(CORROSION) L 1245-10454 1 93-057 VTL L 1500-4100 1 93-057 407 93-057 407 R3-057 93-057 DAILY WELL OP DAILY WELL OP R COMP DATE: 11/16/93 R COMP DATE:05/09/93 R 04/22/93-05/09/93 R 04/22/93-11/06/93 R 9300-9914 R3-057 SURVEY 93-057 SURVEY R3-057 5757 R 9300-9914 T 9290-10667 OH/FINALS 06/28/93 06/28/93 06/28/93 06/28/93 06/28/93 07/30/93 07/30/93 01/14/94 06/28/93 10/19/93 10/19/93 06/28/93 01/21/94 09/13/93 09/13/93 01/21/94 01/21/94 09/13/93 08/31/93 ~re dry ditch samples required? yes no And received? 4as the well cored? yes no Analysis & description received? %re well tests required? yes no Received? yes no Jell is in compliance Initial yes no yes no Comments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WI=LL COMPLI:::TION OR RI::CO P LI=TION REPORT AND LOG ~1. Status of Well Classilication of Service Well OIL [] GAS [] SI. JSPEI~DED [] ABANDONED [] SERVICE [].~.~, 2. Name of Operator 7. Permit Number~'~') _.._, ARCO Alaska, Inc. 93-57 3. Address 8. APl Number ' ,~t I P. O. Box 196612, Anchorage, Alaska 99519-6612 ! ~., '~.-:/,'~ ~C¥t~: 50- 029-20806-01 4. Location of well at surface ~i .-'r?,,~?;.%;r 9. Unit or Lease Name 584' NSL, 985' WEL, SEC. 02, TION, R14E '}:'iii~"-~i~:~!"-?~ i Prudhoe Bay Unit At Top Producing Interval~!~//~~!~'" i';! i .~ 10'6.22AWell Number ~' At Total Depth: .........._ ~_-¢Y~_~ ; Prudhoe Bay Field/Prudhoe Bay Pool 2382' NSL, 2891' EWL, SEC, 1, TION, R14E 5. Elevation in feet (indicate KB, DF. etc.) 6. Lease Designation and Sedal No. KBE = 63' ADL 28311 12. Date Spudded4/30/93 13. Date T.D. Reached5/2/93 14' Date C°mp" Susp' ~ Aband' 115' Water Depth' if °lfsh°re !16' N°' °f C°mpleti°nsl 1/16/93 N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDi 19. Directional Survey 120. Depth where SSSV sel J21. Thickness of Permafrost 10681' MD/9236' TVD 10592' MD/9151' TVD YES [] NO []I 2107' feet MD! 1900' (Approx.) 22. Type Electric or Othe~ Logs Run DLI_/GR/SP/SONIC/NEUTRON 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Surface 79' 30" 1910 # Poleset 13-3/8" 72# L-80 Surface 2519' 17-1/2" 2200 sx Foc~du/400 sx PF "C" 9-5/8" 4 7# L-80 Surface 9960' 12-1/4" 5oo sx Class "G"/300 sx PF "C" 7" 29# L-80 9118' 10681' 8-1/2" 358 cu fl Class "G" 7" 29# 13CR80 2143' 2462' 9-5/8" c ~ 7" 29# L-80 2462' 9087' 9-5/8"(~ 185 cu fl Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and ~5."~ TUBING RECORD interval, size and number) SIZE DEPTH SET(MD/ PACKER SET (MDI Gun DiameterMD 2-1/8" ~Df 3-1/2", L-80 9681' 2138'& 9615' 10482'-10502' 9045'-9064' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) 11/17/93 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE ~GAS-OIL RATIO TEST PERIOD ]~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence ol' oil, gas or water. Submit core chips. : Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sag Rvier 9977' 8560' Top Shublik 10013' 8594' Top Sadlerochit 10084' 8665' Zone 2 10265' 8836' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~~' Title DrillingEno_ineerSuoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. r-.- ~--,~ .-.~ ',.~ ~ '"~ ~ ~'-~ Item 28: If no cores taken, indicate "none". :,.,..: ~.., t,., !_. ! ~..." ~:~; Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: 6-22A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/23/93 02:00 SPUD: RELEASE: 11/05/93 09:00 OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 04/22/93 (1) TD:10675 PB:10626 MOVE RIG TO 6-22A MOVE RIG F/3-20A TO 6-22A MW: 0.0 04/23/93 (2) TD:10675 PB:10626 04/24/93 (3) TD:10675 PB:10626 04/25/93 (4) TD:10675 PB:10626 04/26/93 (5) TD:10675 PB:10626 04/27/93 (6) TD: 9567 PB: 0 04/28/93 ( 7) TD: 9567 PB: 0 PULL BPV W/LUBRICATOR MW: 0.0 MOVE RIG TO SHOP AREA, HANG BOP SCAFFOLDING IN CELLAR, REPLACE SECTION OF FLOWLINE W/SCREEN BOX TO IMPROVE METAL REMOVAL, MOVE RIG TO 6-22A, RAISE DERRICK & SPOT OVER WELL, PULL BPV W/LUBRICATOR WAIT ON TANDEM SPEAR MW: 0.0 TAKE ON SEAWATER, BULLHEAD TBG & LNR VOL.,REV CIRC, SET BPV, ND TREE, NU BOPE, TEST BOPE, RU BOP LUBRICATOR, PULL BPV, RU TO PULL TBG, BACK OUT LOCK DOWN STUDS, WAIT ON TRISTATE TO BRING TANDEM SPEAR, REINSTALL LOCK DOWN STUDS & PACKING PU 5" DP MW: 0.0 PU SPEAR & JARS, CATCH TBG BELOW TBG HGR, JAR ON TBG HGR, HGR CAME FREE, RD SPEAR, PULL 5-1/2" TBG, PU 2-7/8" STINGER, RIH W/5" DP WORK MULESHOE INTO PBR MW: 0.0 RIH W/2-7/8" STINGER & DP, ATTEMPT TO WORK MULESHOE INTO TBG STUB, NO SUCCESS, POH, PU OVERSHOT & JARS, RIH, OPEN JARS, WORKING SET INTO OVERSHOT WHEN SEAL ASSEM SHEARED, POH LD SEAL ASSEMB & FISHING TOOLS, PU MULESHOE, RIH CUT OUT OF 9-5/8" CSG MW: 0.0 KCl RIH W/MULESHOE, TAG FILL @ 10178', WASH TO 10824', CIRC, PUMP 36 BBLS SLURRY, DISPLACE TO BOTTOM, CEMENT PLUG, CALCULATED TO FILL TO TOP OF PBR, POH 12 STDS, REV CIRC, REV OUT TO 9517' (65' ABOVE PBR), CLEAN PITS, DISPLACE HOLE W/MUD, CIRC & COND WHILE WOC, RIH & TAG TOC @ 9565', SPOT 18 PPG PILL ON BOTTOM, POH LD 2-7/8" STINGER, RU SECTION MILL ASSEMB, RIH, MAKE INITIAL CUT IN 9-5/8" CASG @ 9297' CUT DRLG LINE MW: 9.7 KC1 MILL SECTION F/9297'-9331', CIRC HI-VIS SWEEP, JET FLOW LINE, MAKE CONNECTION, MILL SECTION F/9331'-9347', CIRC HI-VIS SWEEP, JET FLOW LINE, PUMP PILL, POH, L/D BHA, SLIP & CUT DRLG LINE WELL : 6-22A OPERATION: RIG : DOYON 16 PAGE: 2 04/29/93 (8) TD: 9567 PB: 9567 04/30/93 (9) TD: 9716' (9716) DRILLING CEMENT MW: 9.7 KC1 MADE UP MULE SHOE, RIH TO 9447. CIRC @ 9447. CEMENT AS PER STANDARD K.Oo PLUG PROGRAM, C.I.P. @ 1030 HRS. POH 12 STD TO 8326. SQUEEZE CEMENT AWAY. CIRC THHRU CHOKE HOLDING 1800 PSI ON CEMENT, L/D/ 39 JTS. DRILL PIPE. POH. CLEAN METAL FROM BOP AND FLOW LINE. BODY TEST BOP, INSTALL WEAR RING. MADE UP BIT 91 MADE UP K.O. BHA, TEST MWD. RIH FILL PIPE EVERY 10 STDS AND CIRC. CALIBRATE MWD TOOL. WASH DOWN TO CEMENT AT 9155, DRILL CMT. DRLG. DRLG CMT TO 9302' MW: 9.8 VIS: 60 DRLG 8-1/2" HOLE TO 9716'. 05/01/93 (10) TD: 9716' ( 0) 05/02/93 (11) TD:10510' ( 794) 05/03/93 (12) TD:10681' ( 171) 05/04/93 (13) TD:10681 PB: 9567 05/05/93 (14) TD:10681 PB: 9567 05/06/93 (15) TD:10681 PB:10592 RIH MW: 9.8 VIS: 0 DRILL & SURVEY 8-1/2" HOLE TO 9747', CBU @ 105 S?M @ 2450 PSI, SHORT TRIP, HOLE IN GOOD SHAPE, DRILL & SURVEY TO 9970', CBU, DROP SURVEY, PUMP PILL, POH FOR BIT & BHA CHG, L/D MWD MOTOR, RIH W/BHA 92, FILL PIPE @ 3649' & 9232' DRILLING MW:10.0 VIS: 52 RIH TO 9911', REAM F/9911'-9970', DRILL 8-1/2" HOLE TO 10510', MIX & PUMP HI-VIS SWEEP LOGGING OPEN HOLE MW:10.0 VIS: 47 DRILL 8-1/2" HOLE TO 10681' TD 8-1/2" HOLE, SHORT TRIP TO 9263', CBU, DROP SURVEY, PUMP PILL, POH F/OPEN HOLE LOGS, PULLED 8 STDS, 1ST 5 PULLED TIGHT, RIH TO BOTTOM, POH PIPE CAME SMOOTH TO SHOE, POH R/U ATLAS, RIH W/DLL/GR/SP/SONIC/NEUTRON, MILL LOG WELL F/10694' RIH W/7" LINER MW:10.0 KC1 POH W/OPEN HOLE LOGS, R/D ATLAS, RIH FOR CLEAN UP TRIP, NO FILL, CBU, POH, POH LAYING DOWN 30 JTS DP, L/D BHA, R/U TO RUN LINER, CHG OUT CR LINER FOR L-80, RIH W/LINER, M/U HGR, M/U DP RIH DRLG CMT @ 10584' MW:10.0 KC1 RIH W/LINER, CIRC & RECP LINER, CMT W/300 SX "G", POH F/CLEAN RUN, L/D RUNNING TOOL, RIH W/6" CLEAN OUT ASSEM, RIH TAG FIRM CMT @ 10525', DRLG FIRM CMT F/10525'-10584', LANDING COLLAR @ 10600' RIH W/ POLISH MILL. MW:10.0 KC1 DRLG CMT TO 10592' PBTD @ 10592' CBU. ATTEMPT TO TEST LNR. NO GO. CBU. POOH. RIHW/ 7~ SEAL ASS'Y & RTTS. SET @ 2457'. TEST CSG. OK. SET @ 3956'. TEST CSG. TEST FAILED. TEST CSG BELOW. OK. ISOLATE LEAK @ 2615'-2646' o POOH. L/D BHA. R/U ATLAS. RUN VERTILOG. RIH W/ POLISH MILL. WELL : 6-22A OPERATION: RIG : DOYON 16 PAGE: 3 05/07/93 (16) TD:10681 PB:10592 05/08/93 (17) TD:10681 PB:10592 05/09/93 (18) TD:10681 PB:10592 05/10/93 (19) TD:10681 PB:10592 POH W/PLUGGED BIT MW:10.0 KC1 RIH W/POLISH MILL, POLISH 7" LINER TIEBACK EXT., CBU, POH, OPERATION PLAN CHG TO RUNNING CSG PATCH INSTEAD OF TIEBACK, TEST BOPE, RIH W/SCRAPER, RIH TO 2650', WORK SCRAPER ACROSS PATCH SETTING INTERVAL, RIH TO 10592', DISPLACE TO FILTERED SEAWATER, POH, TO P/U MULE SHOE M/U 9-5/8" CSG PATCH MW: 0.0 Seawater FINISH POH-WET, CHG OUT BIT & BOTTOM COLLAR, RIH W/MULE SHOE TO 10592' (PBTD). DISPLACE WELL TO SEAWATER, L/D DP, CIRC DP, R/U ATLAS W/L, RIH & PERFORM TIE IN PASS W/GR/CCL, FLAG E-LINE CABLE @ 2430', P/U PATCH ASSEMB. RIG MOVING MW: 0.0 Seawater M/U HOMCO PATCH, POSTITION @ 2609', RIH W/ATLAS W/L TO FLAG @ 2430' FILL DP W/SEAWATER FOR ACTUATION OF HYDRAULIC · SETTING TOOL, SET 1ST 28' OF PATCH, L/D DP TO 2000', DISPLACE WELL TO DIESEL, L/D DP, TOP WELL W/DIESEL, LAND FMC HANGER, RILDS, INSTALL BPV, N/D BOPE, N/U FLANGE & TREE, INSTALL BLANKING PLUG, TEST TREE TO 5000 PSI MW: 0.0 Seawater 11/02/93 (20) TD:10681 PB:10469 TRIP IN, PICK UP DP MW: 8.5 Seawater MOVE IN, RU. RU BOPE, CHG RAMS. RU & TEST BOPE. RIH W/POLISH MILL. CIRC. TIH, PU DP. 11/03/93 (21) TD:10681 PB:10469 RUN LINER MW: 8.5 Seawater CONT RIH. CBU. CIRC. TO CLEAN CSG. POH. RIH W/LINER. 11/04/93 (22) TD:10681 PB:10623 11/05/93 (23) TD:10681 PB:10623 DISP WELL TO SEAWATER. MW: 8.5 Seawater RIH W/ 7" 13 CR LNR ON DP. CIRC. RIH W/ LNR. CIRC. PUMP 5 BBLS WATER, 33 BBLS CMT. DISP W/ SEAWATER. BUMP PLUG. SET LNR HGR W/ 2600 PSI. SET LNR TOP PKR W/ 4500 PSI. TEST CSG. OK. RELEASE F/ LNR. POOH. RIH W/ C/O ASS'Y. TAG CMT @ 9030'. DRLG CMT TO 9170'. RIH TO 10622'. CBU. TEST LNR LAP. OK. DISP WELL TO SEAWATER. EFS MW: 8.5 Seawater DISPCL WELL W/SW. TEST CSG. POH, LDDP. RU & RUN TBG COMP. PU TBG HGR. NOT ENOUGHT CLEARANCE TO INSTL BPV. HGR TO BE FITTED W/CORRECT X/O. EFS. WELL : 6-22A OPERATION: RIG : DOYON 16 PAGE: 4 11/06/93 (24) TD:10681 PB:10623 RIG RELEASED. MW: 8.5 Seawater M/U TBG HGR. LAND TBG. R/D OTIS. N/D BOPE. N/U TREE. TEST TREE. OK. F/P TREE. SET BPV. RIG RELEASED @ 21:00 HRS, 11/5/93. SIGNATURE: (drilling superintendent) DATE: INA L ICRL FILMED COItal' PRUI)~E BAY DF. ILLING WELL NAME ~Z: $-22A LOCATION, 1 ~LIDHOE BAY LOCATION 2 AK. D~TE: 5~D-AI~:-93 W~L ~B~: O ~ELL Hr. AD LC<ATIG~:~,]47;~,'-c'~,,,. ... O,f.~ AZI}TJTH FROM ROTARY TAB, LE TO T~-.G~T I.e.. 82,82 TIE [N ~INT(TIF') : I"{F..~StIRED D]3PTH 93<>0, O0 TRUE VERT D]ZT'TH 7918,Cx3. II~3Lt~T!~ 24,25. ~ZIMUTH 58.00 L~T!T®E(I¢,'-S) 1743,¢~, DEP~:TIJ~ < E/-W ) 3479, O0 MEASL~ED Zh'T~VAL V~RTICAL DEPTH D~PTH ft f~ f~ 9300,fP3 0°0 791B,00 974~,60 448,6 8340,Z9 9643,97 95,4 6431,.99' 9914,27 70,3 *****.******** ANADRIIL SLIRV£¥ CA~CU~ATIOfl.c. ,.*****: MINIMUM CURVATLR~ ~THOD TARGET STAT]ON AZIKILTH lATITUDE S~C~ION INCLfi, N/-S fc deg dea f~ 3669,~ 24,?.5 5~,OC 1743,00 3813,80 15,54 85-~4 1796,~ 38~9,94 16,37 &3,~ 1796,29 3859.33 15.92 91.41 i795,30 D~'AE99J~:E DISPLAC~EHT at ~2II~JTH ft ft dec 3479,00 3891,21 53,39 3617,58 4039,28 6~,~:~'" 36.43,75 4063,34 53,73 344.3,29 4,3~,_~ 66,85 DLS d~/ lOC, it 0,00 2,79 1,27 1,30 PA~E NO~ ****~****** ANA~q~I£L ************** ****~* MINIMUM CURVATURE MD TVD IH CH CUM, INC CO4G I RATE AZM C~2~qA~ CHC. TURN RAI'E CLOSUF~ TOOL FACE OLS DLSE? ft fr deg deg deg/100f~ deg deg deg/100fr f~ deg. de:/i¢Of~ deo/100fr**2 9300,0 7~£B-C<, 0.~ 0.00 0,~3 0,00 0.'~ 0,00 1274,50 0.00 0,~; 0,00 974~,6 8340,29 -8,71 -8,71 -1,94 27,34 27,3~ 6.09 13~,68 O,O0 2.7? 0,62 ?844,0 8431-99 0,83 -7,88 0,87 3,22 ~},56 3,38 1328,77 0,~ I,Z~ 1,,~ 9914.3 84~,52 -0,45 -8.~ -0,65 2,85 ~,41 4,06 1326,34 O,(X:, 1.20 0,04 ,':..::.'.: L: ?.':' 5'74£-,~,0 ;&,z..... gS43,~.1 ?~cz~?.., z,;.. 25,=,o~ ~,>_=t *-' i7%.,~__ ~z/"':,/J=.. .. 402,5,75 A7,.;,:: ..... 1,52 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 01-04-94 REFERENCE: ARCO CASED HOLE FINALS 5-12 5-26 5-31 6-12A 6-18 6-22A 9-03 Z3-38 14-02 14-04 14-23 Z4-3Z 15-03 Z6-07 16-30 17-13 18-33A 18-29A 11-23-93 Perf Record Io~O.q~_D ,Run 1, 11-20-93 Prod Profile ~l~lt~tslTe-~i~}6a6~Run 1, 11-27-93 Prod Profile [57,a ~,e,,~gi~(e%}~i~un 1, 11-19-93 Inj ~ofile/~,,~}~e~(~l ~c' R~ 1, 11-11-93 M~ Detect/GR/~Vl]Y~iCU R~ 1, 1~-~-~3 ~od ~oa]./~r~a g~i~.~ ~, 11-13-93 Perf Record l/~[~q'0 R~ 1, 11-20-93 SBT/GR/CCL }0~0-11~3 R~ 1, 11-20-93 GR/CCL ;!~-~ - ' 11-17-93 CNL(Ci4 j ~c ~.~k -~ ' ..... ;~- R~ 1, 11-13-93 Perf Record ei?~(: ~ic.,c ~ R~ 1, 11-27-93 ~od ~0file/-'~;~ '< ..... ~ '" 11-27-93 Perf Record '~,.!:3!: ~c~i~ R~ 1, 11-27-93 Perf Record :c,%~C:--~.~. i~ R~ 1, 11-28-93 Perf Record ~g ~"J '-'~: '?C R~ 1, ... 11-12-93 Perf Record ~:~¥{: ~ :.~-?:- R~ 1, 11-17-93 Packer Setting Rec R~ 1, 11-16-93 Perf Record lc~-:iG~l~$0 R~ 1, 11-2o-93 ~ Detect}~-c~i~i~iC~ R~ 1, 11-16-93 D~I B~st TDT-P/~ R~ 1, 11-15-93 TBG Cutter ~00 ~ ~00 R~ 1, 11-16-93 Packoff GLM ~ A~ ,6 R~ 1, 11-16-93 ~od ~ofile~l.'~)Yrc9/ ~ 1, 11-12-93 ~od ~ofile/~,h ~?[ W~I~MR~ 1, 11-13-93 ~od ~ofile/~ ]~l P~a~J&~ 1, 11-13-93 Perf Record [0~106i~ ' R~ 1, 11-20-93 Perf Re ord ~06-{0~5~ R~ 1, 11-17-93 USiT[~olori9 ~-9~V R~ 1, 11-23-93 Perf Record ~t~-qS~ R~ 1, PleaSe sign and return the attached copy as receipt of data. .ECE,VE Have A Nice Day! John E. DeGrey ATO-1529 5- 5- 5" 5" 5" 5" ;7.:7;' -',.:'~,~ ~ , 5" 5' 5" 5" 5" ,;'.~"c--~'3~ ~ 5" ~, ~ boO- qGqO 5" 5" Sch Sch Sch Sch Sch Sch Sch Atlas Atlas Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch APP ROVED ~'vc'~o'~.¢s~ C°~e' ~s~ 94004 · # CENTRAL FILES # CHEVRON # BPX # STATE OF .ALASKA # PHILLIPS # AN08 GEOLOGY # EXXON # MOBIL * The corrected APl# for 18-29A is 50-029-22316-01 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 7, 1993 Mr. Roger K. Mochnick Chief, Ground Water Section U. S. Environmental Protection Agency (EPA) Region X 1200 Sixth Avenue Seattle, WA 98101 ,3OMM IYNG ASST STAT TECH ~YAT TECH FILE Dear Mr. Mochnick: Subject: Well Information Area of Review for the Pad 3 Class I UIC Wells Prudhoe Bay Unit - Eastern Operating Area (PBU-EOA) As requested in your November 13, 1992 correspondence to ARCO Alaska, Inc. (ARCO), we are providing additional data on sidetrack/new well drilling in the area of review for the subject wells. Enclosed for your information and records are documents detailing the current status of 2 wells which have been sidetracked within the Pad 3 area of review since our last submittal of information to EPA. Submittal of this data was delayed due to minor well difficulties which required additional diagnosis and analysis on our part prior to deeming these wells satisfactorily completed. On a related topic, ARCO has completed its examination of the Pad 3 Class I UIC permits to determine if other issues may need clarification and/or modification as part of the effort to modify these permits to adjust the frequency of mechanical integrity testing. We would like to meet with you and your staff in the next few weeks to discuss this permit modification in greater detail. We will contact your staff to make arrangements for this meeting. If you have any questions, do not hesitate to call me at (907) 265-6136. Sincerely, Mark Major Permit Director Prudhoe Bay/Lisburne Health, Safety, Environmental, & Training Enclosures cc: David Johnston, AOGCC - Anchorage (w/ enclosures) Keri Schur, EPA - Seattle (w/ enclosures) Alaska Utt& Gas GoBs. O0mmiss~on Anchorage ARCO Alaska. Inc. is a Subsidiary ot AllanlicRichfieldCompany r.r. ::= .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO, MMISSION WELL COMPLETIO OR RECOMP LETIOR REPORT AND LOG F 1. Stazus of Well OIL ~ GAS [] SUSPE:hDED 1-1 ABANDONED [] SERVICE [] Classi!icalion of Servi. ce Well 2. Name of Operalor ARCO Alaska. Inc. 7. Permit Number 93-57 4. Locaimn ol well at surlace 584'NSL, 985' WEL, SEC. 02, TION, R14E At Top Producing Inlerval 2382'NSL, 2725' EWL, SEC. 1, TION, R14E At Total Depth 2382'NSL, 2891'EWL, SEC, 1, TION, R14E 5. Elevation in leer (inaicate KB, DF. etc.) 16. Lease Designation and Sedai No. KBE = 63' I ADL 28311 12. Dale Spuac~ed il3. Dnle T.D. Reached 114. Date Comp., Susp. or Abancl. 4/30/93 I 5/2/93 I 5/9/93 I 10681' MD/9236' TVD I 10592' MD/9151' T1/D ! YES [] NO [] I 22. Type Eleclric or Other Logs Run I DLL/GR/SP/SONIC/NEUTRON 3. Address 8. APl Number P. 0. Box 196612, Anchorac/e, Alaska 99519-6612 so-029-20806.01 ,, g. Unit or Lense Name Prudhoe Bay Unit 10. Well Number 6-22A 11. Field and Pool '~ Prudhoe Bay Field/Prodhoe Bay Pool 15. WaiSt' Deplh, il ollshore 16. No. ol Complelions N/A feel MSL Zero Depth where SSSV sei J2..1, Thickness ol Permalrost None ~eet MD ! 1900'(Approx.) i 23. CASING. LINER AND CEMENTING RECORD SEI3'lqG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SEE CEMBVT1NG RECORD AMOUI',FF R. JM.ED 20" 91.5~ H-40 Surface 79' 30' 1910 # Poleset 13-3/8' 72# 1.80 Surface 2519' 17-1/2' 22oo .~x Fondu/400 sx PF 'C' 9-5/8" 47# L-80 Surface 9960' 12-1/4" 500 sx ~ 'G'/300 sx PF 'C,' 7" 29# L-80 9118' 10681' 8-1/2' 358 cuft Class "G' · 25. TUB I',lG RECORD 24. Periorations open to Production (MD~.TVD of Top and Bottom and interval, size and number) None SiZE DEPTH SET fMD) 4-1/2', 13CR80 8' PACKER SET (MD) None 26. ACID, FRACTURE, CEMENT SQUFFTF ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED I 127. PRODUCTION ~ Dale First Production Not on ¢roduction I Mell'mcl ol OperatiOn (FtOW, ng, gas lilt. etc.) N/A ~Ad. CUt. ATED 244..IOUR RATE OIL-BBL OIL-BBL ~F GAS-MCF WATER.SBL tCHOKE SIZE IGAS-OIL RATIO WATER-BBL rlL GRAVITY-APl (CDC'r) Date ol Test Flow Tubing Press. Hours Tested Casing Pressure 28. CORE DATA Briel aescnpHon ol lithology, porosity, lractures, apparenl ail)s, and presence c~ oil, gas or water. Submml core c~os. RECEIVED DEC - 9 1993 Alaska UII & Gas Cons. CommJssior: Anchorage Submil in duplicale Form 10-407 Rev. 7-1.80 COh/T1NUED ON REVERSE SIDE i 2g. 30, GEOI.CXD,~ M,ARKEF:~S ..,~!A4ATION TESTS , t ~E Include interval lesled, pressure data, all fluids recovered and gravity, MEAS. DEPT~ TRUE VERT. DEPTH GOR, and time ol each phase. ) = Top Sag Rv/er 9977' 8560' Top Shub//k 10013' 8594' i Top Sadlerochit 10084' 8663' Zone 2 10265' 8836' i31. LIST OF A'TTACHMENTS ,, i 32. I hereDy certily that the loregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 : If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, 1nc. P.O.Bo~ 100:360 Anchorage, Alaska 99~10 DATE: 10-8-93 77-S7 1-11 ~-- 1~.7 6-21 7~7~ ** 9-9 ~?~t ~1-25 ~7~7 11-28 x -i ~3-~ J4-24 e lS-ao q~-?~ 16-31 8-29-93 Prod Proflle/~z-~l~le~,~ Run 1, 5" I~al0~'~ch 8-29-93 Prod Proflle/~aa/~z~.~5 R~m 1, 5" ~u0~-t~0Sch 8-29-93 ~od ~offie (~{¢a~s R~ L 5" ~w ~Sch ~0~ 9-7-93 ~j ~offie & --~ ~*'~ 9-7-93 ~j ~offie & ~a~xc/~' t ~ l, 5"~o-t~ch R- - 5" 9-3-93 ~a~- Sch t-~.o 9-8-93 ~j ~offie & Static ~7~-~ ~Sch 9-3-93 ~ml B~t T~P R~ 1, 5"~c~-~v Sch 9-4-93 Pe~Record I~-Iio~ R~ 1,5" Sch 9-4-93 Pe~ Record ~-~ R~ 1,5" Sch 9-10-93 ~ucflon~al~l~e R~ 1, 1"&5" ~ Schq~ 8-31-93 USIT (Cement) Color R~m 1, 5"~ IZ~~ch)~ 8-31-93 USIT (~sion) ~lor R~ 1, 5"t~i~q Sch 9-2-93 ~ Brat ~P R~ 1, 5"~~-- Sch~%~ 9-10-93 ~od ~offie~a[~~ R~ 1, 5'~ Sch I~co-~s~ 8-29-93 ~od ~offiel~tT~~ R~ 1, 5" ~.o-~ Sch ~a 9-5-93 C~ l~ ~l~~ R~ 1, 5" Sch 9-12-93 ~P ~%~ R~m 2, 5" Sch 8-30-93 ~ Detectl~~ R~ 1, 2" t00-~5 Sch 9-10-93 Pe~ Record ~zz~-t~ R~ 1,5" Sch 9-3-93 GR/CCL (TCP ~e-~) R~ 1, 5" ~- - ~~z~o 9-5-93 ~ ~/ae~ai~[~/ea~ R~ 1, 1"&5" ~- Sch ~t ~5 9-7-93 ~~ ~-i~ R~ 1,1"&5" Sch 9-4-93 Pe~ Record %~a~o R~ 1,5" Sch RECEIVED BY__~ ,~ Have A Nice Dayl Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # EXXON # MOBIL the attached copy as receipt of data. Trans# 93109 # PtHLLIPS PB WELL FILES # BPX # STATE OF ALASKA The correct top logged interval for this log is 12,900 feet. The correct top logged tnter~l for this log is 10,400 feet. INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 09/15/1993 PAGE: 1 93-057 BHC/AC/GR 93-057 BHP 93-057 CNL/GR 93-057 DLL/}4LL/GR/SP 93-057 GR/COLLAR 93 -057 LEAK 93-057 LEAK 93-057 SSTVD 93-057 VTL 93-057 407 93-057 SURVEY 93-057 Are well tests required? 5757 Yes RUN1,2&5" 9150-10667 RUN1,2&5" 9150-10667 RUN1,2&5" 9150-10667 RUN1,2&5" 9150-10667 RUN 1, 5" 2435-2690 RUN1,2" 2000-3100 RUN1,5" 0.0-10550 RUNI,I&2" 9150-10667 RUN 1, 5" 1500-4100 COMP DATE:05/09/93 ANADRILL 9290-10667 OH/FINALS Was well cored? Yes ~o//.. yes, was the core analysis & description received? Ye~_No/~ If Are dry ditch samples required? Yes //~ WELL IS ON COMPLIANCE.INI~TIA~L ~~\~~ COMMENTS: ARCO ,~l_~Sk_~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-1 0-93 REFERENCE: ARCO DIRECTIONAL DATA c~_ ~-'2. 3-18A 4-24-93 Electronic Multi-Shot Survey Job~~ Sperry q% ~'~ 3-20A 4-14-93 Electronic Multi-Shot Survey Job~~ Sperry ~%-~ 5o3A 5-26-93 MWD Directional Survey Aha ct~/~ 5-14A 6-26-93 MWD Directional Survey Ana c/%.q-~ 5-15A 6-26-93 MWD DireCtional Survey Ana ~-5'7 6-22A 4-30-93 MWD Directional Survey Ana ~-q0 18-29A 4-26-93 MWD Directional Survey Aha q2- !~5 AGI-3 4-14-93 MWD Directional Survey Job~1163 BHI c~._ 1~0 AGI4 4-14-93 MWD Directional Survey Job~l168 BHI ~-27 AGI-7 4-28-93 MWD Directional Survey' Job~ 1185 Teleco /AGI-9 3-17-93 MWD Directional Survey Job#1195-450 BHI c~5 <~,AGI-9 5-8-93 MWD Directional Survey' Job~ll~ BHI Please sign and return the attached copy as receipt of datih ,ECEIV, - % Have A Nice Day! Sonya Wallace ' APPROVED ~J ATO- 1529 Trans# 9310~" CENTRAL FILES CHEVRON D&M # CLINT CHAPMAN # EXXON MARATHON MOBIL # PB WELL ~ R&D #BPX # ST. OF AIL (2 COPIES) # LUCILLE JOHNSTON STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG !1. Stalus of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED r-I SERVICE [] 2. Name of Operator 7. Permit Number ¢~..~.~'..~ ARCO Alaska, Inc. 93-57')"~'-~ _ 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 9951~:6612 5o- 029-20806-01 4. Location of well at surface ~ ~L~'~-~ ~~' 9. Unit or Lease Name 584' NSL, 9~' WEL, SEC. 02, TION, R14~~~L.A'~ ~c "[J ] ~~[ 10.Prudh°ewell NumberBay Unit~ At To- Producing Interval ~ VERIFIED ~ ~,~~/~ 6-22A 2382'NSL, 2725' EWL, SEC. 1, TION, R14E ~"~ ~ ~~ [-~~~-. 11. Field and P~I At Total Depth Prudhoe Bay Field/Prudhoe Bay Pool 2382'NSL, 2891'EWL, SEC. 1, TION, R14E 5. Elevation in feet (indicia KB, DF, etc.) ~6. Le~e Designation and Serial No. KBE = 63' ~ ADL 28311 12. Date Spudded 13. D~e T.D. Re~d 14. Date Comp., Susp. ~ Aband. J15. Water Depth, if offshore ~16. No. of Completions 4/30/93 5/2/93 5/9/93~ N/A feet MSL ~ Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 10681' MD/9236' ~D 10592' MD/9151' ~D ~ ~ ~ D~ None feet MD~ 1900' (Approx.) 22. Type Electric or Other Logs Run DL~GR/SP/SONIC/NEUTRON 23. CASI~, LINER AND CEMENTI~ R~O~ SE~ING DEp~ MD CASING SIZE ~. PER ~. G~DE TOP ~OM ~LE SIZE C~~ R~ORD A~UNT ~LLED 20" 91.~ H-40 Surface 79' 30" 1910 · Poleset 13-3/8" 72~ L-80 Surface 2519' 17-1/2" 2200 sx Fmd~400 sx PF "C" 9-5/8" 4 7~ L-80 Surface 9960' 12-1/4" ~o sx Class "G'Y300 sx PF 'C" 7" 29~ L-80 9118' 10681' 8-1/2" 358 cu ~ Class "G" 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. ~BINGR~ORD interval, size and number) SIZE DEP~SET(MD~ PACKER SET None 4-1/2", 13CR80 8' None 26. ACID, F~O~RE, CEMENT ~UE~, ~C. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL ~ 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on production N/A _ Date of Test !Hours Tested PROD~TIONFOR OIL-BBL GAS-MCF WATER-BBL C~KES~E JGAS-OIL RATIO TEST PERIOD ~ I Flow Tubing ~Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL ~OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CQRE DATA Brief description of ,ithology, porosity, fracture, apparent dips, and pr~ence of oil, gas or wW.~i~e~¢i~ ~~ ~-- ~.~ r.~,, ~ . ~ ,, A ch0rage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS ~-~RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sag Rvier 9977' 8560' Top Shublik 10013' 8594' Top Sadlerochit 10084' 8663' Zone 2 10265' 8836' 31. LIST OF A'I-I'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,/ Title Drilling Engineer Supervisor Dale ¢° t~1_ ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: 6-22A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/23/93 02:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 04/22/93 ( 1) TD:10675 PB:10626 MOVE RIG TO 6-22A MOVE RIG F/3-20A TO 6-22A MW: 8.5 Seawater 04/23/93 ( 2) TD:10675 PB:10626 04/24/93 ( 3) TD:10675 PB:10626 04/25/93 ( 4) TD:10675 PB:10626 04/26/93 ( 5) TD:10675 PB:10626 04/27/93 ( 6) TD: 9567 PB: 0 04/28/93 (7) TD: 9567 PB: 0 PULL BPV W/LUBRICATOR MW: 8.5 Seawater MOVE RIG TO SHOP AREA, HANG BOP SCAFFOLDING IN CELLAR, REPLACE SECTION OF FLOWLINE W/SCREEN BOX TO IMPROVE METAL REMOVAL, MOVE RIG TO 6-22A, RAISE DERRICK & SPOT OVER WELL, PULL BPV W/LUBRICATOR WAIT ON TANDEM SPEAR MW: 8.5 Seawater TAKE ON SEAWATER, BULLHEAD TBG & LNR VOL.,REV CIRC, SET BPV, ND TREE, NU BOPE, TEST BOPE, RU BOP LUBRICATOR, PULL BPV, RU TO PULL TBG, BACK OUT LOCK DOWN STUDS, WAIT ON TRISTATE TO BRING TANDEM SPEAR, REINSTALL LOCK DOWN STUDS & PACKING PU 5" DP MW: 8.5 Seawater PU SPEAR & JARS, CATCH TBG BELOW TBG HGR, JAR ON TBG HGR, HGR CAME FREE, RD SPEAR, PULL 5-1/2" TBG, PU 2-7/8" STINGER, RIH W/5" DP WORK MULESHOE INTO PBR MW: 8.5 Seawater RIH W/2-7/8" STINGER & DP, ATTEMPT TO WORK MULESHOE INTO TBG STUB, NO SUCCESS, POH, PU OVERSHOT & JARS, RIH, OPEN JARS, WORKING SET INTO OVERSHOT WHEN SEAL ASSEM SHEARED, POH LD SEAL ASSEMB & FISHING TOOLS, PU MULESHOE, RIH CUT OUT OF 9-5/8" CSG MW: 0.0 KC1 RIH W/MULESHOE, TAG FILL @ 10178', WASH TO 10824', CIRC, PUMP 36 BBLS SLURRY, DISPLACE TO BOTTOM, CEMENT PLUG, CALCULATED TO FILL TO TOP OF PBR, POH 12 STDS, REV CIRC, REV OUT TO 9517' (65' ABOVE PBR), CLEAN PITS, DISPLACE HOLE W/MUD, CIRC & COND WHILE WOC, RIH & TAG TOC @ 9565', SPOT 18 PPG PILL ON BOTTOM, POH LD 2-7/8" STINGER, RU SECTION MILL ASSEMB, RIH, MAKE INITIAL CUT IN 9-5/8" CASG @ 9297' CUT DRLG LINE MW: 9.7 KC1 MILL SECTION F/9297'-9331', CIRC HI-VIS SWEEP, JET FLOW LINE, MAKE CONNECTION, MILL SECTION F/9331'-9347', CIRC HI-VIS SWEEP, JET FLOW LINE, PUMP PILL, POH, L/D BHA, SLIP & CUT DRLG LINE WELL : 6-22A OPERATION: RIG : DOYON 16 PAGE: 2 04/29/93 ( 8) TD: 9567 PB: 9567 04/30/93 (9) TD: 9716' ( 0) DRILLING CEMENT MW: 9.7 KC1 MADE UP MULE SHOE, RIH TO 9447. CIRC @ 9447. CEMENT AS PER STANDARD K.O. PLUG PROGRAM, C.I.P. @ 1030 HRS. POH 12 STD TO 8326. SQUEEZE CEMENT AWAY. CIRC THHRU CHOKE HOLDING 1800 PSI ON CEMENT, L/D/ 39 JTS. DRILL PIPE. POH. CLEAN METAL FROM BOP AND FLOW LINE. BODY TEST BOP, INSTALL WEAR RING. MADE UP BIT #1 MADE UP K.O. BHA, TEST MWD. RIH FILL PIPE EVERY 10 STDS AND CIRC. CALIBRATE MWD TOOL. WASH DOWN TO CEMENT AT 9155, DRILL CMT. DRLG. DRLG CMT TO 9302' MW: 9.8 VIS: 60 DRLG 8-1/2" HOLE TO 9716'. 05/01/93 (10) TD: 9716' ( 0) 05/02/93 (11) TD:10510' ( 794) 05/03/93 (12) TD:10681' ( 171) 05/04/93 (13) TD:10681 PB: 9567 05/05/93 (14) TD:10681 PB: 9567 05/06/93 (15) TD:10681 PB:10592 RIH MW: 9.8 VIS: 0 DRILL & SURVEY 8-1/2" HOLE TO 9747', CBU @ 105 SPM @ 2450 PSI, SHORT TRIP, HOLE IN GOOD SHAPE, DRILL & SURVEY TO 9970', CBU, DROP SURVEY, PUMP PILL, POH FOR BIT & BHA CHG, L/D MWD MOTOR, RIH W/BHA #2, FILL PIPE @ 3649' & 9232' DRILLING MW:10.0 VIS: 52 RIH TO 9911', REAM F/9911'-9970', DRILL 8-1/2" HOLE TO 10510' MIX & PUMP HI-VIS SWEEP l LOGGING OPEN HOLE MW:10.0 VIS: 47 DRILL 8-1/2" HOLE TO 10681' TD 8-1/2" HOLE, SHORT TRIP TO 9263', CBU, DROP SURVEY, PUMP PILL, POH F/OPEN HOLE LOGS, PULLED 8 STDS, 1ST 5 PULLED TIGHT, RIH TO BOTTOM, POH PIPE CAME SMOOTH TO SHOE, POH R/U ATLAS, RIH W/DLL/GR/SP/SONIC/NEUTRON, MILL LOG WELL F/10694' RIH W/7" LINER MW:10.0 KC1 POH W/OPEN HOLE LOGS, R/D ATLAS, RIH FOR CLEAN UP TRIP, NO FILL, CBU, POH, POH LAYING DOWN 30 JTS DP, L/D BHA, R/U TO RUN LINER, CHG OUT CR LINER FOR L-80, RIH W/LINER, M/U HGR, M/U DP RIH DRLG CMT @ 10584' MW:10.0 KC1 RIH W/LINER, CIRC & RECP LINER, CMT W/300 SX "G", POH F/CLEAN RUN, L/D RUNNING TOOL, RIH W/6" CLEAN OUT ASSEM, RIH TAG FIRM CMT @ 10525', DRLG FIRM CMT F/10525'-10584', LANDING COLLAR @ 10600' RIH W/ POLISH MILL. MW:10.0 KC1 DRLG CMT TO 10592' PBTD @ 10592'. CBU. ATTEMPT TO TEST LNR. NO GO. CBU. POOH. RIHW/ 7" SEAL ASS'Y & RTTS. SET ~@ -24§7'. TEST CSG. OK. SET @ 3956' TEST CSG. TEST FAILED. TEST CSG BELOW. OK. ISOLATE LEAK @ 2615'-2646' POOH. L/D BHA. R/U ATLAS. RUN VERTILOG. RIH W/ POLISH MILL. WELL : 6-22A OPERATION: RIG : DOYON 16 PAGE: 3 05/07/93 (16) TD: 10681 PB: 10592 05/08/93 (17) TD:10681 ?B:10592 05/09/93 (18) TD:10681 PB:10592 05/10/93 (19) TD:10681 PB:10592 POH W/PLUGGED BIT MW:10.0 KC1 RIH W/POLISH MILL, POLISH 7" LINER TIEBACK EXT., CBU, POH, OPERATION PLAN CHG TO RUNNING CSG PATCH INSTEAD OF TIEBACK, TEST BOPE, RIH W/SCRAPER, RIH TO 2650', WORK SCRAPER ACROSS PATCH SETTING INTERVAL, RIH TO 10592', DISPLACE TO FILTERED SEAWATER, POH, TO P/U MULE SHOE M/U 9-5/8" CSG PATCH MW: 0.0 Seawater FINISH POH-WET, CHG OUT BIT & BOTTOM COLLAR, RIH W/MULE SHOE TO 10592' (PBTD). DISPLACE WELL TO SEAWATER, L/D DP, CIRC DP, R/U ATLAS W/L, RIH & PERFORM TIE IN PASS W/GR/CCL, FLAG E-LINE CABLE @ 2430', P/U PATCH ASSEMB. RIG MOVING MW: 0.0 Seawater M/U HOMCO PATCH, POSTITION @ 2609', RIH W/ATLAS W/L TO FLAG @ 2430', FILL DP W/SEAWATER FOR ACTUATION OF HYDRAULIC SETTING TOOL, SET lST 28' OF PATCH, L/D DP TO 2000', DISPLACE WELL TO DIESEL, L/D DP, TOP WELL W/DIESEL, LAND FMC HANGER, RILDS, INSTALL BPV, N/D BOPE, N/U FLANGE & TREE, INSTALL BLANKING PLUG, TEST TREE TO 5000 PSI MW: 0.0 Seawater SIGNATURE: (drilling superintendent) DATE: {mchorar!:~ ****~*** At'~DRILL ~******** ********* SCHLUMB£~R ********** *********************************************************** COMPANY PRU~]H BAY I)F. ILLIN~ WELL ~ DS 6-~A LOCATION 1 ~i[C.~mH3E BAY LOCATION 2 Al<, MAGTI~tC DI~CLINA. TION W~L NUMBS: 0 WELL HHAD LO<ATION: ~T(N/-S) 0.(~ DEP(H/-W) AZIMURq.{ FROM E~3T~Y ?~L£ TO T~.G~ IS 82,82 TI~ IN POIITF(TIP) : MEASURED DHPTH IT~jE {~RT D~PTH INCLINATION AZI~]TH LATIlq]DE(~L/-S) DEPARTUR]3(E/-W) 7918.00 24.~ 1743.0{, 3479,00 ICI OFILMED 9843,97 -~ / I -_i,'TERVAL YERTIC~L 448,6 70,3 84%",52 SL~J~~ CALCULA?IONS MINtl~d~l CURVATLR~: ~THOD ~w,.,-w~ AZIML?H ~TI~DE D~ARTUR£ DISPLAC~N? at ~ZI~TH E/-S ~/-W ft ft ft I743,0() 3479,00 3891,21 53,39 1796, .923617,5~ 4037,2.A .~,57 1798.29 ~43,75 )~04063'34 .~_._..___~ DLS d~/ 2,7Cl 1,27 ANADRILL 2401 ~ ,~ABAR LOOP ANCHORAGE, ALASKA 99507 (907) 349-6575 Prudhoe Bay Unit P.O. Box 196612 Anchorage,AK 99519-6612 Attention: Mike Cook Dear Mike, I have compiled a summary of Anadrill's performance on 6-22A. .SERVICES PROVIDED Anadrill's DSW Service, comprised of our directional package with Downhole Weight on Bit (DWOB) and Downhole Torque (DTOR), was picked up on 28-MAR-93. It was used to drill cement to the kick off point at 9302' and then to kick off the well and drill to the end of the build/turn section. MWD and the directional assembly were layed down at 9970' on 01-May-93. OPERATING STATISTICS · Total operating time (over 200 gpm flowrate) was 39.3 hours over one MWD run with a drilled footage of 668 feet. No MWD failures occurred. JOB PERFORMANCE Calculated formation strengths (FORS) and dimensionless torque (TD) generated by the DWOB/DTOR supported Mechanical Efficiency Log (MEL) program indicated we were off of the plug and into formation after sliding 26' feet. At this point DWOB was increased with a corresponding increase in rate of penetration. Data used to make this pick were somewhat ambiguous due to abnormally high drag encountered in the cased hole section. The first valid survey was taken at approximately 40 feet of departure from the original well bore. Anadrill appreciates the opportunity to provide MWD services on the Prudhoe Bay Sidetrack Drilling Project and looks forward to continued participation. Thank you,. Dan Bordelon Manager Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 SEPTEMBER 7, 1993 MARION SLOAN BP EXPLORATION ALASKA INC. P O BOX 196612 ANCHORAGE, ALASKA 99518-6612 RE: 93-0002 PRUDHOE BAY UNIT AGI-5 COMPLETION REPORT' 93-0009 PRUDHOE BAY UNIT AGI-6 COMPLETION REPORT 93-0082 PRUDHOE BAY UNIT DS5-14A COMPLETION REPORT 93-0047 PRUDHOE BAY UNIT DS3-20A COMPLETION REPORT 93-0057 PRUDHOE BAY UNIT DS6-22A COMPLETION REPORT DEAR MARION SLOAN, OUR FILES INDICATE THAT ARCO ALASKA IS THE OPERATOR OF THE REFERENCED WELLS. THESE WELLS HAVE REPORTED PRODUCTION TO US AND WE HAVE NOT RECEIVED THE APPROPRIATE COMPLETION REPORTS (407 FORMS) TO DATE. MAY AND JUNES MONTHLY PRODUCTION ~'~REPORTS INDICATE THAT THESE WELLS ARE GAS INJECTORS AND OIL PRODUCERS FOR YEAR 1993. WE HAVE NO PAPER WORK SHOWING THE COMPLETIONS FOR THE MENTIONED WELLS. I AM FORWARDING THIS LETTER AS A RECORD FOR YOU AND ME. THANKS FOR YOUR QUICK RESPONSE ON THESE REPORTS. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: q'5~ 57_6.22A~a~q~oq 5-3-93 4' ~25', 930~ ARCO MAGNETIC TAPE(S) WITH LISTINGS I)LL/]~CS/~ I)LL/MLLI~ICNi~ CDN/CDR DLL/M~/AC/GR 0~- DLL/MLL/aC/GR Run I Joi~93196 8ch Run I Job~5949 Atlas Run I Job~93127 8ch Run I .Job~~.01 Atlas I~m I Job~5915.01 Atlas Please sign and return _~he attached co~y as receipt of data. RECEIVED .~Y ~_~'~ Have A Nice Day! Sonya Wallace ATO- 1529 RECEIVED AUG 3 1 1993 ///A~ska Oil & Gas Cons. Commission APPR OVED_~/~///~ Anchorage Trans# 93087 CENTRAL FILES (CH) CHEVRON D&M # BOB ~AS (OH/GCT) # EXXON _MARATHON MOBIL # PHILLIPS PB WEI~ FILF. S R&D # BPX # STATE OF ALAS~ TEXACO This is a revised tape, please replace one previously issued. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 1-28 ~'~'~ ~-18-93 3-25A ~?'~3 6-17-93 3-31 } V-?z 6-16-93 3-32 ~ ~/-~? 6-15-93 3-33 $ ¥~ ~o 6-16-93 4-8 ?~-~o 6-11-93 5-14 ??-~ 6-12-93 6-22A ~ ~.~6-6-93 6-22A - 6-10-93 7-25 ~-y ~, 6-6-93 9-44 f D -~ z~6_6_93 11-18 f~-t*z6-7_93 14-6 7 ~'- ~6-8-93 14-8 7~--(,,7 6-10-93 14-13 ~'id 16-13-93 14-15 fF~ 6-8-93 16-4A tz'l(~ 6-9-93 16-17 ~- zz~6-14-93 16-31 ~-~i 6-7-93 17-4 ~0~ 6-14-93 AGI-5 ~-~-6-13-93 AGI-6 ~-d~ 6-14-93 AGI-7~ _ _6-8-93 AGI-7 ~ ~ ~-16-15-93 AGI-7 6-17-93 Prod Profile Completion Record Plug Setting Record Plug Setting Record Plug Setting Record Perf Record TBG Cutter Record Leak Detect Leak Detect Perf Record Perf Record Production Log PITS/Le~ k Detect Leak Detect Inj Profile Completion Record Prod Profile Perf Record Production Log Completion Record Completion Record Completion Record Perf Record R~m 1, 5" R'~]n 1, 5" R~m 1, 5" Run 1, 5" R!!n 1, 5" R~n 1, 5" Run 1, 5" R-n I 2" Run 1, 5" R~n 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 2"&5" R~]n 1, 5" R~m 1, 5" R~n 1, 1"&5" Run 1, 2"&5" R~m 1, 5" R~!n 1, 5" R-n 1, 5" Run 1, 5" R-n 1, 5" Run 1, 5" R-n 1, 5" Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch AGI-8 ~3'$ ~6-9-93 CuR/CCL R~,n 1, 5" Sch AGI-9~ a ~,~ 6-9-93 CuR/CCL Run 1, 5" Sch AGI-91 -~ ' 6-17-93 Pe~ Record R~ 1, 5" Sch ~e~e s~ ~d ret~~~che~~ ~ceipt ~ Sonya W~ace ~ APPROVED ~~ ~ (~/~ ~ C~ON ~ C~T C~~¢d~ -- ~ B~ t ~ON -- ~ ~ STA~ OF ~~ ~ MOB~ '~/~ * ~e ~~t~ ~ ~32 ~ ~21141~. ' ~e c~ct ~n ~e ~r ~ 1~ ~ ~2~ ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 6-9-93 REFERENCE: ARCO 5*3-93 SSTVD 5-3-93 DLL/M~-T-/GR/$P/Cal 5-3-93 BH proffie 5-2-93 SSTVD 5-2-93 BHCA/GR 5-2-95 CNL/GR ].2/24-3]./92 MWm. DPR/GR ].2/24-3]./92 MW~:. DPR/GR ]./].].-].,5/93 MWD: ]:)PR/aR ]./].].-].,'5/93 MWm. DPR/C,R 1/24-29/93 - MWD: DPR/GR ]./2429/93 ~ I)PR/GR Run 1, 1"&2' Run 1, 2'&~' Run 1, 2'&~' Run 1, 2'&~' Rim 1,1"&2' Run 1, Runs ~, 2'&~ R~ ~7, ~'&~ R~ ~7, ~'&~~ Please sign =.~d re~,u-n the attached copy as re_ cetpt of data~ .,c,IVE Have A Nice Day! Sonya Wallace ATO- 1529 APPROVED _~ Tr~ns# 9306~-~v-~ .... Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Teleco Teleco Teleco Teleco Teleco Teleco # CENTRAL FILES # CHEVRON #D&M # CLINT CHAPMAN # EXXON M~RATHON # MOBIL PHILLIPS PB WELL ~ R&D BPI[ STATE OF ALAS~ TEXACO ARCO Alask~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: REFERENCE: ~-_~~.~'1-7 3-33 14-22A L7-21 LB-gA ~8-16A 6-9-93 5-6-93 Static Pressure Run 5-8-93 Prod Profile Run 5-10-93 Production Run 5-11-93 CBT/New TfKl/Jewelry Run 5-10-93 Leak Detect/Spin/Temp/Press l~m 5-4-93 USIT (Cement & Corrosion) (Color) Run 5-3-93 InJ Profile/Spin/Temp/Press Run 5-2-93 Inj Profile/PITS Run 4-24-93 Leak Detect/Spin/Temp/Press Run 5-7-93 Dual Burst/TDT-P (Borax) Run 5-6-93 Vertilog Run 5-8-93 GR/Collar Run 5-6-93 Per/Record Run 5-7-93 GR/(X~ l~m 5-10-93 CNL l~m 5-11-93 Leak Detect l~m 5-7-93 Perf Record Run 5-9-93 TDT-P (Borax) Run 5-3-93 Leak Detect/Spin/Temp/Press Run 5-3-93 Per/Record l~_m 5-4-93 Production Run 5-5-93 CCL/Per/Record l~m 5-8-93 SBT/GR/CCL l~_m l~m l~m qT.~l~_~ a~4 5-,-93 ~/CCL (Color) ~~GI-5 5-10-93 GR/CCL (Color) - ~~tGI4 5-10-93 GR/CCL {color) ~,~3~AG~,.S 5-3-93 Sm'/G~CC:L Please sign and return the attached copy as receipt of data. RECEIVED BY_.~_~.~~~X3 Sonya Walhce ~, ~ ~"~- APPROVED ArO- 5 - % ..... # EXXON # MOBIL 1, ~' Sch 1, ~' Sch 1, ~' Sch 1, ~' Sch 1, ~' & iY' Sch 1, ~' Sch L ~' Sch 1, [Y' Sch 2,/~' Sch 1, tY' Sch 1. ~' Atlas 1, iY' Atlas 1, IY' Sch 1, IY' Sch 1, ~' Sch 1, 2' & fY' Sch 1, [~' Sch L ~' Sch L lY' Sch 1, IY' Sch 1, ~' Sch 1, ~' Atlas 1, 1~' Atlas 1, [~' Sch 1, IY' Sch 1, IY' Sch 1. 2' & [~' Atlas # STATE OF ALAS~ ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 April 16, 1993 Bill Kirton Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 6-22A ARCO Alaska, Inc. Permit No. 93-57 Sur. Loc. 584'NSL, 985'WEL, Sec. 02, T10N, R14E, UM Btmnhole Loc. 2401'NSL, 2388'WEL, Sec. 01, T10N, R14E, UM Dear Mr. Kirton: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Si · Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] RedrilllTIIlb. Type of well. Exploratory[] Stratigraphic Testl-I Development OilE] Re-Entry [] Deepen131 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 62'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0, Box 19~612. Anchoraoe. Alaska 99519-6612 ADL 28311 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(a,,,, 20 ^^c 2s.o25> 584' NSL, 985' WEL, SEC. 02, TION, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2326' NSL, 2784' WEL, SEC. 01, TION, R14E 6-22A U-630610 At total depth 9. Approximate spud date Amount 2401' NSL, 2388' WEL, SEC. 01, TION, R14E 4/19/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD andTVD) property line ADL 28329-2388' f e e t No Close approach fee t 2560 10696' MD/9253' TVDf e e t 16. To be completed for deviated wells 17. Anticipated pressure (s,~ 20 AAC 2S.035 Kickoff depth 93oofeet Maximum hole anDle 4~'.~ o Maximum surface 3330psig At total depth (TVD) 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# NTSO NSCC 300' 9150'~ 7783' 9450' 8066' 8-1/2" 7" 29# 13CR NSCC 1246' 9450' 8066' 10696' 9253' 270 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. ;!i-'"' ;~''''' !i Present well condition summary Total depth: measured 10680'feet Plugs (measured) :. ,-;,_~ ... q , ,~ true vertical 9255'feet ' :" '~ ~' ' Effective depth: measured 10626'feet Junk (measured) .':'~;~';~:;, ;;,il.. ,!;. u~::: ..,,.~,~,,. true vertical 9203'feet Casing Length Size Cemented Measured depth True Vertical depth Structur~.l Conductor 79' 20" 1910 # Poleset 79' 79' Surface 2445' 13-3/8" 2200 sx Fondu & 2519' 2519' Intermediate 400 sx PF "C" Production 9886' 9-5/8" 5oo sx "G"/3oo sx "c" 9960' 8552' Liner 1027' 7" 350 sx Class "G" 10675' 9250' Perforation depth: measured 10450'-10466', 10466'-10474' true vertical 9030'-9046'~ 9046'-9054' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed reportl-I 20 AAC 25.050 requirements l'q 21. I hereby ceeify that the foregoing is true and correct to the best of my knowledge Si~ned ~ "~~ Title Drilling Engineer Supervisor Date /z,~/'~¢~ Commission Use Only Permit Number IAPI numberli'lAppr°~a'l date ._ ~¢-'~ ISee cover letter ~',~-,.~7 150' °'2"¢'- ~-~ °c'4::~ ~-O / ,~-//~ * Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes '~ No Directional survey requ~rea ~ Yes [] No Required working pressure for DOPE [] 2M; F'I3M; ~SM; l--I10M; F'I15M; Other: Origina, ~ ned by order of'/' --~'~/~ Approved by · ..:i ~ By Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit i~ icate DS 6-22A Drilling Permit Information Obiective: - The goal of this sidetrack is to move the bottom hole location 130' to the south east. The current well is producing with a high gas cut due to a hole in the liner. Scope: 1. Cut the 5-1/2" tubing at +_9660'. Kill and freeze protect the well. Prepare the surface facilities for a rig move. 2. MIRU the Doyon 16 workover rig. 3. Kill the well, nipple up the BOPE, and pull the 5-1/2" tubing out of the well. 4. Lay a cement plug across the current perforations from PBTD to at least 100' above the top perforation with coiled tubing. Tag the TOC with slickline. 5. Pressure test the 9-5/8" casing to 3500 psi. If needed, identify the source and extent of the leak. ... 6. Mill a 50' window-in the 9-5/8" at 9300'. Lay a cement plug across the window. The window is 248' above the production packer. 7. Drill an 8-1/2" hole to 10,696' MD. Run open hole logs. 8. Run and cement the 7" L-80/CR-80 liner. Test the liner and 9-5/8" casing to 3500 psi. 9. Run the 4-1/2" 13CR completion with a 7" packer. Timing: Doyon 16 will move to the DS 6-22 after completing the 3-20A sidetrack. The DS 6-22 sidetrack should be completed in about 13 days. Work should begin about April 19, 1993. David Crockett Page 1 April 1, 1993 DS 6-22A Drilling Permit Information Well- DS 6-22A Redrill PBU EOA APl No,- 50-029-20806-00 Location' Surface' 584 FSL 985 FEL Tie in: 2326 FSL 2784 FEL Target: 2389 FSL 2484 FEL BHL' 2401 FSL 2388 FEL Original KB 62' AMSL S02 T10N R14E UM S0I T10N R14E UM S01 T10N R14E UM S01 T10N R14E UM @ 9300' MD @ 10,348' MD @ 10,696' MD Estimated Start: April 19, 1993 Ooerating days to complete: 13 Contractor: Doyon Rig #16 Directional; Kickoff @ 9300' with a 4°/100' build rate. Drop from 24.25° to 16.12° and turn from 58.0° to 82.8°. Maximum angle 47.5° @ 6800' MD. No close approaches. TVD (BKB) KOP 7918' Sag River 8553' Shublik 8585' Sadlerochit 8657' TD 9253' MD (BKB) Mud Weight 9300' 9.7 9967'- 9.7 10,001' 9.7 10,076' 9.7 10,696' 9.7 Open Hole Logs: GR/Resistivity/Neutron/Density Mud Program- The mud program will be typical of the sidetracking program and will consist of a 9.7 - 9.8 ppg Biozan polymer/KCI water based mud. DEPTH (TVD) KOP' to TD' DENSITY PV YP INT 10 MIN FL OIL SOLIDS MUD (PPG~ (CPI (#/Ff'). GEL GEL cc/30min (%) (%) TYPI~ 9.7 i0 10 5 7 8 0 5 Water to to- to to to to to to Base 9.8 16 18 10 15 5 0 7 Mud David Crockett Page 2 April 1, 1993 DS 6-22A Drilling Permit Information MUD WEIGHT CALCULATIONS /WELL CONTROL: Est. Pore Press. Sag River: 4200 psi/8479' _ss TVD. Est. Pore Press. Sadlerochit: 3550 psi/8800' ss TVD. Mud Wt.' 8-1/2" Hole = 9.7-ppg. Overbalance Sag River: 113 psi. Overbalance Top Sadlerochit: 925 .psi Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4300 psi at 8800'-I-VDss based upon original reservoir pressure. Maximum possible surface pressure is 3300 psi based upon a gas column to surface from 8800' TVDss with no oil column. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: 6;A$1NG 7" 29# NT-80 NSCC 7" 29# OR-80 NSCC DEPTH · -,9150'- 9450' MD 9450 - 10,696' MD BURST COLLAPSE TENSILE 8160 psi 7030 psi 676 klbs 8160 psi 7030 psi 676 klbs CEMENT CALCULATIONS: Measured Depth' 9150'MD (Hanger) - 10,696'MD (Shoe) Basis' 40% open hole excess, 40' shoe joint, 150' liner lap and 150' excess above liner with DP. Total Cement Vol' 270 sxs of Class G blend @ 1.18 ft3/sx TUBING DETAILS: 4-1/2" 12.6# 13CR NSCT David Crockett Page 3 April 1, 1993 DS 6-22A Drilling Permit Information SUMMARY PROCEDURE 1. Rig work: MIRU Doyon 16. Pull the BPV with a lubricator. Circulate and kill the well. , Set a two way check valve. ND the tree and NU the BOPE. Test the BOP's to 5000 psi. Pull the TWC with a lubricator. 3. Pull the 5-1/2" tubing. , RIH with 2-7/8" tubing by 5" driillpipe. Lay a cement plug staring from PBTD. Leave the top of cement at least 100' above the top pedoration but below the packer. The top of cement should be somewhere between 10,286' and 9679' ME). . With AOGCC representative on location to witness operation, run in with slickline and confirm that top of cement is at least 100' above the top perforation. , If the cement is tagged more than 100' below the tubing tail, set a magna-range plug in the tubing tail to prevent future fluid swap-out when laying a kick-off plug. . RIH with a 9-5/8" section mill. Spot an 18 ppg on top of the packer. Mill a 50' window in the casing at 9300'. . Spot a 170 sx balanced cement plug from 9450' - 9100' across the window. Squeeze the cement into the window. 9. Test the 9-5/8" packoff to 5000 psi. Replace the packoff if needed. 10. Run an 8-1/2" steerable drilling assembly. Dress off the cement plug to 5' below the window. Drill to 10,696' MD 9253' TVD. Lay down the MWD and PDM once the well is aligned with the target. 11. 12. Rig up Atlas and run a GR/Resistivity/Neutron/Sonic log. Run the 7" 29# CR-80/L-80 Nscc liner. Cement the liner with 270 sxs of CIG blend cement. This includes 40% excess in the open hole. Set the liner hanger and liner top packer. Reverse out the excess cement. 13. Clean out the liner to PBTD. Test the liner and 9-5/8" to 3500 psi. Displace the mud with clean inhibited sea water. 14. Run the 4-1/2" 12.6# 13CR NSCT completion with a 7" permanent packer. Position the packer at 9550' 15. Set the TWC. ND the BOPE and NU the tree. Test the tree to 5000 psi. 16. Pull the TWO with a lubricator. Set the packer and test the tubing to 4000 psi. Test the packer to 3500 psi. Shear out the RP valve and freeze protect the well. 17. Set the BPV. Release the rig. Anticipated BHP' 7.7 ppg EMW Drilling fluid: 9.7 ppg Workover fluid' 8.5 ppg David Crockett Page 4 April 1, 1993 DS 6-22A Drilling Permit Information MUD & SOLIDS CONTROL EQUIPMENT _ 1- 1- 1- 1- 1- 1- 2- 4- 1- 1- _ Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Tdflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 HP agitators Abcor 10 HP agitators 40' bbls trip tank Recording drilling fluid pit level indicator with both visual andaudio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console David Crockett Page 5 April 1, 1993 LAND DIRECTIONAL DRILLING, COrporate Office 11!~ East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLZNG well ......... : DS 6-22A Field ........ : PRUD~OE BAY DRILL SITE 6 Computation,,: MINIMUM CURV~,TUP, E Units ........ : FEET Prepared ..... : Secticn at.,.: ~ elevation,: LEG,5~ DESCRIPTION Surface ...... : 583 FSL 98~ FEL S02 T10N R14E UM Tie-in ....... : 2326 FSL 2784 FEL S01 T!0N RI~E UM Target ....... : 2389 FSL 2484 FEL $0~ T10N R14E D~ B~L .......... : 23~9 FfL 2484 PEL S01 T10N R!4E UM X ASP ZON~ ~ Y 685997.66 5941182,36 689432.08 5943011.36 689730.00 5943082.00 689825.43 59~3096,48 PROPOSED WELL PR0~iLE 04/07/93 82,82 74.00 ft STATION M-T~%~ INCLN VERT-D~PTHS iDENTIFICATION DEPTH .~NGLE BKB SUB-S TIE-IN 9300 24.25 7912 78~4 9400 21,10 8010 7936 9500 %8.27 8105 8031 END OF CLTRVE 9591 %6.12 8192 8~18 PIJT RIVER 9755 !6.12 8349 8275 SAG RIVER 9967 16.12 8553 8479 SFK/BLIK 10001 16.12 8585 8511 S~LEROCHIT Z4/4B 10076 1~.12 8657 8583 S~DLEROC/~iT Z4A/X-P3k 10186 ~6,12 8763 S~LEROCHIT Z3 10272 16,!2 8846 8772 SECT DIST 3670 3705 3738 3765 3810 3869 3878 3899 3930 3954 SADLEROCHIT Z2/2C 10348 16.12 8919 8845 3975 TARGET 10348 i6,12 @9!9 8845 3975 G0C 10637 16.!2 9004 8930 3999 SA/DLEROC/~T Z2A/RObZE 10652 16,I2 9019 8945 HOT 104B9 16.12 9054 8980 4014 OOWC 10546 16.12 9109 9035 OWC 105~6 16,12 ~109 ~035 ~030 SADLEROC/qIT E1B/LR 1057~. 16,!2 9138 9064 KAVIK !064~ 16.12 9203 9129 4057 TD 10696 16,i2 9253 9179 4071 DIRECTION AZIMUTH 58.00 64.42 72.84 82. 82 82.82 REL - COORD I NATES FROM - WELLHED~D 1743 N 3479 1762 N 3513 1774 N 3544 1780 N 3570 1786 I~ 3615 82,82 1793 ~ 3674 82.82 ~794 N 3683 82.82 1797 ~ 3704 82.82 1800 N 3734 82,82 1803 ~ 3758 82,82 1806 N 3779 E 82.@2 ~806 N 3739 E 82.82 1809 N 3803 E 82.82 18!0 N 3807 E 82.82 1811 N 3817 E 82-82 1813 ~ 3833 E ~2.82 !@13 }~ 3833 E 82.82 iB14 N 3842 E 82,82 1816 N 3860 E 82.82 1818 N 3875 ~ DL/ <TIE 4.0 4.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 O.0 0.0 0,0 C~-D~ (c) 92 DS622A Ri,~3 8:43 ~5~ 2) Narker idantific~tJon TIE-IN ENO OF CURVE TARGET MD BKB $ECTN INCLN 9300 79J8 3670 24.25 §5§~ 8~9~ 3765 J6.J2 10348 89~9 S§75 ~6.~2 ~059G 9253 4071' t6.~2 ~K 3500 4200- ~800i PRUDH DS 5-22A (P1) VERTICAL SECTION VZEW Section TVO Scale.' Pep Sca2e ' ~Opa~n ..... 82.82 J inch = J200 feet ~ inch = 1200 feet 04/07/93 5000~ .......... . ~T,D, ~- .~' 9ooo- -~' 0 % -,- : -:1_--_-:2 ~800 2400 3000 3600 ~200 7200 7800 Section Departure PRUDHOE'BAY · _ ~ . ~D 8K8 SEOTN iNOLN g~o0 ?928 3670 24,25 g5g~ 8292 3765 16.12 '10348 Bg~9 3975 ~6.12 }0695 g253 z07! DRZLL'ING ._ i ..__ , DS 6-22A. (Pi) VERTICAL SECTION VIEW Section at: 82.82 TVD Scale.' ~ inch : 200 feet Dep Scale' 1 inch : 200 feet , j , ~j wn 04/07/93 , ~ ' ....... -~¢, ~ -~ - I I ~- -,~,~- ~ ~ ......................... I ~,~z4~N=¢,~¢ ; :mr t .......... '~ - ~ , -- - J - ~ - - = j ..... · m .... .. ~ .... ~.. ~... ;~ ..... -o,~:~5 ........... ~ .......... ~--<-- ~ i I 8g00- 9000 ~207 930u ..... 9~00 3400 3,500 3600 2?00 H800 3g--oo ,4000 .4',00 ,4200 4300 4400 4500 4800 4700 4800 Sect ~.on Departure lC) 5_2 ~S6_~2/,. ¢--,i .,43 §; ,48 ~ 2] ................. PLAN VIEN CLOSURE ' 4280 feet at Azimuth 64.86 DECLINATIB,I.- 30.00 E !SCALE ' J inch : 500 feet DtANN. ' 04/07/93 ....... PRUDHoE' BAY-D-RiLL' NG ':" ii,l, i i , _I i I __ i illi I ii ii I _L_ ~ i I i i _ II I I II I I i Nar'kef I[Ienti ricat ion MD NIS E/h' A] TIE-IN 9300 1743 N 3479 E BI END OF cum'e 959:1. J780 N 3570 E C) TARGEI t(~34B ~8OfJ N 377§ E 0] lO i0696 i818 N 3875 E m _1,.I JI I I ___ ifAflGEr 2 iO Fl' F1AI IUS i ~ ..... ~,. , I- - .................... ¢- I ......................... ~c~ .._. , ~.. ~ ........................... ~, '-~ - . , ~ % ~. ~, .... :r;s~ _ ~_~ ............. I ..... .... LS' ~ ......... ,. _ . . : ..- , I ~ i ................... L__~_ ~ ........................ ~ ...... , ....... 250 O 250 500 750 rOOD 1 ~50 ~500 ~ 750 2001 ~250 2500 2750 3000 32'50 3500 3750 ~OO0 42.50 <- ~EST' EASf-> ii m m idi'-r~--y_J ~' -- / '2 :2,.) F_.jD. F_.jI~21 I-I~Ul'l I~l%r-I-I I !_ldlN,D .VII";. ,L)I'~.I.L. Li.I"II2 I U I'-'D.I~ l-I',lU11 INI-I-I%,D I-- · DID PRUBHOE DS 6-22A PLAN VTEW CLOSURE ..... : 4280 feet at Azimuth 84.86 30. O0 E ~ inch = ~00 feet 04/07/93 DECLZNATION.' SCALE ' DRAWN · 3400 3450 Icj ~2 ~S622A ~ .43 BAY DRILLING Marker Identification NO N/S E/H A) TIE-IN §30o 1742 N 3479 ~1 ENoo~ CURVE ~59~ ~780 ~ 35?0 ¢) TAR6ET 10348 1806 3779 6) TD J0696 I818 N 3875 3500 AN 2J 3550 3¢00 3550 3700 2750 3800 3850 EAST -> 3950 4000 4050 4100 TOTAL P. 06 DOYON 16 13 5/8" 5,000 psi Stack 10.15 4.5 r/ RKB ! ! HYDRIL J ! , I 5.02 Variable 3.5" x 6" Pipe Ram Variable 4.5" x 7L" Pipe Ram 1.02 1.80 2.35 0.25 GROUND LEVEL MUD CROSS ! Blind Ram TBG SPOOL TBG SPOOL BASE FLG , , i FLO ,R 12.40 15.40 17.60 20.7O 24.85 25.10 6.22ACMT.XLS State: Well: Field:. State Permit Il: DS6-22A Prudhoe Day 9~-57 Engineer: Work Sheet: Date: Ce.n~t Vo/un~e C. alculation~ 4/14/93 Casing T.~:e C.a~ing Size Casing Length Hole Diameter Cement- Sacks Cement- Yield Cement- Cubic It Cement- Cubic fl Cement- Sacks Cement- Yield Cement- Cubic P: Cement- Cubic tI Cement- Sacks -Inches - Feet -Inches ti1 111 111 111 112 112 112 112 113 Cement- Yield113 Cement- Cubic It 113 Cement- Cubic tt 113 Cement- Cubic tt /Vol Cement- Fill Factor Conducto~ 0.000 0.000 0.000 0.000 0.000 11000 11000 110O0 11000 11000 0.000 0.000 11DIV/O! Surlace 0.000 11000 11000 0.000 11000 11000 0.000 0.000 11000 0.000 tZ000 0.000 0.000 0.000 0.000 0.000 ItL)IV/O! Liner 7.000 1,54G. 000 8.500 270.000 1.180 318.G00 318. G00 0.000 0.000 0.000 0.000 318.600 1.625 Casing Type Casing Size -Inches Casing Depih - Feet Hole Diamete~-Inches Cement-Sacks Cement-Yield 111 Cement- Cubic It 111 Cement- Cubic It 111 Cement-Sacks 112 Cement-Yield 112 Cement- Cubic It 112 Cement-Cubic It 112 Cement- Sacks113 Cement- Vield113 Cement- Cubic It 113 Cement- Cubic It 113 Cement- Cubic It / Vol Cement-interval it Top of Cement- Feet Int~mediaIe 111 11000 11000 11000 0.00 0.00 0.00 1100 1100 0.00 0.00 0.00 0.00 1100 0.00 1100 1100 11DIV/O!. ~IV/O! Intermediate 112 0.000 0.000 11000 0.00 0.00 0.00 0.00 1100 0.00 0.00 1100 1100 1100 0.00 0.00 0.00 11DIV/O! IIDIV/O! Produclion 0.000 0.000 0.000 0.00 0.00 1100 1100 0.00 0.00 1100 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/0! I*DIV/O! Measured Deplh Printed 4/14/93 State: Alaska Borough: Well: DS6-22A Field: Prudhoe Bay St. Perm ~ 9,3-57 Date Engr: 6.2~ACSG.DOC .. 4/14/~, M. Minder Casing Interval Interval Size Boffom lA 7 9253 2A 0 0 3A 0 0 4A 0 0 5A 0 0 6A 0 0 7A 0 0 8A 0 0 9A 0 0 10A 0 0 Top Length 7788 1546 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Lbs Grade Thread Lbs 29 13CR-80 TD$IFOX 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 2B 3b 4B 5B 6B 7B 8B 9B 10B Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/ft psi/ft 9.8 0.510 0,410 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0,100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0,100 Maximum Minimum Pressure psi 333O 0 0 0 0 0 0 0 0 0 Yield psi BDF 8160 o #DIV/O! 0 #DIVI0! 0 #DIV/O! 0 #DIV/O.I 0 #DIV/O! 0 #DIVi0! 0 #DIV/0! 0 #DIV/0! 0 #DIV,/0! lC 2C 8C 4C 5C 6C 7C 8C 9C 10C Tension Strength K/Lbs 44.834 0 0 0 0 0 0 0 0 0 K/Lbs TDF 676 15.08 0 #DIV/0! 0 #DN/0! 0 #DlVl0! 0 #DIV/0! 0 #DIV/0.1 0 #DIV/0! 0 #DIV/0.1 0 #DIV/'0! 0 #DIV/0.1 Collapse Collapse Pr-Bot-Psi 3790 0 0 0 0 0 0 0 0 0 Resist. CDF 7020 1.852 0 #DIV/O! 0 #DIV/O! 0 #DIV/O.! 0 #DNIO! 0 #DIVIO! 0 #DIVIO! 0 #DIV/O! o #DIV/O! 0 #DIV/0! Page 1 .-~. STATE OF ALASKA r ~ AL,. ~, OIL AND GAS CONSERVATION COMMISS , APPLICA i1ON FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suslc~end __ Operation Shutdown .... Re-enter suspended well ~ Alter casing ~ Repair well ~ Plugging x Time extension ~ Stimulate ~ Change approved program ~ Pull tubing ~ Variance J Perforate ~ Other x ~ Plugback Ior redrlll 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 584' NSL, 985' WEL, SEC. 2, TION, R14E At top of productive interval 2434'NSL, 2665'EWL, SEC. 1, TION, R14E At effective depth At total depth 2508'NSL, 2772'EWL, SEC. 1, TION, R14E 5. Type of Well: Development Exploratory Stratigraphic Service APR - 9 199, Alaska 0il & Gas Cons. Cornmissio Anchorage 6. Datum elevation (DF or KB) RKB- 74' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 6-22 9. Permit number 82-131 10. APl number 50- O29-2O806 ~11. Field/Pool Prudhoe Bay Field/O# Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10680 feet 9255 feet 10626 feet 9203 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Measured depth Structural Conductor 79' 20" 1910 # Poleset 79' S u dace 2445' 13-3/8" 2200 sx Fondu & 2519' Intermediate 400 sx PF "C" Production 9886' 9-5/8" 500 sx "G"7300 sx "C" 9960' Liner 1027' 7" 350 sx Class "G" 10675' Perforation depth: measured 10450'-10466', 10466'-10474' True vertical depth 79' 2519' 8552' 9250' true vertical 9030~9046~ 9046~9054' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9608'MD; 12.6#, L-80, PCTtail @ 9679'MD Packers and SSSV (type and measured depth) Baker SAB Packer@ 9598'MD; Camco Bal-O SSSV @ 2095'MD 13. Attachments Description summary of proposal × Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 4/1 O/93 16. If proposal was verbally approved Name of approver 15. Status of well classification as: Oil x Gas Suspended~ Date approved Service 17. ! hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ?~'~'~ Title Dril/ing Engineer Supervisor Date ~//~'/~'_~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ._~.----L-t:~ce~on clearance F;rm 10-403 Rev 06/15/8~ ' '~ - ~ Commissioner SUBMIT IN TRIPLICATE CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee /~./m~__ ~//¢//? ( 2 ) Loc .~./o~_ ~/¢//~_~ [2 thru 8] (3) Admin .[~](. .~.//?/~_~ [9 thru 13] [10 & 13] ' ,, (4) Casg ...... [14 thru 22] (5) BORE [23 thru 28] . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company /~/d_~_~ Lease & Well ~/~ NO YES 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... ./~ _ 4. Is well located proper distance from other wells ..................... /~_ 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ ,.., Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... ~'~ Is lease nLrnber appropriate .......................................... Does well have a unique name & nL~nber ................................ Is conductor string provided ......................................... Will surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface g intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of-dd~&~-~-~l~ BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~O~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS ! (6) Other [29 thru 31] (7) Contact [32] (8) Add~ 29. 30. 31. 32. 33. geol ogy' eng i neet ing: DWJ MTM~/ RAD-r~ H -~ !/~ RPC~ BEW JDH~{. ~../~., .~. & LG rev 12/92 FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLrnber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE .... Additional remarks' MERIDIAN: UM /~< SM TYPE' Exp~_~/~, Inj Redrill Rev O -rZ ~O Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 6-22A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292080601 REFERENCE NO : 98093 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 98/02/24 ORIGIN : FLIC REEL NAME : 98093 CONTINUATION # : PREVIOUS REEL : COf4MENT : ARCO ALASKA INC, D.S. 6-22A, PRUDHOE BAY, 50-029-20806-01 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 98/02/24 ORIGIN · FLIC TAPE NAME : 98093 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, D.S. 6-22A, PRUDHOE BAY, 50-029-20806-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 6-22A API ~ER '. 500292080601 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 2 4 -FEB- 9 8 JOB NUlVZBER: 98093 LOGGING ENGINEER: BAILEY OPERATOR WITNESS: K NEUPERT SURFACE LOCATION SECTI ON: 2 TOWNSHIP: 1 ON RANGE: 14E FNL: FSL: 584 FEL: 985 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 74. O0 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 675 9297.0 47. O0 2ND STRING 7. 000 9046. 0 29. O0 3RD STRING 7. 000 10681.0 29. O0 PRODUCTION STRING 3. 500 9681.0 9.30 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 03 -MAY- 93 LOGGING COMPANY: WESTERN ATLAS BASELINE DEPTH 88888.0 10535.5 10533.5 10530.0 10527.5 10526.0 10524.0 10519.0 10516.0 10510.5 10510.0 10505.5 10502.5 10501.5 10500.0 10492.5 10484.5 10483.5 10481.5 10475.0 10472.0 10468.5 10465.5 10464.0 10463.0 10461.5 10459.0 10453.0 10448.5 10446.5 10442.5 10440.5 10437 5 10434 5 10420 5 10420 0 10414 5 10414 0 10412 0 10409.5 10409.0 10405.0 10404.0 10403.0 10401.5 .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP 88888.0 88887.0 10527.5 10525.5 10517.0 10514.0 10508.0 10504.5 10500.0 10498.5 10491.0 10482.0 10480.5 10475.0 10470.5 10467.0 10464.5 10463.0 10460.0 10458.5 10452.0 10446.0 10444.0 10441.5 10440.0 10437.5 10434.0 10420.0 10415.0 10412.0 10408.5 10405.0 10403.0 10534.5 10532.0 10528.0 10524.5 10517.0 10514.0 10508.0 10504.0 10500.0 10498.5 10491.0 10482.0 10480.5 10475.0 10470.5 10467.0 10464.5 10463.0 10460.0 10458.5 10452.0 10446.0 10444.0 10441.5 10440.0 10437.5 10434.0 10420.0 10415.5 10412.0 10408.0 10405.0 10403.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10390.5 10388.0 10386.5 10380.0 10379.0 10377.5 10375.0 10370.5 10361.5 10361.0 10358.0 10351.5 10351.0 10348.0 10347.0 10345.0 10341.0 10333.5 10325.5 10320.5 10317.0 10312.5 10310 5 10307 0 10301 0 10300 5 10297 5 10291 5 10291 0 10289 0 10287 0 10284.5 10279.0 10277.0 10273.5 10271.0 10268.5 10263.5 10262.0 10259.5 10259.0 10256.0 10255.0 10253.5 10252.0 10245.5 10245.0 10242.5 10241.5 10239.0 10236.5 10235.5 10232.0 10226.0 10225.5 10222.5 10390.5 10390.5 10388.0 10388.0 10386.0 10386.0 10380.0 10380.0 10377.5 10377.5 10373.5 10371.5 10371.5 10361.5 10361.5 10357.5 10357.5 10350.5 10344.5 10343.0 10340.0 10350.5 10347.0 10332.5 10332.5 10324.0 10323.5 10320.5 10320.5 10317.0 10317.0 10312.0 10310.5 10307.0 10307.0 10301.0 10301.0 10297.5 10297.5 10292.5 10292.5 10289.5 10288.5 10284.5 10285.0 10279.0 10279.0 10276.0 10276.0 10273.0 10273 . 0 10271.0 10271.0 10269.5 10269.5 10262.5 10263.0 10260.0 10257.5 10260.0 10257.5 10254.5 10254.5 10252.0 10252.0 10246.0 10245.0 10242.0 10236.5 10242.0 10239.0 10236.5 10232.0 10232.0 10226.0 10226.0 10222.5 10222.5 24-FEB-1998 10:05 PAGE: 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10214.5 10208.0 10204.5 10204.0 10201.0 10199.0 10198.5 10194.0 10192.0 10189.5 10187.0 10186.5 10184.5 10183.5 10179.0 10176.5 10173 5 10167 0 10165 5 10164 5 10157 0 10152 0 10151 5 10147 5 10144 0 10138.0 10132.5 10132.0 10128.0 10127.0 10122.5 10114.0 10113.5 10108.5 10107.0 10099.0 10098.0 10097.5 10096.5 10095.0 10094.0 10092.5 10092.0 10090.5 10090.0 10085.0 10084.0 10082.0 10077.0 10072.0 10070.5 10069.0 10062.5 10060.5 10058.0 10057.0 10213.5 10209.5 10204.5 10199.0 10194.0 10192.0 10190.0 10187.0 10184.0 10179.0 10177.5 10173.0 10167.5 10166.0 10157.5 10153.5 10148.0 10142.0 10138.5 10132.0 10128.0 1 O122.5 10113.5 10108.0 10106.0 10099.5 10097.0 10095.0 10091.5 10089.5 10084.5 10081.0 10076.5 10072.5 10069.5 10068.0 10061.5 10060.0 10057.0 10215.5 10209.5 10204.5 10202.0 10199.0 10194.0 10192.0 10190.0 10187.0 10184.0 10179.0 10177.0 10173.0 10167.5 10165.5 10157.5 10154.0 10148.0 10142.0 10138.5 10132.0 10128.0 10122.5 10113.5 10108.0 10106.0 10099.5 10097.0 10095.0 10091.5 10089.5 10084.5 10076.5 10072.5 10069.5 10068.0 10061.5 10060.0 10057.0 24-FEB-1998 10:05 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 10053.0 10052.5 10052.5 10051.0 10050.0 10050.0 100.0 99.0 99.0 $ REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON ARCO ALASKA'S DS 6-22A WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GAI4MA RAY~ ALSO SIGMA BASE PASS #1 AND THE BCS GA~A RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE ' 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SURff~L~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10529.0 10049.0 TDTP 10541.0 10049.0 $ CURVE SHIFT DATA - PASS TO PASS (~SURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 66 66 73 66 66 73 65 0 0 96 1 0.5 FT 10 1 2 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 SIGMTDTP CU 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 SBHNTDTP CU 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 LCO1 TDTP 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 TSCNTDTP CPS 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 GRCHTDTP GAPI 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1173638 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: ** DATA ** DEPT. 10550. 000 SIGM. TDTP -999. 250 TPHI. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP LCO1. TDTP -999. 250 SDSI. TDTP -999. 250 BACK. TDTP TCAN. TDTP - 999. 250 TCAF. TDTP -999. 250 TCND. TDTP TSCN. TDTP -999. 250 TSCF. TDTP -999. 250 INND. TDTP GRCH. TDTP -999. 250 TENS. TDTP -999. 250 CCL. TDTP DEPT. 10040. 000 SIGM. TDTP -999. 250 TPHI. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP LCO1. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP TCAN. TDTP -999. 250 TCAF. TDTP -999. 250 TCND. TDTP TSCN. TDTP -999. 250 TSCF. TDTP -999. 250 INND. TDTP GRCH. TDTP -999. 250 TENS. TDTP -999. 250 CCL. TDTP -999. 250 SBHF. TDTP -999. 250 TRAT. TDTP -999. 250 FBAC. TDTP -999. 250 TCFD. TDTP - 999.250 INFD. TDTP -999. 250 GR. BCS -999. 250 SBHF. TDTP - 999. 250 TRAT. TDTP -999. 250 FBAC. TDTP - 999.250 TCFD. TDTP -999. 250 INFD. TDTP -999. 250 GR. BCS -999.250 -999.250 -999.250 -999.250 -999.250 39.642 -999.250 -999.250 -999.250 -999.250 -999.250 545.154 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO MST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NOI4BER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NURiBER : 2 DEPTH INCREMENT: 0.5000 FILE SUbgqARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: GRCH 10528.5 10050.0 TDTP 10540.5 10050.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURgF~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFiBER : 1 BASELINE DEPTH 88888.0 10539.0 10537.5 10533.5 10530.5 10528.5 10526.0 10524.0 10520.5 10519.0 10514.0 10513 5 10511 0 105O8 5 10505 5 10502 5 10502 0 10498 0 10492.5 10483.5 10481.5 10481.0 10476.0 10474.0 10467.0 10466.0 10461.0 10459.5 10459.0 10453.5 10451.0 10446.5 10442.5 10441.0 10438.0 10436.0 10430.0 10427.0 10426.0 ! 0423.5 10422.5 10421.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88887.5 88886.5 10528.0 10525.5 10518.5 10516.5 10511.0 10508.5 10504.5 10500.0 10491.0 10480.5 10475.5 10467.0 10461.0 10458.5 10452.0 10446.0 10441.5 10440.0 10434.5 10426.5 10422.5 10421.5 10537.5 10536.0 10532.0 10528.0 10524.0 10517.5 10511.5 10507.5 10500.0 10496.5 10482.0 10478.5 10475.5 10465.0 10458.0 10447.0 10441.0 10438.0 10429.0 10426.0 10423.0 10420.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 10414.5 10415.5 10412.5 10412.5 10412.0 10409.5 10408.5 10408.0 10408.0 10405.5 10405.0 10405.0 10402.5 10403.0 10401 . 0 10403.0 10397.5 10399.0 10396.0 10398.5 10392.0 10392.5 10388.5 10392.5 10385.0 10388.0 10383.5 10384.0 10382.5 10381.0 10380.5 10380.0 10378.0 10377.5 10377.0 10377.0 10375.0 10373.5 10372.5 10371 . 5 10371.0 10371.0 10367.0 10364.5 10361.5 10361.0 10361.0 10361.5 10360.0 10357.5 10354.5 10351 . 0 10343.5 10340.0 10341 . 0 10341 . 0 10337.0 10336.5 10334.0 10332.5 10333.0 10329.5 10327.5 10327.5 10326.0 10326.5 10325.0 10322.5 10320.5 10318.5 10317.0 10313.0 10311.5 10311.0 10311.5 10309.0 10307.5 10307.0 10307.0 10300.5 10301.5 10301.0 10298.0 10297.0 10297.0 10297.5 10290.5 10290.5 10289.0 10289.0 10280.0 10280.5 10277.0 10279.0 10274.5 10274.0 10271 . 5 10272.0 10271.0 10269.5 10263.5 10263.0 10262.0 10263.0 10259.5 10260.5 10260.5 10256.0 10257.5 10257.0 10252.5 10253.5 10249.0 10248.5 10247.5 10248.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 10 10245.0 10242.0 10241.0 10238.5 10235.5 10232.5 10228.5 10225.5 10222.5 10218.5 10217.5 10213.0 10212.0 10208.5 10203.5 10200.5 10198.5 10198.0 10196.0 10193.5 10191.0 10189.5 10187.0 10186.5 10176.5 10176.0 10173.5 10173.0 10169.5 10167.0 10164.5 10160.5 10154.5 10154.0 10153.0 10149.5 10148.0 10141.5 10140.5 10137.5 10137.0 10132 5 10132 0 10127 0 10124 0 10122 0 10121 0 10117, 5 10116.0 10113.0 10111.5 10110.0 10108.0 10107.0 10105.5 10245.5 10242.0 10236.5 10232.0 10229.0 10226.0 10222.5 10218.5 10214.0 10207.5 10201.0 10199.0 10192.0 10187.5 10177.5 10172.5 10170.0 10167.5 10166.0 10158.0 10153.5 10151.5 10150.0 10148.0 10142.0 10138.5 10132.0 10128.0 10122.5 10119.0 10113.5 101!1.5 10108.0 10106.0 10246.0 10242.0 10239.0 10226.0 10218.5 10214.0 10204.5 10202.0 10199.0 10196.0 10194.0 10190.5 10187.5 10177.0 10173.0 10170.0 10166.0 10162.0 10156.0 10140.0 10138.0 10132.0 10128.0 10125.0 10122.0 10116.5 10113.0 10110.0 10106.5 10104.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 11 10099.0 10099.5 10098.5 10099.5 10095.0 10094.5 10091.5 10091.5 10090.0 10089.5 10089.5 10089.5 10084.5 10084.5 10081.5 10081.5 10083.0 10080.5 10080.0 10077.0 10077.0 10076.5 10077.0 10074.0 10074.5 10071.5 10072.0 10071.0 10072.0 10068.5 10068.0 10068.5 10066.0 10065.0 10065.5 10065.5 10063.0 10063.0 10062.5 10060.5 10060.0 10057.5 10057.0 10057.0 10057.0 10052.5 10052.5 10052.5 100.0 100.0 100.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 12 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 LCO1 TDTP 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1173638 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10540. 500 SIGM. TDTP 14. 731 TPHI. TDTP 34. 066 SBHF. TDTP 63 . 637 SBPZN. TDTP 70. 559 SIGC. TDTP O. 373 SIBH. TDTP 106. 254 TRAT. TDTP 1 . 868 LCO1 . TDTP 2. 437 SDSI. TDTP O . 377 BACK. TDTP 167.31 8 FBAC. TDTP 36. 266 TCAN. TDTP 27776.539 TCAF. TDTP 11399. 467 TCND. TDTP 20363.270 TCFD. TDTP 6359. 307 TSCN. TDTP 5564. 566 TSCF. TDTP 2283 . 693 INND. TDTP 1 638. 468 INFD. TDTP 288.141 GRCH. TDTP -999. 250 TENS. TDTP 1250. 000 CCL. TDTP O. 003 DEPT. 10050. 000 SIGM. TDTP 18.907 TPHI. TDTP 21.274 SBHF. TDTP SBHN. TDTP 41 . 573 SIGC. TDTP 2.108 SIBH. TDTP 41 . 573 TRAT. TDTP LCO1 . TDTP 2.197 SDSI. TDTP O. 535 BACK. TDTP 184 . 649 FBAC. TDTP TCAN. TDTP 37055. 008 TCAF. TDTP 16866.293 TCND. TDTP 29111 . 406 TCFD. TDTP TSCN. TDTP 7493. 346 TSCF. TDTP 341 O. 739 INND. TDTP 1741. 483 INFD. TDTP GRCH. TDTP 120. 875 TENS. TDTP 1240. 000 CCL. TDTP O. 000 29. 372 1. 563 44. 326 10676. 771 401. 985 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 13 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INC~: 0.5000 FILE SURk~%RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10529.0 10049.5 TDTP 10540.5 10050.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88888.0 88886.5 10533.5 10532.0 10530.0 10528.0 10528.0 10528.0 10526.5 10525.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 14 10524.5 10522.5 10520.5 10520.0 10515.5 10513.5 10512.0 10506.0 10505.5 10502.5 10501.5 10498.5 10498.0 10496.5 10491.5 10491.0 10485.0 10482.0 10481.0 10475.5 10467.5 10461.0 10459.0 10458.5 10454.0 10449.5 10444.5 10441.0 10440.5 10435.0 10430 5 10428 0 10425 5 10425 0 10422 5 10421 5 10420 5 10418 0 10414, 0 10413.5 10412.0 10408.0 10403.0 10402.0 10395.5 10391.5 10390.5 10379.5 10377.0 10376.5 10374.5 10370.5 10363.0 10361.0 10360.5 10517.0 10513.5 10510.0 10504.5 10500.0 10496.5 10491.0 10482.0 10480.5 10475.0 10467.0 10460.0 10458.5 10452.0 10444.0 10440.0 10434.0 10429.0 10426.5 10422.5 10418.0 10415.0 10412.5 10408.5 10403.5 10393.0 10388.0 10379.5 10378.0 10371.5 10363.0 10361.0 10525.0 10523.0 10517.5 10512.0 10504.5 10501.0 10496.5 10494.5 10490.5 10481.5 10475.5 10458.0 10448.5 10440.5 10435.0 10430.5 10425.5 10423.0 10420.0 10415.5 10412.0 10403.5 10392.0 10380.5 10377.5 10373.5 10371.5 10363.5 10361.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 15 10352.5 10346.5 10341.5 10341 0 10333 5 10331 0 10328 5 10324 0 10321 0 10319 5 10317 5 10308 0 10301.0 10300.5 10298.5 10297.0 10294.0 10289.5 10284.5 10282.5 10280.5 10274.5 10272.5 10267.0 10264.0 10259.5 10259.0 10255.5 10253.5 10248.5 10245.0 10242.0 10241.5 10239.0 10238.5 10236.0 10231.0 10229.0 10225.5 10222.5 10220. 5 10216 5 10204 0 10203 5 10200 5 10198 5 10194 5 10190 5 10190 0 10189 0 10187.0 10186.5 10184.5 10179.0 10176.5 10350.5 10344.0 10340.0 10322.0 10320.5 10318.5 10317.0 10307.0 10301.0 10297.5 10289.0 10284.0 10279.0 10273.0 10269.5 10260.5 10248.0 10246.0 10242.0 10239.5 10236.5 10232.0 10226.0 10222.5 10220.5 10204.5 10199.0 10194.0 10190.0 10189.5 10186.5 10184.5 10179.5 10341.0 10333.0 10330.5 10327.5 10301.0 10297.0 10295.0 10283.5 10280.5 10274.5 10263.0 10260.5 10257.0 10253.0 10246.0 10242.5 10239.0 10237.0 10229.0 10226.0 10218.0 10204.5 10202.0 10199.0 10190.5 10187.5 10177.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 16 10173 5 10169 5 10167 0 10165 5 10161 0 10158 5 10152 0 10151 0 10147 5 10145 0 10141 5 10138 5 10138 0 10132 5 10131.5 10127.0 10125.5 10124.5 10121.0 10116.5 10116.0 10114.0 10113.5 10111.0 10105.0 10099.5 10095.0 10094.0 10089.5 10085.0 10083.0 10082.0 10077.0 10075.5 10073.5 10069.0 10066.5 10063.5 10063.0 10060.5 10058.0 10057.0 10054.0 10052.5 100.0 $ 10174.0 10167.5 10166.0 10158.0 10153.5 10148.0 10144.5 10138.5 10132.0 10128.5 10116.0 10113.5 10106.0 10095.0 10084.0 10081.5 10077.0 10075.0 10072.5 10064.5 10062.5 10060.0 10057.0 10053.5 99.5 10174.0 10170.0 10162.0 10153.5 10140.0 10138.5 10132.5 10128.5 10125.0 10121.0 10116.0 10113.5 10110.0 10100.0 10095.0 10089.5 10083.0 10068.5 10062.0 10057.0 10052.5 100.0 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 1i 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 SBHNTDTP CU 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 SIBHTDTP CU 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 LCO1 TDTP 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1173638 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 18 * * DA TA * * DEPT. 10540.500 SIGM. TDTP SBHN. TDTP 66. 882 SIGC. TDTP LCO1. TDTP 2. 463 SDSI. TDTP TCAN. TDTP 29130. 820 TCAF. TDTP TSCN. TDTP 5806. 743 TSCF. TDTP GRCH. TDTP -999.250 TENS. TDTP DEPT. 10049. 500 SIGM. TDTP SBPZN. TDTP -999. 250 SIGC. TDTP LCO1 . TDTP -999. 250 SDSI. TDTP TCAN. TDTP -999. 250 TCAF. TDTP TSCN. TDTP -999. 250 TSCF. TDTP GR CH . TDTP 131 . 375 TENS. TDTP 14 790 0 514 0 368 11828 086 2357 732 1315 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TPHI. TDTP SIBH. TDTP BACK. TDTP TCND. TDTP INND. TDTP CCL. TDTP TPHI. TDTP SIBH. TDTP BACK. TDTP TCND. TDTP INND. TDTP CCL. TDTP 35 105 97 393 199 851 21137 781 1784 931 -0 024 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 SBHF. TDTP TI(AT. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP SBHF. TDTP TRAT. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP 63.269 1.896 52.063 6530.348 300.663 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 0 O1 CO 1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NOY4~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NYIMBER : 4 DEPTH INCRE~IE1VT ; O . 5000 FILE SUN~4~RY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 19 GRCH 10529.0 10048.5 TDTP 10541.5 10049.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10538.5 10536.5 10529.5 10524.0 10523.5 10521.5 10519.0 10518.5 10515.0 10513.0 10505.5 10505.0 10502.5 10500.5 10498.5 10497.5 10496.5 10489.0 10488.5 10486.0 10485.5 10482.5 10481.0 10478.5 10474.0 10468.0 10466.5 10465.0 10462.5 10460.0 10458.5 10454.0 10446.5 10444.5 10440.0 10439.5 10438.5 10434.5 10434.0 10430.0 10426.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88888.0 88887.5 10524.0 10518.0 10516.5 10514.0 10504.0 10500.0 10496.5 10493.5 10491.0 10487.5 10482.0 10480.5 10477.5 10474.5 10469.0 10467.0 10464.0 10463 0 10460 0 10458 5 10452 0 10444 5 10442 0 10440 0 10438.0 10434.0 10538.0 10536.0 10528.0 10524.5 10518.0 10516.5 10512.0 10504.0 10500.0 10496.5 10490.5 10487.5 10482.0 10480.5 10477.5 10474.5 10469.5 10465.0 10460.0 10440.0 10434.5 10429.5 10426.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 2O 10425.5 10423.5 10423.0 10420.5 10415.5 10414.5 10412.5 10408.5 10407.0 10405.0 10400.5 10398.5 10394.5 10391.5 10387.5 10382.5 10380.0 10378.0 10375.5 10371.0 10370.5 10364.5 10361.5 10361.0 10357.5 10352.0 10351.0 10341.5 10337.5 10334.5 10330 0 10327 5 10324 0 10320 5 10320 0 10317 0 10316 5 10312 0 10310.0 10307.5 10301.5 10301.0 10297.5 10294.0 10289.5 10284.5 10282.5 10281.5 10280.5 10275.0 10273.0 10269.5 10267.5 10264.0 10263.5 10426.0 10422.5 10415.0 10412.5 10408.5 10405.0 10399.0 10388.0 10385.0 10381.5 10380.0 10377.5 10371.5 10365.0 10361.0 10357.5 10350.5 10340.0 10332.5 10324.0 10320.5 10317.0 10310.5 10301.0 10292.5 10289.5 10284.5 10282.5 10279.0 10275.5 10273.5 10269.5 10268.0 10263.0 10423.0 10420.0 10415.5 10412.0 10408.0 10405.5 10399.0 10394.5 10380.5 10377.0 10373.5 10371.0 10361.0 10350.0 10341.0 10337.0 10332.5 10327.5 10324.5 10319.0 10317.0 10311.5 10307.5 10301.0 10297.0 10280.5 10274.0 10263.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 21 10260.5 10251.5 10246.0 10245.5 10240.0 10239.5 10237.0 10226.5 10219.0 10218.0 10213.5 10204.5 10201.5 10199.0 10197.0 10191.5 10190.0 10187.5 10180.0 10179.5 10178.0 10170.5 10168.0 10166.0 10163.5 10161.5 10160.0 10151.5 10145.5 10144.5 10142.5 10141.5 10139.5 10138.5 10133.5 10131 0 10129 5 10127 5 10125 5 10123 0 10121 5 10117 0 10116.5 10114.0 10111.5 10108.5 10106.5 10106.0 10104.5 10100.0 10098.5 10096.0 10095.0 10090.5 10086.0 10260.0 10251.5 10245.0 10239.0 10236.5 10226.0 10219.0 10213.5 10204.5 10198.5 10197.0 10191.5 10187.0 10179.0 10177.5 10167.5 10165.5 1 O162.5 10158.0 10144.5 10142.0 10139.0 10132.0 10128.0 10117.5 10113.0 10108.5 10106.0 10099.5 10095.0 10089.5 10260.0 10246.0 10239.0 10226.0 10218.5 10202.0 10199.0 10196.0 10190.0 10187.5 10179.5 10170.0 10162.0 10153.5 10142.5 10140.0 10138.5 10132.5 10128.0 10125. 0 10122. 0 10121.0 10116.0 10113.5 10110.5 10105.0 10103.0 10100.0 10095.0 10089.5 10086.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 22 10085.5 10084.5 10084.0 10083.0 10083.0 10081.5 10077.5 10076.5 10076.0 10075.5 10075.5 10074.5 10072.5 10072.0 10070.0 10068.5 10068.5 10067.5 10064.5 10065.0 10062.5 10064.0 10063.0 10061.0 10060.0 10060.0 10059.5 10058.5 10057.0 10057.5 10057.0 10055.0 10054.0 10053.0 10052.0 10052.0 10050.5 100.0 98.5 99.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #1ANDSIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 23 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 SIGMTDTP CU 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-L 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 SBPZN TDTP CU 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 LCO1 TDTP 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 TCAFTDTP CPS 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 TSCNTDTP CPS 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 1173638 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10541 . 500 SIGM. TDTP 14. 378 TPHI. TDTP 32. 472 SBHF. TDTP SBHN. TDTP 68. 283 SIGC. TDTP O. 404 SIBH. TDTP 98. 075 TRAT. TDTP LCO1. TDTP 2. 504 SDSI. TDTP O. 349 BACK. TDTP 205. 469 FBAC. TDTP TCAN. TDTP 30446. 637 TCAF. TDTP 12156. 975 TCND. TDTP 21689. 086 TCFD. TDTP TSCN. TDTP 6097. 543 TSCF. TDTP 2434. 675 INND. TDTP 1718. 869 INFD. TDTP GRCH. TDTP -999.250 TENS. TDTP 1270. 000 CCL. TDTP O. 000 66.059 1.916 46.426 6653.782 306.733 DEPT. 10048.500 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 LCO1.TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND.TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 137.875 TENS. TDTP -999.250 CCL. TDTP -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 24 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAi~E : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUN~ER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10529.0 10049.0 TDTP 10540.0 10048.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 BASELINE DEPTH 88888.0 10539.5 10537.0 10533 0 10530 0 10524 0 10523 5 10520 5 10519 0 10518.5 10515.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.0 88886.0 10537.5 10536.0 10532.0 10528.0 10524.0 10517.0 10514.0 10524.0 10520.0 10516.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 25 10513.0 10508.0 10505.5 10503.0 10501.5 10499.0 10496.5 10495.5 10491.5 10490 0 10488 0 10485 5 10482 5 10482 0 10478 5 10475 5 10475.0 10473.5 10469.5 10467.5 10465.0 10462.5 10460.0 10459.5 10456.5 10454.0 10452.0 10450.0 10446.5 10444.0 10440.5 10440.0 10433.0 10431.0 10430.5 10426.0 10423.5 10422.5 10421.0 10420.5 10419.0 10414.5 10412.5 10412.0 10410.0 10404.5 10402.5 10399.5 10398.5 10394.5 10393.5 10391.5 10388.0 10386.5 10382.0 10506.0 10504.5 10500.0 10496.0 10493.5 10491.0 10482.0 10480.5 10477.5 10475.0 10467.0 10462.0 10458.5 10452.5 10446.0 10441.5 10440.0 10434.0 10422.5 10421.5 10419.0 10412.5 10409.0 10405.0 10398.5 10393.0 10390.5 10388.5 10381.5 10511.5 10500.5 10496.5 10490.0 10487.5 10480.5 10474.5 10472.5 10468.5 10464.0 10459.0 10454.5 10451.5 10446.5 10439.5 10432.5 10429.5 10426.0 10422.5 10420.0 10415.5 10412.0 10408.5 10403.0 10399.0 10394.5 10387.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 26 10380.0 10377.5 10375.5 10373.0 10370.5 10365.5 10364 0 10362 0 10361 0 10360 0 10355 0 10354 5 10351 0 10350 0 10343 0 10342 0 10334 0 10332 0 10330 5 10328 0 10326 0 10325 0 10321 5 10318 5 10316.0 10314.5 10312.0 10309.5 10307.5 10301.5 10301.0 10299.5 10297.5 10289.0 10281.5 10278.0 10274.5 10271.5 10267.0 10264.5 10262.5 10260.5 10253.0 10246.0 10244.0 10242.5 10242.0 10240.0 10239.5 10236.5 10236.0 10232.0 10226.5 10226.0 10223.0 10379.5 10377.5 10371.5 10365.0 10361.5 10357.5 10350.5 10343.0 10340.0 10332.5 10324.0 10322.0 10318.5 10317.0 10315.0 10308.5 10301.0 10298.0 10287.0 10279.0 10273.0 10267.5 10262.5 10245.5 10243.0 10241.5 10239.0 10236.5 10232.0 10225.5 10223.0 10380.0 10377.0 10373.5 10371.5 10363.5 10361.5 10355.5 10350.5 10340.5 10333.0 10328.0 10325.0 10323.5 10311.5 10307.5 10300.5 10297.0 10281.0 10274.0 10263.0 10260.5 10252.0 10246.0 10242.5 10239.0 10236.0 10226.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 27 10218 0 10213 0 10210 0 10204 5 10201 5 10201 0 10199 5 10194 5 10194.0 10191.0 10187.0 10185.0 10181.0 10180.0 10179.0 10177.5 10175.5 10174.0 10173.0 10170.5 10170.0 10166.0 10165.5 10163.5 10162.0 1 O159.5 10152.0 10147.5 10142.5 10139.0 10138.5 10135.0 10133 0 10129 5 10128 5 10127 5 10126 5 10125 0 10123 0 1 O121.0 10118.5 10116.5 10114.5 10114.0 10111.5 10106.0 10105.0 10103.5 10100.5 10096.5 10094.0 10092.5 10091.0 10086.0 10084.0 10214.0 10209.0 10204.5 10201.0 10199.0 10194.5 10190.0 10184.0 10181.5 10179.0 10177.5 10172.5 10170. 0 10166. 0 10162. 0 10158. 0 10152.5 10147.5 10138.5 10136.5 10132. 0 10128. 0 10126.5 10122.5 10117.5 10115.5 10113.5 10110.5 10106. 0 10103. 0 10098. 0 10095.0 10091.0 10084.5 10218.0 10202.0 10199.0 10193.5 10190.5 10187.0 10179.5 10177.0 10173.0 10170.0 10166.0 10162.0 10153.5 10140.0 10138.5 10132.5 10128.0 10125.0 10122.0 10120.5 10113.0 10104.5 10099.5 10090.0 10084.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 28 10083.0 10081.5 10077.5 10077.0 10077.0 10075.5 10075.5 10075.0 10073.5 10072.0 10070.0 10069.5 10068.5 10067.0 10065.5 10064.5 10062.5 10064.0 10063.0 10058.0 10057.5 10056.0 10054.5 10053.5 10052.5 10052.0 100.0 99.0 98.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #2AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #2ANDSIGMA BASE PASS #1, CARRYINGALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 29 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173638 O0 000 O0 0 5 1 1 4 68 SIGM TDTP CU 1173638 O0 000 O0 0 5 1 1 4 68 TPHI TDTP PU-L 1173638 O0 000 O0 0 5 1 1 4 68 SBHF TDTP CU 1173638 O0 000 O0 0 5 1 1 4 68 SBPZN TDTP CU 1173638 O0 000 O0 0 5 1 1 4 68 SIGC TDTP CU 1173638 O0 000 O0 0 5 1 1 4 68 SIBH TDTP CU 1173638 O0 000 O0 0 5 1 1 4 68 TRAT TDTP 1173638 O0 000 O0 0 5 1 1 4 68 LCO1 TDTP 1173638 O0 000 O0 0 5 1 1 4 68 SDSI TDTP CU 1173638 O0 000 O0 0 5 1 1 4 68 BACK TDTP CPS 1173638 O0 000 O0 0 5 1 1 4 68 FBAC TDTP CPS 1173638 O0 000 O0 0 5 1 1 4 68 TCAN TDTP CPS 1173638 O0 000 O0 0 5 1 1 4 68 TCAF TDTP CPS 1173638 O0 000 O0 0 5 1 1 4 68 TCND TDTP CPS 1173638 O0 000 O0 0 5 1 1 4 68 TCFD TDTP CPS 1173638 O0 000 O0 0 5 1 1 4 68 TSCN TDTP CPS 1173638 O0 000 O0 0 5 1 1 4 68 TSCF TDTP CPS 1173638 O0 000 O0 0 5 1 1 4 68 INND TDTP CPS 1173638 O0 000 O0 0 5 1 1 4 68 INFD TDTP CPS 1173638 O0 000 O0 0 5 1 1 4 68 GRCH TDTP GAPI 1173638 O0 000 O0 0 5 1 1 4 68 TENS TDTP LB 1173638 O0 000 O0 0 5 1 1 4 68 CCL TDTP V 1173638 O0 000 O0 0 5 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 10540. 000 SIGM. TDTP 14.275 TPHI. TDTP 33.236 SBHF. TDTP SBHN. TDTP 69.062 SIGC. TDTP 0.491 SIBH. TDTP 101.871 TRAT. TDTP LCO1 . TDTP 2. 537 SDSI. TDTP O . 321 BACK. TDTP 206. 078 FBAC. TDTP TCAN. TDTP 29237. 457 TCAF. TDTP 11524. 129 TCND. TDTP 20966. 625 TCFD. TDTP TSCN. TDTP 581 O. 869 TSCF. TDTP 2290. 391 INND. TDTP 1705. 203 INFD. TDTP GRCH. TDTP -999. 250 TENS. TDTP 1275. 000 CCL. TDTP O. 013 59.721 1.932 48.746 6411.449 319.730 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 3O **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE IVVJMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUNkr~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10529.5 10049.5 TDTP 10542.0 10049.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER : 1 BASELINE DEPTH 88888.0 10536.0 10529.5 10525.5 10522.5 10519.0 10518.0 10513.5 10512.5 10510.0 10507.0 10505.5 10502.5 10500.0 10497.5 10497.0 10492.5 10492.0 10490.5 10486.5 10483.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.5 88888.0 10526.0 10516.5 10513.5 10508.5 10505.5 10500.0 10496.0 10491.5 10536.0 10528.0 10525.5 10518.0 10511.5 10505.5 10500.0 10496.5 10492.5 10490.0 10487.5 10483.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 31 10481.5 10480.5 10479.0 10476.0 10476.5 10475.0 10475.5 10475.0 10472.0 10472.0 10473.0 10470.5 10470.5 10467.5 10469.0 10465.5 10464.5 10464.5 10462.0 10463.0 10460.5 10462.0 10460.0 10459.0 10458.5 10453.0 10452.0 10445.0 10443.0 10446.0 10440.5 10440.0 10439.5 10440.0 10434.5 10434.0 10434.0 10434.0 10430.0 10429.5 10425.5 10426.0 10424.5 10422.5 10423.0 10423.0 10420.5 10420.5 10415.5 10415.0 10414.5 10415.5 10412.0 10412.0 10412.0 10410.0 10409.0 10409.0 10408.5 10401.5 10399.0 10397.5 10399.0 10395.5 10393.0 10392.0 10388.0 10391 . 5 10393.0 10386.5 10386.0 10380.5 10379.5 10377.5 10377.5 10376.5 10377.5 10375.5 10373.5 10371.0 10371.5 10370.0 10371.5 10364.0 10364.5 10363.5 10364.5 10361 . 5 10361 . 5 10361 . 0 10361 . 5 10358.0 10357.5 10355.0 10351.0 10345.5 10344.0 10343.0 10342.5 10341.0 10340.0 10337.0 10340.0 10331.5 10330.5 10329.5 10328.0 10329.0 10332.5 10327.0 10325.0 10320.5 10320.5 10316.0 10317.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 32 10311.5 10309.5 10301.0 10300.5 10298.0 10292.0 10290.0 10287.5 10284.0 10282.0 10280.5 10272.0 10270.0 10269.0 10263.0 10260.5 10259.5 10256.5 10255.0 10252.5 10246.5 10245 5 10241 5 10239 5 10236 5 10236 0 10228 5 10226 0 10225.5 10223.5 10222.5 10217.5 10212.5 10210.0 10204.0 10203.5 10200.5 10199.0 10195.5 10194.0 10190.0 10187.0 10179.0 10176.5 10174.0 10169.5 10168.0 10166.0 10165.0 10161.0 10158.0 10154.0 1 O151.5 10148.0 10145.0 10311.5 10310.5 10301.5 10297.5 10292.5 10289.0 10284.5 10281.0 10273.0 10269.5 10260.5 10257.5 10254.5 10252.0 10246.0 10236.5 10229.0 10226.0 10222.5 10218.5 10213.5 10209.0 10204.5 10199.0 10196.5 10191.5 10190.0 10187.0 10179.0 10167.5 10166.0 10158.0 10155.5 10153.0 10148.0 10144.5 10311.0 10300.5 10289.5 10281.0 10270.5 10262.5 10260.5 10246.0 10242.0 10239.0 10237.0 10226.0 10222.0 10218.5 10204.5 10202.0 10199.0 10190.5 10177.0 10173.0 10170.0 10166.0 10161.5 10154.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 33 10141.5 10140.0 10140.0 10138.5 10138.0 10138.5 10132.5 10132.0 10131 . 0 10132.0 10127.5 10128.5 10127.0 10126.5 10124.5 10124.5 10123.0 10122.5 10116.0 10116.5 10115.5 10116.5 10113.5 10114.0 10113.0 10112.0 10110.5 10103.0 10103.5 10099.5 10099.5 10097.0 10098.0 10096.0 10095.5 10094.0 10094.5 10089.5 10089.0 10085.0 10084.5 10084.5 10084.5 10082.5 10081 . 5 10077.0 10077.0 10076.0 10071.0 10069.5 10068.5 10068.0 10063.5 10062.5 10063.0 10061.0 10060.0 10057.0 10056.5 10053.0 10052.5 100.0 99.5 99.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BORAX PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BORAX PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 34 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 SIGMTDTP CU 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI TDTP PU-L 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF TDTP CU 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNTDTP CU 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC TDTP CU 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH TDTP CU 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT TDTP 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 LCO1 TDTP 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI TDTP CU 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN TDTP CPS 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF TDTP CPS 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 TCND TDTP CPS 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD TDTP CPS 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 TSCNTDTP CPS 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF TDTP CPS 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 INND TDTP CPS 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 INFD TDTP CPS 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 TENS TDTP LB 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 CCL TDTP V 1173638 O0 000 O0 0 6 1 1 4 68 0000000000 * * DA TA * * DEPT. 10542. 000 SIGM. TDTP SBHN. TDTP 69. 259 SIGC. TDTP LCO1 . TDTP 2 . 519 SDSI. TDTP TCAN. TDTP 31514. 758 TCAF. TDTP TSCN. TDTP 6284. 979 TSCF. TDTP GRCH. TDTP -999.250 TENS. TDTP 14 472 0 470 0 328 12512 334 2495 331 1290 000 TPHI. TDTP 33. 480 SBHF. TDTP SIBH. TDTP 99. 971 TRAT. TDTP BACK. TDTP 229. 068 FBAC. TDTP TCND. TDTP 21843.164 TCFD. TDTP INND. TDTP 1689. 423 INFD. TDTP CCL. TDTP O. 000 57.928 1.929 60.814 6699.034 321.470 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 35 DEPT. 10049. 500 SIGM. TDTP 20. 968 TPHI. TDTP 17. 830 SBHF. TDTP SBH~. TDTP 85. 235 SIGC. TDTP O. 111 SIBH. TDTP 116. 693 TRAT. TDTP LCO1. TDTP 1. 926 SDSI. TDTP O. 634 BACK. TDTP 211. 907 FBAC. TDTP TCAN. TDTP 17257. 672 TCAF. TDTP 8961 . 949 TCND. TDTP 13731 . 012 TCFD. TDTP TSCN. TDTP 3485.432 TSCF. TDTP 1809.993 INND. TDTP 1748.998 INFD. TDTP GRCH. TDTP 141. 250 TENS. TDTP 1190. 000 CCL. TDTP O. 000 67.142 1.387 51.720 5479.006 338.663 ** END OF DATA ** **** FILE TRAILER **** FILE NA~iE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUMBER: 7 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREFiENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, TDTP REMARKS: THIS FILE CONTAINS THE ARITH~4ETIC AVERAGE OF BASE PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 36 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN * * NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FT 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 DEPT SIGM PNAV CU 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PNAV PU-S 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PNAV CU 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 SBHN PNAV CU 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PNAV CU 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PNAV CU 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PNAV 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PNAV CU 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 TCAN PNAV CPS 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PNAV CPS 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PNAV CPS 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PNAV CPS 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PNAV CPS 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PNAV CPS 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 INND PNAV CPS 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PNAV CPS 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 LCO1 PNAV 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 1173638 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 37 ** DATA ** DEPT. 10541.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBP~N. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 127.660 FBACoTDTP 44.067 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 LCOi. PNAV -999.250 GRCH. TDTP -999.250 DEPT. 10049.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC.PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI. PNAV -999.250 BACK. TDTP 157.416 FBAC. TDTP 35.526 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD. PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 LCOi.PNAV -999.250 GRCH. TDTP 121 . 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .008 SERVICE : FLIC VERSION . O01CO1 DATE · 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~9IARY V~IDOR TOOL CODE START DEPTI~ STOP DEPTH TDTP 10573.0 10050.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PA GE: 38 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAI~fA RAY TDTP THERMAL DECAY $ 26-0CT-97 CP 44.2 1138 26-0CT-97 10555.0 10562.0 10050.0 10542.0 1800.0 TOOL NUMBER CGRS 862 TDT SET 396 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 10681.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE/BORAX 10.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN) : REMARKS: TIED IN TO WA BHC DATED 3-MAY-93. THE PURPOSE OF THIS LOG WAS TO FIND THE CURRENT GOC, LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 39 ANY GAS UNDERRUNS, AND DETERMINE IF A CHANNEL E~ISTS. WELL HAD BEEN LOADED TWO DAYS PRIOR TO LOGGING AND ONLY 15 BBLS OF CRUDE HAD BEEN PUMPED PRIOR TO THE FIRST PASS. NEAR WELLBORE GAS WAS HIGH ON PASS ONE, SO IT WAS NOT PRESENTED OR AVERAGED. VOLUMES PUMPED: BORAX=138 BBLS, CRUDE=142 BBLS, DIESEL= 10 BLS, [4ETHANOL= 5 BBLS. APPROXIMATE G0C=10458'. NO UNDERRUNS WERE OBSERVED. THERE IS AN UPCHANNEL FROM THE TOP OF THE PERFORATIONS AT 10451 ' TO 10432' WHICH IS WELL UP INTO THE GAS CAP. THE GAS OIL CONTACT APPEARS TO MOVE DOWN INTO THE PERFORATED INTERVAL. THE FIRST THREE PASSES WERE LOGGED ON A SANDSTONE MATRIX. THE THREE BORAX PASSES WERE LOGGED ON A LIMESTONE MATRIX. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS1 CU 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS1 PU 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 4O NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SBHF PS1 CU 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 SBHN PSi CU 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PSi CU 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PS1 CU 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS1 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 LCO1 PS1 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PS1 CU 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 BACK PS1 CPS 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS1 CPS 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 TCAN PS1 CPS 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF PS1 CPS 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 TCND PS1 CPS 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD PSi CPS 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN PS1 CPS 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PS1 CPS 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 INND PS1 CPS 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 INFD PS1 CPS 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS1 LB 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS1 GAPI 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS1 V 1173638 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 10550.000 SIGM. PS1 14.227 TPHI.PS1 26.311 SBHF. PS1 SBHN. PS1 73.476 SIGC. PS1 0.640 SIBH. PS1 104.563 TRAT. PS1 LCO1.PS1 2.208 SDSI.PS1 0.355 BACK. PSI 124.714 FBAC. PS1 TCAN. PS1 23363.695 TCAF. PS1 10579.582 TCND.PS1 19323.805 TCFD. PS1 TSCN. PS1 4844.073 TSCF. PS1 2193.500 INND.PS1 1706.672 INFD.PS1 TENS. PSi 1290.000 GR.PS1 87.313 CCL.PS1 0.000 DEPT. 10050.000 SIGM. PS1 19.074 TPHI.PS1 22.575 SBHF. PS1 SBHN. PS1 38.549 SIGC. PS1 2.533 SIBH. PS1 38.549 TRAT. PS1 LCO1.PS1 2.255 SDSI.PS1 0.654 BACK. PSi 157.416 FBAC. PS1 TCAN. PS1 32167.637 TCAF. PS1 14264.412 TCND. PS1 26475.992 TCFD. PS1 TSCN. PS1 6551.476 TSCF. PS1 2905.186 INND.PS1 1799.745 INFD. PS1 TENS.PSi 1210.000 GR.PS1 121.000 CCL.PS1 0.000 62.269 1.670 41.492 6339.681 275.493 29.217 1. 602 35. 526 9291. 764 344. 330 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 41 **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE · FLIC VERSION · O0!CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AFUlVi~ER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10574.0 10049.5 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~94A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 26-0CT-97 CP 44,2 1138 26-0CT-97 10555.0 10562.0 10050.0 1 0542.0 1800.0 TOOL NUMBER CGRS 862 TDT SET 396 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 42 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 10681.0 CRUDE/BORAX 10.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED IN TO WA BHC DATED 3-MAY-93. THE PURPOSE OF THIS LOG WAS TO FIND THE CURRENT GOC, ANY GAS UNDERRUNS, AND DETERMINE IF A CHANNEL EXISTS. WELL HAD BEEN LOADED TWO DAYS PRIOR TO LOGGING AND ONLY 15 BBLS OF CRUDE HAD BEEN PUMPED PRIOR TO THE FIRST PASS. NEAR WELLBORE GAS WAS HIGH ON PASS ONE, SO IT WAS NOT PRESENTED OR AVERAGED. VOLUMES PUMPED: BORAX=138 BBLS, CRUDE=142 BBLS, DIESEL= 10 BLS, METHANOL= 5 BBLS. APPROXIMATE G0C=10458'. NO UNDERRUNS WERE OBSERVED. THERE IS AN UPCHANNEL FROM THE TOP OF THE PERFORATIONS AT 10451' TO 10432' WHICH IS WELL UP INTO THE GAS CAP. THE GAS OIL CONTACT APPEARS TO MOVE DOWN INTO THE PERFORATED INTERVAL. THE FIRST THREE PASSES WERE LOGGED ON A SANDSTONE MATRIX. THE THREE BORAX PASSES WERE LOGGED ON A LIMESTONE MATRIX. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 43 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS2 CU 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS2 PU 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PS2 CU 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 SBP~N PS2 CU 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PS2 CU 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS2 CU 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS2 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 LCO1 PS2 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PS2 CU 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 BACK PS2 CPS 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS2 CPS 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 TCAN PS2 CPS 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 TCAF PS2 CPS 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 TCND PS2 CPS 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PS2 CPS 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PS2 CPS 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS2 CPS 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 INND PS2 CPS 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PS2 CPS 1173638 O0 000 O0 0 9 1 i 4 68 0000000000 TENS PS2 LB 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS2 GAPI 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS2 V 1173638 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 44 ** DATA ** DEPT. 10550.000 SIGM. PS2 14.100 TPHI. PS2 25.565 SBHF. PS2 SBH~.PS2 72.287 SIGC. PS2 0.879 SIBH. PS2 101.714 TRAT. PS2 LCO1.PS2 2.157 SDSI.PS2 0.378 BACK. PS2 178.635 FBAC. PS2 TCAN. PS2 23642.859 TCAF.PS2 10959.363 TCND. PS2 19031.941 TCFD. PS2 TSCN. PS2 4736.452 TSCF. PS2 2195.526 INND.PS2 1755.982 INFD.PS2 TENS.PS2 1260.000 GR.PS2 117.500 CCL.PS2 0.000 DEPT. 10049.500 SIGM. PS2 19.903 TPHI.PS2 22.783 SBHF. PS2 SBP~N. PS2 40.918 SIGC. PS2 2.166 SIBH. PS2 40.918 TRAT. PS2 LCO1.PS2 2.260 SDSI.PS2 0.602 BACK. PS2 186.355 FBAC. PS2 TCAN. PS2 34496.602 TCAF. PS2 15261.115 TCArD.PS2 28005.762 TCFD. PS2 TSCN. PS2 6979.813 TSCF. PS2 3087.832 INND.PS2 1759.453 INFD. PS2 TENS.PS2 1235.000 GR.PS2 125.688 CCL.PS2 0.000 61 . 636 1. 652 47. 991 6278. 481 293. 355 32.006 1.591 44.327 9967.117 393.436 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT . O10 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIM~ER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS~BER: 3 DEPT~ INCRE~IENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 45 TDTP 10574.0 $ LOG H~ER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 10049.0 26-0CT-97 CP 44.2 1138 26-0CT-97 10555.0 10562.0 10050.0 10542.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA;4MA RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS 862 TDT SET 396 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10681.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE/BORAX 10.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 46 REMARKS: TIED IN TO WA BHC DATED 3-MAY-93. THE PURPOSE OF THIS LOG WAS TO FIND THE CURRENT GOC, ANY GAS UNDERRUNS, AND DETERMINE IF A CHANNEL EXISTS. WELL HAD BEEN LOADED TWO DAYS PRIOR TO LOGGING AND ONLY 15 BBLS OF CRUDE HAD BEEN PUMPED PRIOR TO THE FIRST PASS. NEAR WELLBORE GAS WAS HIGH ON PASS ONE, SO IT WAS NOT PRESENTED OR AVERAGED. VOLU~iES PUMPED: BORAX=138 BBLS, CRUDE=142 BBLS, DIESEL= 10 BLS, METHANOL= 5 BBLS. APPROXIMATE G0C=10458'. NO UNDERRUNS WERE OBSERVED. THERE IS AN UPCHANNEL FROM THE TOP OF THE PERFORATIONS AT 10451 t TO 10432' WHICH IS WELL UP INTO THE GAS CAP. THE GAS OIL CONTACT APPEARS TO MOVE DOWN INTO THE PERFORATED INTERVAL. THE FIRST THREE PASSES WERE LOGGED ON A SANDSTONE MATRIX. THE THREE BORAX PASSES WERE LOGGED ON A LIMESTONE MATRIX. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 8 9 11 12 13 14 15 16 0 0.5 FT 11 65 68 65 66 68 66 0 65 FT 66 68 66 1 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 47 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS3 CU 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS3 PU 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF PS3 CU 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 SBHNPS3 CU 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS3 CU 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS3 CU 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS3 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 LCO1 PS3 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS3 CU 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS3 CPS 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS3 CPS 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 TCANPS3 CPS 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 TCAFPS3 CPS 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 TCNDPS3 CPS 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS3 CPS 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN PS3 CPS 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS3 CPS 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 INND PS3 CPS 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 INFDPS3 CPS 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS3 LB 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS3 GAPI 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS3 V 1173638 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 10550.000 SIGM. PS3 15.397 TPHI.PS3 32.040 SBHF. PS3 63.277 SBH~.PS3 71.812 SIGC. PS3 0.905 SIBH. PS3 106.385 TRAT. PS3 1.788 LCO1.PS3 2.371 SDSI.PS3 0.390 BACK. PS3 210.103 FBAC. PS3 54.950 TCAN. PS3 25201.473 TCAF. PS3 10627.900 TCND. PS3 20383.727 TCFD. PS3 6280.193 TSCN. PS3 5029.094 TSCF. PS3 2120.856 INND. PS3 1787.309 INFD. PS3 296.340 TENS. PS3 1310.000 GR. PS3 115.625 CCL.PS3 0.000 DEPT. 10049.000 SIGM. PS3 20.118 TPHI.PS3 27.509 SBHF. PS3 31.193 SBHN. PS3 40.880 SIGC. PS3 3.054 SIBH. PS3 40.880 TRAT. PS3 1.715 LCO1.PS3 2.498 SDSI.PS3 0.696 BACK. PS3 207.856 FBAC. PS3 46.746 TCAN. PS3 32551.941 TCAF. PS3 13033.248 TCND.PS3 27655.738 TCFD. PS3 9089.510 TSCN. PS3 6553.791 TSCF. PS3 2624.027 INND. PS3 1882.386 INFD. PS3 410.094 TENS.PS3 1250.000 GR.PS3 136.875 CCL.PS3 0.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 48 **** FILE TRAILER FILE NA~E : EDIT . O10 SERVICE · FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE · 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : TDTP LOG HEADER DATA FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in iasc file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMFZARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10574.0 10044.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 26-0CT-97 CP 44.2 1138 26-0CT-97 10555.0 10562.0 10050.0 10542.0 1800.0 TOOL NUMBER CGRS 862 TDT SET 396 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 49 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 10681.0 CR UDE/BORAX 10.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL LIMESTONE 2.71 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): RE~L~gKS: TIED IN TO WA BHC DATED 3-MAY-93. THE PURPOSE OF THIS LOG WAS TO FIND THE CURRENT GOC, ANY GAS UNDERRUNS, AND DETERMINE IF A CHANNEL EXISTS. WELL HAD BEEN LOADED TWO DAYS PRIOR TO LOGGING AND ONLY 15 BBLS OF CRUDE HAD BEEN PUMPED PRIOR TO THE FIRST PASS. ~ WELLBORE GAS WAS HIGH ON PASS ONE, SO IT WAS NOT PRESENTED OR AVERAGED. VOLUMES PUMPED: BORAX=138 BBLS, CRUDE=142 BBLS, DIESEL= 10 BLS, METHANOL= 5 BBLS. APPROXIMATE G0C=10458'. NO UNDERRUNS WERE OBSERVED. THERE IS AN UPCHANNEL FROM THE TOP OF THE PERFORATIONS AT 10451' TO 10432' WHICH IS WELL UP INTO THE GAS CAP. THE GAS OIL CONTACT APPEARS TO MOVE DOWN INTO THE PERFORATED INTERVAL. THE FIRST THREE PASSES WERE LOGGED ON A SANDSTONE MATRIX. THE THREE BORAX PASSES WERE LOGGED ON A LIMESTONE MATRIX. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 5O ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM BX1 CU 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI BX1 PU 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF BX1 CU 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 SBHNBX1 CU 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC BX1 CU 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH BX1 CU 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT BX1 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 LCO1 BX1 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI BX1 CU 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 BACK BX1 CPS 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC BX1 CPS 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 TCANBX1 CPS 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 TCAFBX1 CPS 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 TCNDBX1 CPS 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD BX1 CPS 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN BX1 CPS 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF BX1 CPS 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 INNDBX1 CPS 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 INFD BX1 CPS 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 TENS BX1 LB 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 GR BX1 GAPI 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 CCL BX1 V 1173638 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 51 ** DATA ** DEPT. 10550 SBHN. BX1 73 LCO1.BX1 2 TCAN. BX1 23319 TSCN. BX1 4654 TENS.BX1 1275 000 SIGM. BX1 15.311 TPHI.BX1 21.448 SBHF.BX1 278 SIGC.BX1 0.684 SIBH. BX1 102.498 TRAT. BX1 183 SDSI.BX1 0.394 BACK. BX1 219.940 FBAC. BX1 637 TCAF.BX1 10681.682 TCND.BX1 19328.582 TCFD.BX1 763 TSCF.BX1 2132.139 INND.BX1 1776.988 INFD.BX1 000 GR.BX1 115.563 CCL.BX1 0.000 DEPT. 10043.500 SBt{N. BX1 87.473 LCO1.BX1 2.052 TCAN. BX1 9361.344 TSCN. BX1 1888.879 TENS.BX1 1205.000 SIGM. BX1 SIGC.BX1 SDSI.BX1 TCAF. BX1 TSCF.BX1 GR.BX1 23 529 1 017 0 958 4562 321 920 559 221 375 65.779 1.659 50.851 6239.072 299.439 TPHI.BX1 20.794 SBHF. BX1 67.938 SIBH. BX1 129.694 TRAT. BX1 1.374 BACK. BX1 203.489 FBAC. BX1 51.313 TCND.BX1 10825.113 TCFD.BX1 3711.351 INND.BX1 1588.050 INFD.BX1 272.105 CCL.BX1 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NANZE : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 52 TDTP 10574.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 10045.0 26-0CT-97 CP 44.2 1138 26-0CT-97 10555.0 10562.0 10050.0 10542.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR G~ RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS 862 TDT SET 396 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 10681 . 0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE/BORAX 10.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL LIMESTONE 2.71 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAi9 COU1TT RATE HIGH SCALE (CPS): 13000 ~ COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 53 REMARKS: TIED IN TO WA BHC DATED 3-MAY-93. THE PURPOSE OF THIS LOG WAS TO FIND THE CURRENT GOC, ANY GAS UNDERRUNS, AND DETERMINE IF A CHANNEL EXISTS. WELL HAD BEEN LOADED TWO DAYS PRIOR TO LOGGING AND ONLY 15 BBLS OF CRUDE HAD BEEN PUMPED PRIOR TO THE FIRST PASS. NEAR WELLBORE GAS WAS HIGH ON PASS ONE, SO IT WAS NOT PRESENTED OR AVERAGED. VOLUMES PUMPED: BORAX=138 BBLS, CRUDE=142 BBLS, DIESEL= 10 BLS, ~ETHANOL= 5 BBLS. APPROXIMATE G0C=10458'. NO UNDERRUNS WERE OBSERVED. THERE IS AN UPCHANNEL FROM THE TOP OF THE PERFORATIONS AT 10451' TO 10432' WHICH IS WELL UP INTO THE GAS CAP. THE GAS OIL CONTACT APPEARS TO MOVE DOWN INTO THE PERFORATED INTERVAL. THE FIRST THREE PASSES WERE LOGGED ON A SANDSTONE MATRIX. THE THREE BORAX PASSES WERE LOGGED ON A LIMESTONE MATRIX. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 92 66 1 66 0.5 FT 11 0 FT 68 1 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 54 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM BX2 CU 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI BX2 PU 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF BX2 CU 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 SBHNBX2 CU 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC BX2 CU 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 SIBH BX2 CU 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT BX2 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 LCO1 BX2 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI BX2 CU 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 BACK BX2 CPS 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC BX2 CPS 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 TCANBX2 CPS 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 TCAFBX2 CPS 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 TCNDBX2 CPS 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 TCFDBX2 CPS 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 TSCN BX2 CPS 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 TSCF BX2 CPS 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 INNDBX2 CPS 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 INFD BX2 CPS 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 TENS BX2 LB 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 GR BX2 GAPI 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 CCL BX2 V 1173638 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 10550.000 SIGM. BX2 15.680 TPHI.BX2 33.849 SBHF. BX2 65.565 SBHN. BX2 71.152 SIGC.BX2 0.542 SIBH. BX2 107.601 TRAT. BX2 1.884 LCO1.BX2 2.497 SDSI.BX2 0.440 BACK.BX2 211.623 FBAC.BX2 55.002 TCAN. BX2 25064.848 TCAF. BX2 10038.523 TCND.BX2 19822.922 TCFD.BX2 5959.592 TSCN. BX2 5001.945 TSCF. BX2 2003.290 INND.BX2 1761.227 INFD.BX2 270.964 TENS.BX2 1260.000 GR.BX2 120.000 CCL.BX2 0.000 DEPT. 10045.000 SIGM. BX2 23 191 TPHI.BX2 26.532 SBHF. BX2 66.588 SBHN. BX2 86.804 SIGC.BX2 1 267 SIBH.BX2 140.127 TRAT. BX2 1.489 LCO1.BX2 2.256 SDSI.BX2 0 960 BACK.BX2 216.504 FBAC. BX2 50.888 TCAN. BX2 9567.600 TCAF. BX2 4240 685 TCND.BX2 10773.146 TCFD.BX2 3446.601 TSCN. BX2 1939.566 TSCF. BX2 859 762 INND.BX2 1618.199 INFD.BX2 279.569 TENS.BX2 1155.000 GR.BX2 252 500 CCL.BX2 0.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 55 **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 M_AXREC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIJAfBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS I~J~fBER : 6 DEPTH INCREMENT: O. 5000 FILE SU~mfARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10573.5 10033.5 TDTP $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 26-0CT-97 CP 44.2 1138 26-0CT-97 10555.0 10562.0 10050.0 10542.0 1800.0 TOOL NUMBER CGRS 862 TDT SET 396 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 56 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10681.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE~BORaX 10.0 ArEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL LIMESTONE 2.71 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED IN TO WA BHC DATED 3-MAY-93. THE PURPOSE OF THIS LOG WAS TO FIND THE CURRENT GOC, ANY GAS UNDERRUNS, AND DETERMINE IF A CHANNEL EXISTS. WELL HAD BEEN LOADED TWO DAYS PRIOR TO LOGGING AND ONLY 15 BBLS OF CRUDE HAD BEEN PUMPED PRIOR TO THE FIRST PASS. NEAR WELLBORE GAS WAS HIGH ON PASS ONE, SO IT WAS NOT PRESENTED OR AVERAGED. VOLUMES PUMPED: BORAX=138 BBLS, CRUDE=142 BBLS, DIESEL= 10 BLS, METHANOL= 5 BBLS. APPROXIMATE G0C=10458'. NO UNDERRUNS WERE OBSERVED. THERE IS AN UPCHANNEL FROM THE TOP OF THE PERFORATIONS AT 10451' TO 10432' WHICH IS WELL UP INTO THE GAS CAP. THE GAS OIL CONTACT APPEARS TO MOVE DOWN INTO THE PERFORATED INTERVAL. THE FIRST THREE PASSES WERE LOGGED ON A SANDSTONE MATRIX. THE THREE BORAX PASSES WERE LOGGED ON A LIMESTONE MATRIX. THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 57 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM BX3 CU 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI BX3 PU 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 SBHF BX3 CU 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 SBHNBX3 CU 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 SIGC BX3 CU 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 SIBH BX3 CU 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT BX3 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 LCO1 BX3 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 SDSI BX3 CU 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 BACK BX3 CPS 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC BX3 CPS 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 TCANBX3 CPS 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 TCAFBX3 CPS 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 TCNDBX3 CPS 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 TCFD BX3 CPS 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 TSCN BX3 CPS 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 TSCF BX3 CPS 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 INNDBX3 CPS 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 INFD BX3 CPS 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 TENS BX3 LB 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 GR BX3 GAPI 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 CCL BX3 V 1173638 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1998 10:05 PAGE: 58 ** DATA ** DEPT. 10550.000 SIGM. BX3 16.875 TPHI.BX3 33.108 SBHF. BX3 SBPZN. BX3 70.928 SIGC.BX3 0.885 SIBH.BX3 104.671 TRAT. BX3 LCO1.BX3 2.471 SDSI.BX3 0.456 BACK.BX3 223.985 FBAC.BX3 TCAN. BX3 23022.848 TCAF. BX3 9315.580 TCND.BX3 19958.352 TCFD.BX3 TSCN. BX3 4571.224 TSCF. BX3 1849.624 INND.BX3 1849.771 INFD.BX3 TENS.BX3 1290.000 GR.BX3 137.875 CCL.BX3 0.000 DEPT. 10040.000 SIGM. BX3 33.888 TPHI.BX3 44.064 SBHF. BX3 SBI{N. BX3 93.356 SIGC.BX3 0.394 SIBH.BX3 157.084 TRAT. BX3 LCO1.BX3 2.711 SDSI.BX3 1.725 BACK.BX3 203.822 FBAC.BX3 TCAN. BX3 9041.447 TCAF. BX3 3169.637 TCND.BX3 9079.486 TCFD.BX3 TSCN. BX3 938.128 TSCF. BX3 346.106 INND.BX3 1868.928 INFD.BX3 TENS.BX3 1165.000 GR.BX3 174.125 CCL.BX3 0.000 63.516 1.824 64.470 5987.148 306.920 81.144 1.447 49.027 2559.988 284.602 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION · O01CO1 DATE · 98/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/02/24 ORIGIN : FLIC TAPE NAME : 98093 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, D.S. 6-22A, PRUDHOE BAY, 50-029-20806-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/02/24 ORIGIN : FLIC REEL NAME : 98093 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, D.S. 6-22A, PRUDHOE BAY, 50-029-20806-01 i i I I I I /.9901, ~i 9IN OIO~tFI'IINFI-IQ ~66 I,'/[elN- 80 · I, un~l 8,1.eQ Q IHII:IOU:)Ii AV~I ~lOH(lf~~ld Vi~Z ' 9 'S'(I DNI V SV IV ODh'V i i i Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: RUN1 5949.00 R. ECK K. HUDSON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING D.S. 6 - 22A 500292080601 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 21-MAY-93 9.625 9297.0 8.500 10682.0 CIRCULATION STOPPED @ 19:00 02-MAY-93. DEPTH ADJUSTED TO ORIGINAL K.B. OF 74' (12' ABOVE DOYON RIG 16 K.B. OF 62'). NEUTRON IS CALIPER CORRECTED, NO CASING CORRECTIONS AND CHISM FILTERING NOT ACTIVE. DUE TO COMPUTER ERROR, THE COMPUTED NEUTRON CURVES (CN & CNC) RECORDED IN THE FIELD WERE INCORRECT (CURVES ON BLUELINE ARE OK, PROBLEM OCCURRED WHEN WRITING DATA TO TAPE). USING THE RAW COUNT CURVES, THE CN & CNC CURVES WERE RE- GENERATED IN THE ANCHORAGE LAC. REMARKS: CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2 10N 14E 584 985 74.00 RUN2 RUN3 FILE HEADER. FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS DEPTH INCREMENT: 0.5000 FILE SUMMARY TOOL CODE GR DLL BCS 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA START DEPTH 9290.0 9290.0 9290.0 9290.0 GR (MEASURED DEPTH) BASELINE DEPTH MLL 9290.0 9290.0 9303.0 9306.0 9306.0 9315.0 9315.5 9318.0 9318.5 9319.0 9321.0 9321.0 9327.0 9327.5 9334.5 9336.0 9339.0 9344.0 9344.0 9349.5 9349.0 9352.5 9355.5 9354.5 9357.5 9357.0 9358.0 9359.5 9360.0 9359.0 9362.0 9364.5 9364.5 9370.0 9370.0 9372.0 9376.0 9376.5 9378.0 9378.5 9380.0 9381.0 9387.0 9388.0 9387.5 9391.0 9401.5 9402.0 9402.0 9410.0 9411.5 9429.5 9435.0 9437.0 9437.5 9440.0 9440.5 9447.5 9448.0 STOP DEPTH 10585.0 10667.0 10649.0 10592.0 EQUIVALENT UNSHIFTED DEPTH LL3 DT NPHI 9290.0 9290.0 9290.0 9303.0 9317.5 9320.0 9319.0 9320.0 9322.0 9328.5 9330.0 9334.5 9338.0 9341.0 9344.5 9343.5 9350.5 9354.5 9358.0 9357.0 9359.5 9359.0 9360.5 9362.0 9369.5 9372.5 9378.5 9378.0 9381.5 9387.0 9387.5 9390.0 9401.5 9402.0 9401.0 9447.5 9411.0 9429.5 9437.0 9411.5 9435.0 9437.0 9447.5 9447.5 9448.5 9459.0 9459.5 9461.0 9465.0 9474.5 9488.5 9489.0 9504.0 9506.0 9523.0 9535.5 9544.5 9555.0 9558.0 9561.0 9566.0 9580.0 9589.5 9608.5 9609.0 9618.0 9625.0 9639.0 9639.5 9640.0 9642.0 9647.0 9649.0 9656.5 9672.0 9682.5 9701.5 9702.0 9710.0 9713.5 9714.0 9719.5 9733.5 9734.5 9735.0 9738.5 9742.0 9742.5 9750.0 9751.5 9752.0 9754.0 9756.5 9757.0 9770.5 9771.0 9775.5 9778.5 9779.0 9785.0 9800.5 9803.5 9804.0 9810.0 9449.0 9460.5 9490.0 9522.5 9544.0 9566.0 9581.0 9625.0 9640.5 9642.5 9649.5 9672.0 9713.5 9734.0 9742.5 9751.5 9756.5 9774.0 9777.5 9780.5 9805.5 9489.0 9580.0 9608.5 9639.5 9672.0 9701.0 9735.0 9741.0 9751.0 9779.5 9803.5 9459.5 9489.0 9535.5 9580.5 9607.5 9617.0 9625.5 9672.5 9683.0 9701.5 9710.0 9714.5 9749.5 9752.0 9757.5 9771.0 9779.0 9785.0 9459.5 9465.0 9474.0 9488.5 9503.5 9505.5 9536.0 9555.5 9559.0 9561.0 9580.5 9589.0 9609.0 9617.0 9625.0 9638.5 9647.5 9658.5 9674.0 9685.0 9701.0 9714.5 9719.5 9733.0 9738.5 9743.0 9751.5 9753.0 9756.0 9771.5 9803.5 9812.5 9832.0 9832.5 9835.0 9862.0 9884.5 9885.5 9966.5 9984.0 10015.0 10015.5 10019.0 10021.0 10025.5 10026.0 10026.5 10034.5 10036.0 10036.5 10037.0 10049.5 10070.0 10079.5 10080.0 10081.0 10081.5 10084.5 10089.5 10101.5 10113.5 10147.0 10165.0 10165.5 10176.5 10187.0 10190.0 10198.5 10204.5 10225.5 10226.0 10232.0 10236.5 10238.5 10239.0 10241.5 10245.5 10251.0 10259.5 10286.5 10300.5 10326.5 10331.5 10361.0 10361.5 10379.5 10400.0 10405.0 10411.5 10412.0 10434.0 10458.0 9832.0 9862.5 9984.0 10014.0 10025.5 10033.5 10035.5 10069.0 10080.0 10081.0 10086.0 10100.0 10164.0 10176.0 10186.5 10198.0 10204.0 10225.5 10240.0 10245.5 10251.5 10285.5 10300.5 10411.5 10458.5 9831.5 9884.0 10015.5 10018.5 10020.5 10026.0 10034.0 10036.5 10038.0 10050.0 10069.5 10081.0 10083.0 10086.5 10089.5 10113.0 10146.5 10164.5 10175.0 10186.0 10198.0 10231.0 10235.0 10238.5 10240.5 10244.5 10258.5 10326.5 10331.5 10360.5 10378.5 10400.0 10411.0 9833.0 9966.0 10015.0 10081.0 10113.5 10186.5 10198.0 10225.5 10259.5 10361.0 10379.5 10412.5 10459.0 9831.5 9835.0 9885.5 10016.0 10025.5 10080.0 10081.5 10113.0 10176.5 10190.0 10237.5 10244.5 10300.5 10379.0 10404.5 10411.5 10433.0 10479.5 10480.0 10480.0 10498.5 10499.0 10498.5 10500.0 10500.0 10503.5 10503.5 10504.5 10513.5 10514.5 10515.0 10522.0 10527.5 10528.5 10528.0 10537.5 10538.0 10553.5 10554.0 10554.0 10563.0 10562.5 10614.0 10614.0 10696.0 10696.0 10696.0 $ MERGED DATA SOURCE TOOL CODE RUN NO. PASS NO. GR 1 2 DLL 1 2 BCS 1 2 2435 1 2 $ REMARKS: CN WN FN COUN STAT 10480.0 10529.0 10553.5 10696.0 10498.5 10512.5 10522.0 10526.5 10537.5 10696.0 MERGE TOP 9290.0 9290.0 9290.0 9290.0 OPEN HOLE PORTION MAIN PASS. TENS, TEND, & CALl WERE SHIFTED WITH MLL. LLD & SP WERE SHIFTED WITH LL3. FUCT & NUCT WERE SHIFTED WITH NPHI. $ : ARCO ALASKA INCORPORATED : D.S. 6 - 22A : PRUDHOE BAY : NORTH SLOPE : ALASKA MERGE BASE 10585.0 10667.0 10649.0 10592.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 Name Tool Code Samples Units GR BCS 68 1 GAPI DT BCS 68 1 US/F TEND BCS 68 1 LB TENS BCS 68 1 LB CALl DLL 68 1 IN MLL DLL 68 1 OHMM LL3 DLL 68 1 OHMM LLD DLL 68 1 OHMM SP DLL 68 1 MV NPHI 2435 68 1 PU-S FUCT 2435 68 1 CPS NUCT 2435 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 * DATA RECORD (TYPE# 0) Total Data Records: 149 994 BYTES * 48 Tape File Start Depth = 10696.000000 Tape File End Depth = 9290.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 36570 datums Tape Subfile: 2 410 records... Minimum record length: 58 bytes Maximum record length: 994 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 9148.0 BCS 9238.0 2435 9154.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH DT 9120.0 9120.0 9196.5 9213.0 9244.5 9244.0 9254.5 9254.5 9276.0 9276.5 9281.5 9285.0 9285.5 9290.0 9290.0 $ REMARKS: CN WN FN COUN STAT STOP DEPTH 9290.0 9290.0 9290.0 EQUIVALENT UNSHIFTED DEPTH NPHI 9120.0 9196.5 9212.5 9256.0 9276.5 9282.5 9285.0 9290.0 CASED HOLE PORTION MAIN PASS. FUCT, NUCT, TEND, & TENS WERE SHIFTED WITH NPHI. $ : ARCO ALASKA INCORPORATED : D.S. 6 - 22A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units GRCH BCS 68 1 GAPI DT BCS 68 1 US/F TEND BCS 68 1 LB TENS BCS 68 1 LB NPHI 2435 68 1 PU-S FUCT 2435 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 98 211 23 1 4 98 211 23 1 7 NUCT 2435 68 1 CPS 4 4 98 211 23 1 * DATA RECORD (TYPE# 0) Total Data Records: 11 998 BYTES * 28 Tape File Start Depth = 9290.000000 Tape File End Depth = 9120.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2729 datums Tape Subfile: 3 48 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9148.0 DLL 9290.0 MLL AC 2435 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 9278.0 9238.0 9154.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB MASS ISOLATION SUB BHC-ACOUSTILOG MICRO LATEROLOG CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS FTS MIS AC MLL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: STOP DEPTH 10607.0 10639.0 10688.0 10670.0 10613.0 03-MAY-93 FSYS REV. J001 VER. 1.1 1900 02-MAY-93 434 03-MAY-93 10682.0 10672.0 9150.0 10667.0 1500.0 TOOL NUMBER 3974NA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967NA 1229EA/1229MA 3967NA 1609EA/1603MA 1233XA 8.500 9297.0 9290.0 KCL POLY MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: MAIN PASS. NEUTRON IS CALIPER CORRECTED. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 6 - 22A : PRUDHOE BAY : NORTH SLOPE : ALASKA 10.00 48.0 10.0 6.8 186.0 0.135 0.051 0.113 0.000 0.155 0.000 THERMAL SANDSTONE 0.00 0.000 0.0 70.0 186.0 65.0 0.0 60.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Name Tool Code Samples Units GR AC 68 1 GAPI AC AC 68 1 US/F CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN CAL MLL 68 1 IN RMLL MLL 68 1 OHMM RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV ED DLL 68 1 MV ES DLL 68 1 MV ID DLL 68 1 A IS DLL 68 1 A CNC 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 06 969 49 6 4 48 852 89 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 90 132 02 1 4 71 857 46 1 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 84 023 70 1 18 SSN 2435 68 1 CPS 4 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 485 994 BYTES * 72 Tape File Start Depth = 10696.000000 Tape File End Depth = 9120.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 156366 datums Tape Subfile: 4 571 records... Minimum record length: Maximum record length: 62 bytes 994 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9963.0 DLL 9996.0 MLL AC 2435 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 10045.0 10026.0 9969.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CABLEHEAD TENSION TEMPERATURE GAMMARAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB MASS ISOLATION SUB BHC-ACOUSTILOG MICRO LATEROLOG CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS FTS MIS AC MLL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): STOP DEPTH 10609.0 10641.0 10690.0 10672.0 10615.0 03-MAY-93 FSYS REV. J001 VER. 1.1 1900 02-MAY-93 400 03-MAY-93 10682.0 10672.0 9150.0 10667.0 1500.0 TOOL NUMBER 3974NA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967NA 1229EA/1229MA 3967NA 1609EA/1603MA 1233XA 8.500 9297.0 9290.0 KCL POLY 10.00 48.0 MUD PH: FLUID~LOSS. (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: REPEAT PASS. NEUTRON IS CALIPER CORRECTED. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 6 - 22A : PRUDHOE BAY : NORTH SLOPE : ALASKA 10.0 6.8 186.0 0.135 0.051 0.113 0.000 0.155 0.000 THERMAL SANDSTONE 0.00 0.000 0.0 70.0 186.0 65.0 0.0 60.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 GR AC 68 1 GAPI AC AC 68 1 US/F CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN CAL MLL 68 1 IN RMLL MLL 68 1 OHMM RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV ED DLL 68 1 MV ES DLL 68 1 MV ID DLL 68 1 A IS DLL 68 1 A CNC 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 06 969 49 6 4 48 852 89 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 90 132 02 1 4 71 857 46 1 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 84 023 70 1 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 234 994 BYTES * 72 Tape File Start Depth = 10698.000000 Tape File End Depth = 9938.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 60509 datums Tape Subfile: 5 318 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 6 is type: LIS 93/ 5/21 01 **** REEL TRAILER **** 93/ 5/25 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 25 MAY 93 9:48a Elapsed execution time = 1 minute , 0.2 seconds. SYSTEM RETURN CODE = 0 IS Tane Verification Listlno chlumher%ler A!asKa'ComPutlno Center 26-0CT-1994 20:40 **** REEL SERVICE NA~ : ~DIT ONTINU~T!O~! ~E¥IOU~ REEL : C~M"ENT : ARCO ALASKA INC,, PRUDHOE BAY, DS 6-~2A, 500~9~08060! 8~RVICE NAME ~ EDIT DATE : 94/06/~1 OPIGIN : FS!C T~P~ NA~E . : 94~9 P~EwIOUS TA~E : CO~E~T : ARCO ALASKA !NC.., PRUD~OE BAY, DS 6-~2A, 50029~08060! T~PF ~EAD~R PmUDHOE CASED HOLE WlRELINE 50GS WFL!., AoI OPErATOr: LOGCING COMPANY: TAP~ CREATION DATE: jOB NU~BE~: L~GCING ENGINEEP: OPE~ATO~ WITNESS: S~RFACE LOCATION S~CTION: TOWNSWIP: Ra~OE: F~b: ESL: FWL: EL~VATIO~(F~ ~0~ ~Sb ~ELLY RUSHI~C: CRoU~D L~VFL: 500:29208060! ARCO A~ASKA 21-jUN-94 94219 T, J, HEUSSER 7~,00 73,00 CURVE S~I~T !.)AT.~ - ~L~.~ PASSES TO ST~DA~D(~MASU~ED DEPTH) OPE~} HOLE CASINR DRILLERS CASING BIT SIZE (IN) SIZE (iN) DEPTH (F~) WEIGHT (LB/ET) ................9. ~ .... ;':~'''2.~ ~~''' ..... 7,000 10681.0 ~9.00 3.500 9681.0 9.30 I$ Tat~e Verl, ficatlo~ !,istlng chlumberger AlaSKa Comp!It!no Center !0513 0 ~0480 0 ~045~,S I045~,0 ~0442,~ )0439.S ~0437.5 ~0434,0 ~.0420 0 )0411 5 ~.04!0 0 10380 5 ~036! 0 ~0360 ~ 0~00, 10~69. ~0269.0 ~0~5~.5 10~53.5 ~0~45.0 t0~27.0 ~0226 5 !0204~5 0199,~ 0~85.0 ~0~77.0 ~0~66,0 ~0~4~.0 ~0~47.5 .0~0.5 ~0~,5 ~0~03.0 ~0~1.5 26-0CT-!9~4 20:40 ----------E~UI'VahEMT UN6HIFTED DEPTH-----.---'- GRC~ CNTD 888 . 1~513.5 ~.049~.5 10480.5 ~045~.5 10444,0 !0440,0 ~0437.0 ~0437.0 104~0,5 ~041~,5 t030~.0 ~0269.5 10~69.5 10260.0 10~54,5 %0~45.5 ~0~45.S 10~]9.0 10~39.5 !0~2~,0 ~0~26.n ~0~04,5 ~0~04,5 !0~9~,0 !0~84.5 1.0166.0 !0~47.5 !.0145.5 10113.0 1010~.5 !O~.O0.n 9~.5 10177.0 10166.0 10147.5 !0!.38.5 101.14.0 99.5 I~FORMATION PERTAINING TO TNE SPEW MOLE TIE-IN LOG, LOGGING CO~!PA~Y~vbOGG?NG DATE RUN NUMBMR AND ~,U~BFR WFR~ NOW PR~ TD~D"WIT~ TH~ TAPE SUPPLIED BY PAGE) 2 MICROFILMED iS ~a~e Verification List'!nc chlum~erger AlasKa Computln~ Cente~ 26-0C?-~994 20:40 TEE CLIENT. THE DEPTH C~R~ECTIONS SHOWN ABOVE REFLECT CASED HOLE GR TO mPE~ HOL~ GR AN[) C.~SED HOLE NP~I TO OPEN HOLE ~R ALL OTHER CNTD CURVES ~EE CARRIED WITH TEE NPHI SH~FT$ $ PAGE~ **** FILM HEADER **** F~bF NA~ : EDIT ,001 8FR¥ICE : FL!C ~ERSION : 001C01 F!L~ TYPE : LO LAST FILE F%LT FIbF NU~ER: EDITED CURVES DePth Shifted and cl~pped curves for each Pass ~D seParate~tles, P~S~ NU~S~R~ 1 D~PTH IMC~EMENT~ 0.5000 FTL~ SUUNARY LDWG TOOD CODE START DEPT~ STOP.DEPTH ~'''''''''''. H '''''~''''',0~I0 0 ~;'';~;'''10 CNTD !052],0 10100.0 CURVE S"IFT DAT~ - PASS TO PASS(~EASURED DEPT~) ~ASELINE CURVE FOR SHIFTS LDW~ CU~V~ CODE~ P~SS ---------~QUIVAL~MT U~SNIFTED DEPTH---------- mASELIME D~PTH ~E~A~K$: THIS FILE CONTAINS PASS ~! OF THE CNTD. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. Sbls FORMAT DATA TaBT.E TYFF : CONS C~~ A~C~ ALaSKa, ~NC. ComDanV Wame F~ PRUDHO~ BAY Field Name w~, DS 6 - 92A Well Name IS vane verification cbltln'~ber~er Alaska Computing Center 26-0CT-1994 20:40 T!~! N ! VA b b DEF! FL 5S~' ~$[~ & 985' S~CT 2 COb~ ~ORTH $5OPE STAT ADASKA :~ 0. L"F RK~ ADD FT 74, EKB FT 7~, EDP ~T 73 TgD WT T~L FT I05~7. BLI ~T i05~3, TLI FT 9480. DFT PU~P-IN SEAWATER TLA~ 0~:45 2~-~AY-94 ~P! Serial Number Field 5ocatton Section Township Range County State or Province ~ation Witness Name Service Order Number Permanent datu~ Elevation of Permanent Datum Lo~ ~easured From Above Permanent Datu~ ~levation of Kelly Bush~n~ Elevation of Derricg Floor Total DePth- Driller Total DePth Logger Bottom Log I;terVal Top boo Interval Brllltng FlUid Type Time,So~aer at Sottom TaBI~E TYP~ : CU~V DEr! D~P? Pebth NPMI Compensated ~eutron Po~ositV, SS !~atrlX, cali& dead time corr. NRgT ~ieutron ~ation ~on-Dead time Corrected (M/F) C~A~ ~eutroD ~atio, Dead Time Corrected (~N/RF) NCN~ Paw ~ear Detector Count Pate, Dead Time Corrected FCN~ Raw War Detector Coumt rate, Dead Time Corrected C~TC Corrected Par Detector Count Rate CWTC Corrected Meat Detector Count ~ate G~C~ Gamma Ray ~n Casing TFNS Surface Tension CCi, CCI, Amplituoe G~ ~PI-Corrected ~a~ma ~a¥ IS Tape VerY, f!cation 26-0CT-!994 20:40 2 66 0 4 66 5 66 6 73 7 65 66 13 66 0 1~ 65 I~ 66 68 I~ 66 0 66 DWpT FT NPH? CNTD PU-S C~A~ C~D FCN~ C~T{) CPS CFT~ C~TD CPS C~TC C5TD CPS G~CN C!~TD GAPI T~ CNTD ~B CCL CN~O V G~ ON GAPI TYPE -CHAN ** , · SE~VTCK ~pI ~pT AP1 AP1 FILE NUmB NU~'B SIZE REPR PROCESS ORDE~ , bOG TYPE CLASS ~OD NUmB SAMP ELEM CODE (HEX) mm~m~mmmmmmm.mmmmmmmmm~--.mmm.mmmmmmmm~#~8~..m..~m..m----'~'m'm'--m'~'m~ 488216 O0 000 O0 0 1 1 1 4 6B 0000000000 48~2~6 O0 000 OO 0 I ~ ! 4 68 0000000000 4~216 O0 000 O0 0 I ~ I 4 68 0000000000 ~:892~6 O0 000 O0 0 1 1 ! 4 68 0000000000 48~216 O0 000 O0 0 1 ~ 1. 4 68 0000000000 48~216 O0 000 O0 0 1 I I 4 68 0000000000 t8~2!6 O0 000 O0 0 1 1 1 4 68 0000000000 488216 O0 OOO O0 0 1 ~ ~ 4 68 0000000000 48~216 O0 000 O0 0 1 1 ! 4 68 0000000000 48821.6 O0 000 O0 0 1 1 ~ 4 68 0000000000 48~2~6 O0 000 O0 0 1 ~ i 4 68 0000000000 ~82~b O0 000 On 0 1 ! 1 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmmm#mmmmmmmmmmmmmm#m~mmmmm-mmmmmm-m-m-m--m-mmmmmmmm--m~----m-----m~ DFP~ I06~8.0no MPHI.CNTD -999.250 NR~T.CNTD -999.~50 CRAT.CNTD N~,':CbT[? -9~9.~50 FCNT'CNTD -~99.~50 CFTC.CNT9 -999.250 CNTC.CNTD G~CH.CNTD -999.2K9 TE~S.C~T~ -99~.~50 CCL.CNTQ -999.~50 GR.OH DFPT. ~2~0.500 NPHI.C~'TD -999.~50 NRfiT.CNTD -999.950 CRAT.CNTD NCN~.C~TD -909.25u wCNT.CNTP -999.250 CFTC.CNTD -999.~50 CNTC.CNTD G~CN.CN~D -999.25U TENS.CNTD -999.~50 CCL.CWTD -999.~50 G~.OH -999.250 -999.250 -9999.000 -999.250 -999,250 ~5.941 IS ~a~e ver]ficatf, on Ll~tina c~lumber~er Alaska Co~put,ino Center 26-OCT-J, 994 20:~0 PA ..E; END OW DATA FTLF ~A~E : EDIT .001 SFRVlCE : PLIC VERSION : O01C0! MaX RFC SIZE : !024 FTbF TYPE : LO LaST FILE : **** FILE HEADER **** FILE NAME : EDIT ,002 VERSION : OO~CO1 DaTF ! 94/06/~ M~X FMC SIZE : 10~4 F!LF TYPE : LO haST FILE FILM ~U}~BMR: 2 EDITED CURVES nenth shifted and cl~.,pped curves for each pass ~n separate files. PASS MU~B~R: 2 DFPTH I ~]CgE~EMT: 0.5000 FILM SU~,! ~. RY ~DWG T~OL CODE START DEPT~ STOP DFPTH ... ........ ;;--;7;---- cR~H 51 1 .0 C[-]TD 1052~, 0 10100,0 CURVE SHIFT DATA - PASS TO PASS(~-!EASU~ED DEPT~) ~ASEL!ME CURVE FOR S~IFTS LD~G CU~VF CODE: GRCH mASE!,i~:E DFPTH 10509.5 .......... EOUIVALEMT UMSHIFTED DFPTH----- ..... ~RCN CDTD 1050~.5 ~050a. O ~C500.5 ~oagm.5 chl. umberc~er ~!as~a Computins center 26-0CT-!994 20:40 PAGE: 10492.5 10480,~ ~047~. .... I0480.0 ~0473o5 !0a73,5 ~047!,0 ]0463,0 !0~63,5 ~0457'5 ~ 0436 , 0 ~042~, 0 t0416,5 ~0407,5 ~0400,5 ~039~,5 10380,5 ~037~,5 ~.0364,5 ~0356,5 0355.0 10354.5 0347o0 ~0347.5 10330,5 ~030o.5 ~0300,5 ~0~96oK *0~9~,5 ~0~84,5 t0~85.0 ~0~70:6 10~69.0 ~0960,5 ~0~58,5 ~0246,~ ~0~45.5 10~3~.5 ~0~28.5 !022t,5 !021~,5 !0207,5 ~0~0~.5 10199,0 ~0199.0 10191,5 ~0177,0 ~0~63,5 ~.0493.0 ~0470,5 10459,0 ~0445,~ ~0429o0 10424,© ~0416,0 ~0~04.5 10400.0 ~0380.5 ~037~.o !0365,0 10330.0 ~030~,5 10~96.5 10~92,0 10269.5 ~0~58.5 10~40,5 ~0237.o 02325 .022g:0 ~_022~.~ 10216.5 ~0~13o0 ~0704.5 !0~.77.0 IS Tare Ver~,~ication cblumberoer AlasKa Comput~1n~ Center 26-0CT-1994 20:40 !0~28,5 10~,28,5 !.00.r~ lO0.O J. O0.O ~E~A~$: T}~IS PILE CONTA!NS ~AS8 #2 OF T~E CNTD. TME DEPTH' C~R~ECT!ONS S}{OWN AMOVg REFLECT PAS8 ~2 G~CM TO PASS G~CH .~ND PASS ~2 NPHI TO PASS ~ ~PHI. A~SL OT'HE~ CNTD C[;RVES WE~F~ CARRIED WIT~ THE NPHi 8 IFIS. LIS FORMAT DATA C~ A~CO ALASKA, INC. FM PRUDHOE BAY API~ 50-029-20~06-0~ T~W~? R~ STAT N~T? USA SON 4~B~16 P~AT MSL E~D FT O. L"F RKB APQ FT 74, EDF ~T 73. TDD WT 10508. Tn~ ~T 105~7. BL! FT 105~3, TLI rT 9a80. D~T PUMP-IN SEAWATER TLAn 08:45 22-~AY-94 Compan~ Name Field Name Well Name ~P! Serial Number Field Location Section Township ~ange County State or Province Nation witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log ~easured From Above Permanent Datum Elevation of Kel!¥ Busbino Elevatlo. of Derrick Floor Total Depth - Driller Total Depth - Logger 8ottom Log Interval Toy Loo Interval Dr lllnq Fluid Type Time Lo~er at Bottom I$ Tame Ver~t~.cation 5istino ChlUn~ber~er Alaska Computino Center 26. 0CT-1994 20:40 TaB~,E TYP~ : CUPV DEFY D~P? ~enth NPH! Comoensated..Neutron PorositY, S$ Matrix, call & dead time corr. NBA? ~e~tron ~atlon Non-Dead time Corrected C~A? Neutron ~atlo, Dead Tize Corrected (RN/RF) NCNT gaw ~ear Detector Count ~ate, ~ead T~me Corrected FCNT ~aw Far Detector Count rate, Dead Time Corrected C~TC Corrected Far Detector Count Rate CNTC Corrected Near Detector Count Rate GPC~ Gamma Ray ~n Casino TFN~ Surface Tension CCL CCL · YPE R~PR CODE ~6 mmmmmmmmmmmmmmmmmmmmm#mmmmmmmm .h.F g~V U~iI~ ~E~VTCr AP ._ P . [,E fJljM~ NUMB SIZE ~EPR P~OCE$S ID r]~P~;P ~ LOG TYPE CLASS tl~D NUmB SA~p EL~N CODE (HEX) DFpw FT 4882~6 O0 OOO 00 0 2 ~ ~ 4 §8 0000000000 NPH! C~T~ PU-S 48~210 nO 000 O0 O ~ I 1 4 68 0000000000 NPA~ c~D ~2!~, or) OeO nO n 2 1 1 4 6~ 0000000000 C~A? c~T~ ~8~21~ eo 9o0 oo o 7 I ! 4 68 0000000000 NCN* C~c*D CPS a8~2!6 OO 0o0 O0 0 ~ 1 1 4 6~ 0000000000 FCr~~ C~D C~S ~8~2~0 DO 000 O0 0 2 I I 4 6~ 0000000000 IS Tare ,Ver~,.ficat~,on ~,istine cblumberoer A,IasKa Comput~,.n~ Center 26-OCT-~994 20:40 PAGE: ID ORDE~ ~ LDO TYPE CLASS ~QD NUMB SA~P EbE~ CODE (HEX) C~TC 't~ D C . O0 000 00 0 ~ 1 ! 4 68 0000O00 CMTC CNTD CPS ~89216 O0 000 00 0 2 1 I 4 68 0000000000 G~CW CN~D G~PI 48~2!.6 O0 000 O0 0 2 1 I 4 6~ 0000000000 T~NS CNTD LB 488216 O0 000 00 9 ~ 1 1 4 68 0000000000 CCh CNTD V 488216 O0 000 00 O ~ i 1 4 68 0000000000 DEPT. 105~3.000 '~P~I;CNTD NCNT.CNTD ~611.603 PCNT.CNTD G~CM,C~':TD -999.~50 T~NS'C~TD 29.548 NRAT"CNTD 544..5~4 CFTC-CNTD 1530.000 CCL'CNTD D~PT, i0100.000 ~'~H I:. CNTD i9 450 NCN"~.CNTD 4!~6.272 FCNT'CNTD 1224~490 G~CN.CN~D 12.883 TEN$.C~TD 1510.000 NR,~T:, C, %D CFTC, CNTD CCb. CNTD 4.882 CRAT.CNTD 558.207 CMTC.CNTD 0.000 3.333 C~AT'CNTD 1185.310 C~TC,CNTD 0.000 4.. 989 27~9.423 ** E!~.~'t) {:)F DATA ** **** FILE TR~ILEP **** FILE MA~E : EDIT ,002 SFRVlCE : ~LIC VFR$iON : 00~C01 D~TK : 94/06/2! ~aX REC SIZ~ ! J, 02~ FILE TYPE : LO L~ST WILE : **** FILE HEADWR **** FILF ~A~E : EDIT .003 SKRVICE : FbIC VFRSIO!~ : nO!CO1 DAT? : o4. Iu6/21 ~X ~EC STZ~ : 1024 FIb~ TYPE bAST FILE FILM wijuBER~ 3 EDITED CUmV~S neot~ Sh!fte~ and clipped curves for each uass ~n separate flles. P~S8 ~U~BFR: 3 Ig ga~.e Ver~.~.ca~.on !..,i. stina chlumberger ~.lasKe Computln~ Center 26-0CT-1994 20:4.0 PAGEr LD~G TOOL Cf]DE CNTD CURVE SWIFT D~T~ START ~ 0~10. SToP DEPTH !0!00,0 lOlO0.O - PASS TO PASS(HEASURED DEPTH) PASELIME CleaVE FQ~ SHIFTS LDWG CUPVF COPE: GRCH ~ASELI~E DEPT~ C~CH CNTD ~0516,0 ~0515'5 .0513,0 1051]'n ~0500o~ 10500.5 0a'99,0 I049~,5.. I0491 0 10490,5 ~ !.0480 0 0480, . ~0476,5 !0476,5 ~0471,0 10471,0 046~.5 !0.469,0 ~0464 r) 10463,5 ~04631B 10463.5 ~Oa3~ 5 ~0437,5 ~043~:0 ..... ~0435o0 ~042~,0 10427.5 ~0420,o ~0420,0 ~04o4,o ~0404,5 ~0396,Q ~0394,5 )0)64,0 !0)64.0 t0330.0 10330.0 ~0315.~ ~0313.0 ~0303.5 ~030~.5 10300.5 O9P n !0297.5 .027o:5 10279.0 10245,5 1024J,5 10~41.5 ~093~,5 UNSHIF~ED DEPTH-----,'---- I$ ~aDe Yer~.f~.cat,lon l, istin, q cblu!~-~berger A!a~Ka Comput.~.nU Center 26-0CT-~.994 20:40 ..~ ~" , ill '~ 0201 . ~ 10190.5 101.90.0 ~0~,80,5 lO~8~.e ~0777.0 !0~77.0 ~0177,0 ! 0166.5 ~ 0~,.39,5 10139,5 ~E~A~KS: T~4IS FI[,E CONTAINS PASS ~ OF THE C~TD. THE DEPT~ CORRECTIONS SHOWN ABOVE R~FLECT P~S8 #3 GRC~ TO PASS · G~C~ AND PASS #3 ~PHI TO PASS #1 NP~I. aLL OTHER CNTD C!~RVES W~ZP~] CARRIED WITH THM NPMI SNI,TS.F $ bis FORMAT DATA PAGE: ~2 T~BT~E TYPM : CO~S WT ~T ~T CM F~ W~ API~ FL S~CT TO~ R.BNC COU. STAT PLAT APg EDF T~I TIAR A~CO ALASKA, !NC. P~UDHOE BAY DS 6 22A 50-02~-20~06-01 584' NSL & 985' WEL NORTH SLOPE USA MEUSSEW O, 74, !0~08. ~05~7. 10523. 9480° F!!~P-T~ SEAWATER OBi45 ~2-~AY-94 ompan~ Name ~teld Name WellName AP1 Serial Number Field Location Township Ranqe County State or Province Nation Witness Name Service Order Number Permanent datum Elevation o~ Permanent Datum Log ~easured From AbOVe Permanent Oatum Elevation of Kelly Bushing Klevatlon of Derric~ Floor Total Depth - Driller Total Deotb - Logger Bottom 5o~ Imterval Top Lo~ Interval Dr~,llim~ Fluid Type Time Lo~:er at Bottom IS Tare Ver~.fication I, Ist].no chlumberqer Alaska Co~Hutlno Center 26-0CT-!994 20:40 TYPE ! CU~V DFPT QeDth ~OrOSit¥, S& ~a%ri~ calf & dead time corr, ComDensate~ N~? ~!eutron ~atlon Non ea:d l~e Corrected C~A? Neutron ~atio, Dead Time Corrected (RN/RF) NCN? ~aw ~ear Detector Count ~ate, ~ead Time Corrected FCNT ~aw ~ar ~etector Count rate, Dead Ti~e Corrected CFTC Corrected Far Detector Count Rate CNTC Corrected gear Detector Count Pate GPCW ~amma Ray ~n Casin~ T~NS ~urfaCe TensloD CCL CCh amDlttude ** nATA FORe, AT $,. ECIFIC~TION RECORD ** ** SET TYPE 64~ ** TYPE REP~ CODE V~LUE ~ 66 2 66 0 3 73 44 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 1!. 66 23 12 68 13 66 0 I~ 65 FI 15 66 68 16 66 0 66 1 mmmimmmmmmmmmmmmmmmmmmm#mmmmmm ** MET TYPE - C~AW ** Ti) ORDER ~ LOG TYPE CLASS ~OD NUMB 8AMP ELEM CODE (HEX) ......... .................... ...... ....... ..... .... ........................ F 8 216 O0 000 O0 0 ~ 1 1 4 6~000 O_ 0 fi0000 NPH! CcT[~ PU-S a8~2~6 nO 000 Ou 0 ] 1 1 4 68 0000000000 NPA~ C!~!) 489216 00 0O0 00 0 3 1 1 4 68 0000000000 C~A· CN~ 48~2!6 nc On(; O0 0 3 1 I 4 68 0000000000 NCN~ ~N'D CPS 4~2!6 O0 ono O0 0 3 I i 4 68 00000~0000 FCNT C~,~T!j C~$ ~g2!6 O0 000 OO 0 3 1 1 4 68 0000000000 iS ~aDe Ver]f!cation bist~no chlumberger AlasK~a Computlnq Center 26-0CT-1994 20:40 i4 ID ORDER # LOG TYF~ CDASS ~OD ~U~8 SA~P ~G~M CODE (H~X) CFTC CNTD CPS 4.8~2~6 00 000 O0 O 3 I ! 4 68 0000000000 CMTC CNTD CPS 48~2!6 00 000 00 0 3 I I 4 68 0OO0000000 GDC~ CN~ G~P! 48R216 00 000 0O 0 3 1 I 4 68 0000000000 TFN8 CNTD L~ 4882~6 O0 000 00 0 3 I 1 4 68 0000000000 CCL CNTQ V 48~2J. 6 00 000 00 0 ~ ! i 4 6~ 0000000000 D~Pm, i05~3,000 D!PRI,CNTD 29,734 NCNT.CN'P[.) 2800.393 WCNY,CNTD 581,53~ G~CH,C~TD -999,250 TENS'CNTD 1500,000 ~R~T,CNTD CFTC, CNTD CCL,CNTD 0.000 5-0X2 ~978.431 ** E~I) OF ~A~A **** FILE TRAIbEP FILF ~A~E : EDTT ,003 SFRVICF : FLIC VERSIOM : O0~C01 DhTF : 94106t21 F!LF TYPE h~$~ ~IbE **** FILE HEADER **** V~R$ION : 00~C01 D~T~ : 94106/2! ~X REC STZ~ : ~OP4 FIb~ TYPE : LO D~ST FILE : FTLF HE ~I;~_R AV.F.. P AGED PI~RVFS Co~peDsat. e~ f]eutron.: AritDmetic average of edited passes for all curves, ~ulsed ~.:eutron: ~'~navera~ed edited Pass l Gam~a Ray and backround counts; arithmetic average of e~ite~ static oasellne passes for all other curves. DFPTH I ~,~C~]~,~ENT 0.50nO P~SMES T;.;CbUDE~D 1~ AVFR~GE IS Ta~e V~r!.~.1cat~o~ Listino chlumberqer Alaska Computino Center 26-0CT-~994 20:40 PAGE~ C !~ T D $ ~E~A~K~: T~I~ WiLE CONTAINS THF A~ITHM~TIC AVERAGE OF THE THREE CMTP PASSES. aLL DEPT~ CURRECTION$ WERE MADE BEFORE T~E AVERAGE ~ COMPUTED, T U iq T V A L LI D E F l . wT FT ~T CN AmlW $~CT STA? NAT? WIT~ P~A~ T~.~I T!,AP APC~ ALASKA, INC. PRUDHOE BAY DS 6 - 22a 50-02~-20806-01 5~4' NMb & 985' WEL 2 NORTH SLOPE ALASKA d. ~EU$SE~ 488216 74° io 08. ~05~7. 9480. PU~P-IN SEAWATER 08~45 2~-~AY-94 Compan~ Name Field~ame Well Name ~PI Serial Number Wield Location Section Towns~iD ~an~e County State or Province Nation witness ~ame Service Order Number Permanent datum . Elevation of Permanent Datum Log ~easured From ~bove Permanent Oatum Elevation of Kelly BUShln~ ~levat~on of Derric~ Floor Total DeDtb - Driller Total DePth - Logger Bottom boq Interval Top Lo~ Interval Drtllin~ Flutd Type Time bo~ner at Bottom TaBI,E TYPF : CU~V D~FT mmmm~m~~m~m~m~mmmm~m~m~m~m~~m~m~m~mmmmm~mm~ DWPT NPHT NRAT NCNw FCN~ CFTC C~TC Peoth Compensated Neutron Porosity, SS ~atrix, call & dead time corr, Neutron Pation ~on-k)ead time corrected weutron Ratio, Dead Time Corrected paw Near Detector COUDt ~ate, Dead Tfme Corrected ~aw War Detector Count rate, Dead ~ime Corrected Correctem war Detector Ceunt Rate Corrected ~iear Petector Count ~ate cblt~mberger AlasKa Compt~tinO Center 26 .... CT-~ 994 20:40 PAGE: I¸6 DATA EO}~MAT MP~CIFIC~TIO~ RECO~D ** ** SET TYPE - 64ED ~YPE CODE UE 1 66 0 2 66 0 3 73 4 66 5 66 6 73 7 65 I~ 66 23 19 68 13 66 0 1~ 65 15 66 68 0 66 mmm#mmmmmmmmmm#mmm.mmm,mmmmmm--! ** SET TYPE - CNA~ ** ---------------;---~-~T--------------;;------------------------------------------------N · ~PT FILE U~B ~U~B SIZE REPR PROCESS T.r) ~RDE~ ~ LOG TYPE CLASS MOD NUMB KA!~P ELMM CODE (HEX) DFPw PT ~88216 O0 000 O0 0 4 1 I 4 68 NPH? CMAV P!)-$ 48~2~6 O0 000 O0 0 4 1 ! 4 68 NPAT CN~V 48~2!6 O0 000 O0 ~ 4 I 1 4 6~ CPA~ CN~V 48~2!6 O0 000 O0 0 4 1 1 4 68 NCN~ CN~v CPS 48P216 00 000 O0 ~ 4 1 1 4 68 FCW? CN~v CPS a8~2~6 nO 0PO 00 0 a ! 1 4 6~ CFTC CNSV CPS 48~216 O0 000 o0 0 ~ ~ i 4 68 CNTC CN~V CD$ 48~216 O0 000 OO 0 4 I 1 4 68 G~C~ C~45V GAPI 48~216 O0 000 O0 O 4 I I 4 68 TFNM CNAV h~ ~892~6 nO 000 O0 0 4 ! ! 4 68 CCL CNAV V 48P?!6 O0 000 nO 0 4 ! 1 4 68 O00OOOO000 0000000000 O0000OO000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 mmmmmmmmmmmmmmmmmmmm~mmmmmmmmm~mmmmmmmmmmmmm-mmmmmmmmmmmmmmmmmmmmmm#mmmmmmmmmmmmmmmmmmm IS ~a~e Verl. f!cstio~ chlu~berger AlasKa Comput~no Center 26-0CT-~994 20:40 PAGE% DFPT GPC..CNAV !0573.000 ~781.259 6!9.97~ ~WI.CNAV 27.998 MRA~,CNAV ~C~T,CWAV 613.958 CFTC,CMAV · E~!$.C~AV 1504.850 CCb. C~AV 4.636 CRAT.CNAV 619.974 CMTC.CNAV 0.000 4.794 ~960.171 **** FILB TRAILER **** FILM ZA*~g : EDIT .004 $~RVIC~ : FLIC ¥~RSIO~ : oO~CO1 DATF ~ 94/06/2! FILM TYP£ : LO LaST FI!~E ~ **** FILE ~EADMg **** FILM NA~E : EDIT SERVICE ~ WLIC V~RSION ~ oO~COI DATW ~ 94/0~/~1 MSX ~C SIZE : ~0~4 FIL~ TYPE ~ LO RAM CURVES ~urves a~d loq header ~ata ~or each pass i~ separate PASS NU~ER: 1 D~PTH INCrEasEd!T: 0.5000 VEMDOR TOOL CODE START DEPT~ S~OR DEPTH L~G HFA~EP DA~A ~AmE ~OVTi~A~ VERSION: TD DPlLLER (FT): · OP LO~ Ti:~TE~VAI., (FT): ~UTTO~ LnG IWTE~VAL filesl raw backarou.d pass in last fi 22-MAY-94 B45 22-~AY-94 1.0508.0 10527.0 9480.0 10523.0 ~800,0 IS Ta~e V~r~.f!cation Ll, stina ChlUmberg~r AlasKa ComputinO Center 26-0CT-.~994 20:40 PAGE: I8 ~T COLLA~ L CAL UB C~!TD AUX~bLIARY ~EASUREME~T$ ATC CB 433 C~TD COMPENSATED ~EUTRON CNC DA 146 $ DRTLLERS CASID~G DEPTH LO~G~RS CASING D~PTH ~O~EHO!~E cONDITIONS FLUID TYPE: FLUID DENSITY (LB/G) SURFACE T~PE~ATURE (DEGF~: B~TTO, ROLE T~IDE~ATU~E FLUID SALINITY (PPS~) FblJIO LE EL (FT): FLUID RAT~ IT ~ELLHEAD WATER CUTS (PCT): G~$/O!L R~TIO: ~ Et,,~T ~ 0~-~ TOOL TOOt, ~iPg (EPITHEP~!Ab OR THERMAL): ~aT~IX: ~AT~IX DENSITY: HOL~ CORRECTION (IN] 9~97.0 PUMP-IN SEAWATER NEITHER SANDSTONE ~.65 BL!JMbINE CO!IHT RATE NORMALIZATION IN OIL ZONE TOP NOrmALIZING WINDOW BASE NORMALIZING W~NDON P, LUELIME COUNT RAT~ SCAL~$ SET BY FIELD ENGINEER FA~ CO!,!~T ~ATE LOW SCALE (CPS): WA~ CO!~N~ RA?E HIG~ ,~CAbE NEaR COU~T ~ATF I,OW $CAbF (CPS): NEaR COUNT RaTE HIGH SCALE (CPS): TOO[, 5TA~DOFF RF~RKS: flE-!~ WA 3-~AY-1993. PIlMDED-TN 260 BLS SFAWATER BEFORE bOGGING AT 4-5 BPS. P!~ogn AT 1 BPN WHILE bOGGING. $ LT8 F~RUAT ~ATA IS ~a~e Ver~,ffcati,,on ,Chlumberger AlasKa Computf, n~ Center 26-OCT-~.gg4 ~0 2.:40 T t..~ ,~<~ ! v A L U D E F ! F~ PROD!'fOE BAY W~ DS 6 - 22A APlN 50-029-20g06-0! F~, 5~g' ~SL & 985' SFC? 2 CO[i~ NORTH SLOPE STA? A[,ASK~ N~T? USA WIT~,~ J ~EUSSEP SON 4~B~16 PDA,? MSL EnD FT APD FT 74, E~8 WT 7~, EDF ~T 73 ~"~ 105 TLI wT 9480. D~T PUN~-IN SEAWATER TLA~ 08:45 22-~AY-94 Company ~ame Field Name Well Name ~! Serial Number Field Location Section Township Range County State or Province Nation Witness Name Service Order NumDer Permanent datum Elevation of Permanent Datum Log ~easured From Above Permanent Datum ~levat~on of Kelly Bushing Elevat!on of De~ric~ Floor Total Depth - Dr~ller Total Depth ~ Logger Bottom Log Interval Top Log Interval Drilll6Q Fluid TYpe Time 5ogger at Bottom TA~.!.,E TYPW : CU~V DEF? DFP~ neoth Nm}~iT Compensated ~eutrom Porosity, SS ~atri~, call & dead time corr. R~}~P ~aw ~herma! ~eutron Patio ~R~ Thermal ~eu[ron Ratio Ca!ibrated RC~T ~Aw ~!EAR C~ COugars RCF~ PAw mAP CN~ COUNTS C~TC ~o~rected '~ear Detector Count ~ate CFT~ Corr-cted ~ar Detector Count Rate GP aPT-Corrected Gamma Pav T~S Surface CCL CCL Am~litude I$ Ta~e Verff~caticn Chlumberqer t~tasKa Co,put,ne Center 26-0CT-~,994 20:40 PAGE ri, 23 1 66 2 66 3 ~3 4 66 5 66 6 73 ? 65 8 9 !1 66 !4 65 1~ 66 16 66 1 O 66 ** SET TYPE - CMAM ** ORDER # bOG TYPE CLASS ~OD ~U~B Sh~P ~b. Eg CODE DFp? VT 4~21.6 O0 000 O0 0 5 1 1 4 68 0000000000 NPHT PSI pIJ 48n2!6 O0 000 O0 0 5 1 ! 4 68 0000000000 RTN~ PS~ 488216 O0 000 O0 0 5 1 1 4 68 0000000000 T~R~ DS~ 4~216 O0 000 O0 0 5 1 i 4 6~ 0000000000 RCNT PSJ CPS 488216 O0 000 O0 0 5 1 ! 4 68 O000000OO0 RCFT PS~ CPS 48~2!6 O0 0o0 O0 0 5 I 1 4 68 0000000000 CNTC PS1, CPS 48~216 O0 000 O0 0 5 1 I 4 68 0000000000 CFTC P$~ CPS 488216 O0 000 O0 o 5 1 1 4 68 0000000000 G~ PS~ G~PI 48~216 O0 OeO O0 0 5 1 1 4 68 0000000000 TF~S PSi b~ 48~2~6 00 000 O0 0 5 1 I 4 68 0000000000 CCh PS1 V 48~2!6 O0 000 O0 0 5 1 1 4 6~ 0000000000 mmmmmmmmmmmmmmmmmm mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm 2O ** DaTa ** DFpT. 10529.000 bIPFI.PSI RCNT.PS! ~927.573 PCFT.PSI G~.PS~. K3.0q4 ~EJ~'JS.PS1 DFPT. lOOqh.0nO ~PWI.PSI RC~.PS1 .4!17.87b RCFT.PS! GP.D~! !1.977 T~S.PS1 27 36! ~Tf!R.PSi 4.500 T~RA.PS! 650~57¢ CNTC.PSl 3084.638 CFTC.PS1 1105.000 CCh.PSi O.nO0 20 J4n ¢TNR.PS1 3.743 TMRa.PS1 !101~78 CNTC.P$1 4301.730 CFTC.PS1 1580.00~ CCh. PSi 0.000 4.719 653.697 114 720 IS Taue Verif.lcatlon Listino chlumberger Alaska Compqtino Center 26-0CT-1994 50:40 PAGE~ 21 **** FILE TR~ILE~ S~RVICE : ~LIC FTLW TYPE : bO LAST FILE FTL~ NA~E : ~D~T .006 SERVICE ~ FLIC VFRSION : oOICO1 D~TF : o4/06/21: ~X RFC S!ZF : !.0~4 F!LF TYPE : LO L.aS· FILE RaW CURVES Curves and lou header data for each pass in separate P~S~ ~U.B~R: 2 DFP~H I~CPEWE~T: 0.5000 # FILr SUu~Y VEMDOR TOOL CODE ST~R? DEPTH 10 3 . ' LOG H~ADE~ DATA r,~TE LOGCED: SOVTWA~E VFRSIO~ ~O DPILLW~ (PT): WD LOGCE~(FT): TOP LOG INTErVaL "OTTn~ LOG DEPTH COaUThOr. !IS~D (YES/FO): TOO~ SIPlMG (~OP TO VF~cD~ ~OCL C~DF TOOI~ TYPE ST0P DEPTH files; raw bacKcround pass in last ~2-gAY-94 ]B 2 ~.050~,0 !0527,n 1052],0 ~800.0 22-~AY-04 TOOL NUMBER IS Tape Ver.]f~catJ. on bist).no cblUmberQer A1asKa Compute. nE Center 26-0CT-~994 20:40 $ DRTLLER8 CASING D~PTH (FT)~ ~OREHOLE CONDITIONS MLU!D TYPE: F'bUTD D~NSlTY (LB/G)I BOTTO~ MOLE TMMDEPATU~E FLUID SALINITY FLUID LEVEL FLUID RATE AT ~MLL~EAD W~T~R CUTS (PCT): G~S/OIh ~iEUT~O~ TOOL ~TPI~: ~aTRIW DENSITY: C~bI..AP [,OCAT~P CAL UB CNC DA i46 9297.0 NEITMER SANDSTONE ~.65 BLU~L%N~ COUNT ~ATE i~OR~ALIZATION IN Oil, ZONE ~ASE NOR~.ALIZI~G ~INDOW ~,~,~,,I~E COU~T R~TE SCAb,S S~T BY FIELD ~NGI~E~R ~A~ CO,,NT PATE bO'~ SCAI. E (CPS), ~A~ CO"N~ ~TE HIGH SCALE (CPS): ~EAR COUMI RaT~ LOW SCALE (CPS): ~EAR CCUN~r RAT~ NIGH SCALE (CPS): TOOL 8TANDOFm RF~SRKS: T!E-I~ ~A 3-M~Y-1qg3. PUMPED-I{:~ 2~0 B!~S SEAWATER MEFURE hOGGiNG AT 4-5 $ FO~.AT DATA PAGE: ~2 T~B! E TYPW : CO~!S T!!~!i ! VAI, U DEF! CN A~CO ALASKA, INC. Company Name FN PRUDHOE BAY Field Name W~ DS 6 - ?2A Well Name IS Ta~e Verification List'.no cblumberger AlasKa Computin~ Center 26-OCT-1994 20:40 PAGE.'. 23 API5? 50-029-20~06-01 FL 584' ~6b & 985' SFCv 2 TO~ 10~ R~N~ 14E C~U~ NORTH SbOPE NAT? USA WIT~ ~ S~N 4~8~16 pOAT ~SL EPD B~F A~D ~T 74. EWB FT 74, EDF ~T 73 TDD W~ TDL FT !05~7. 8t~I ~T I0523. TLI FT 9~80. DWT PUhP-IN SEAWATER TLAP 08:45 2~-~AY-94 AP! Serial Number Field bocation Township Range Countv State or Province Nation Witness ~ame Service Order ~u~ber Permanent datum Elevation of Permanent Datum Log ~easUred From Above Permanent Datum Elevation of Kelly Elevation of Derric~ Floor Total Depth - Driller Total DePth - bogger Bottom Lo~ InterVal Top Log Interval ~ll~ng Fluid T~pe T~me bog~er at BottOm TYPE DEFI DWPT Depth NPHI Compensated ~eutron Porosity, SS Natri~. call & dead t~me corr. RT~!P ~aw T~ermal ~'eutron ~atio T~Ra Th,rmal ~eutron Patio Calibrated RCN· ~AW ~!EAR C~T COU~TS RCFT ~AW mAR CNT COUNTS C~TC Corr,cted ~ear D~tector Count Pate CFTC Corrected Far Detector Count Rate GP ~Pl-Corrected Gamma Pav T~ Surface Ten$!o. CCL CCL AmDl~,tude DATA FOR~AT SP~CIF?CATION ~ECOPD ** SE· TYPE - e4E~ ** T¥oE R~PP CODE VAI,UE 2 66 0 IS Tame Yeritlcatlon Listlnc cblumberqer AlasKa ComPL!tln~ Center 26-0CT'1994 20:40 ¸24 3 73 44 5 66 7 65 8 6S 0,5 9 65 FT 11 66 23 I~ 6B 13 66 0 14 65 F~ 15 66 6~ 16 66 ~ ** SET TYP N~NF $~RV UNI~ gED D~pT Fm NPHI P~2 PU 4892 RTN~ P82 4882 TNRa P$2 4882 RCFT PS? CPS 4882 C~TC PS2 CPS 4882 CFTC PS~ CPS %8~2 G~ DS? GaPI 4882 COb PS~ V 48~2 C~AN ** LOG TYP~ CLASS ~OD NUMB SAMP ELaM CODE (HEX) ~.6 O0 000 00 0 6 1 I 4 68 0000000000 ~6 O0 000 00 0 6 I I 4 68 0000000000 ~6 O0 000 O0 0 6 I 1 4 68 0000000000 1.6 O0 000 O0 0 6 1 1 4 68 0000000000 ~.6 O0 000 O0 0 6 I 1 4 68 0000000000 ~6 O0 000 O0 0 6 1 I 4 68 0000000000 ~6 O0 000 O0 0 6 1 I 4 68 0000000000 16 O0 000 O0 0 6 1 1 4 68 0000000000 lb O0 000 O0 O 6 1 1 4 68 0000000000 ~6 O0 000 OO 0 6 I 1 4 68 0000000000 !6 O0 000 O0 0 6 1 1 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm, mmmmmmmmmmmm DFPT. 10531.500 RCN~.DS? 96a2.948 GP.PS~ 48.8a. 4 DFPm. 10095.500 ReN~.PS? 4-1o4,208 Gu.~$? 13.477 NPHI,PS2 3!,65.4 RTNR,PS2 5.000 TMRA.PS2 RCFT.PS2 528.590 CNTC'PS2 2784,74~ CrTC.P$~ T[j~$.P$2 1~20.000 CCL.PS2 0.000 NP~I.P$2 18.q07 RTNR,PS2 3.493 T~RA.PS9 ~CFT.P$2 1901.201 CNTC.PS2 4327.374 CFTC,PS2 TE'~S,PS2 1505.000 CCh. PS2 0.000 5.243 531,129 3,592 1221.198 END OF DATA IS TaDe Ver~f..~.Cation Listino chlumberQer Alask~a ComputJ. no CeDter 26-0CT-!994 20:40 PAGE: 25 FIBF NA~E : EDIT ,006 SERVICE : ~LIC VERSIOn! : O0~,CO! DATE ~ q4/06/?1 ~X R~C SIZE L~$T ~ILE F~L~ NA~E : EDIT ,007 S~RV~CE : wLIC VERSIO~ : O0~CO~ D~TF ~ ~4/06t21 ~AX REC SIZE : tO~4 LAST FILE : FILE ~U~BER 7 RaW CURVES Curves a~d 1oo header data for each pass in seDarate DEPTH I ~JC~E~E~T: O.qO00 F~LE VENDOR TOOL CODE START DEPTH STOP DEPT~ .......... .. ;-;[;-.--.- .... MT 0 0 0084.5 LOG HFADE~ DAT~ bOGGED: SOFTWARE VERSIONS: w!uE LOGGE~ O~ BOTTOM: TD DPlLLEK (FT): · D LOGGE~(WT): PE)T~O~'; L~G INTERVAL fFT)! T,OCGTN~ SPEED DE~TU CO~TROI, ~5~0 (YES/NO): files.,' raw baeKoround pass in last f~ ]8,2 845 10508.0 10527.0 9480,0 i0523,0 180o.0 NO 22-~AY-94 TnOb S'I'"RI~'G (TOP TO VF{-~nOP TOOL ChOw TOOl, TYPE TOOL MUMBE~ CNTD CobI,AR [,OCATO~ CAI, U C??TD AUXTL~.~IARY ~."EhSURE~NTS ATC CB 433 C~,,TTM CO~PEr, tSATFD NEUTRON CNC DA 146 S IS ~a~e Yer~ficatlon Listlno CblU~her~er'AlasKa Computin~ Center 26-~CT-!994 20:40 DRILLERS C~$I~G LO~GFRS CASi~,!G D~PTH FLUID TYPF: F!,UID DENSITY SURFACE T~iPER~TURE (DEGF): ~L}.{ID I, EVEI, ~T~ CUTS (PCT): TOOl,,, TYPE (EP!T~ER~L OR THERmaL): ~ATPlX DENS!TY~ HOL~ COrReCTION B!,U~LTN~ CO!.,~NT RATE NOR~ALIZATtON IN OIL ZONE Wf~P NOPHaLIZ!h~ WINDO~ (PT): BASE NOR~,I%ING W!NOO~ ~AR COUN~ DAT~ 50~ SCALE (CPS): ~aR COUNT R~T~ HICH 9297,0 PU~P-IN SEAWATER NEITHER _ SANDSTONE ~.65 TOOL 8TA~!DOFF (IN): R~M~RK$: TIE-I~ WA 3-~A¥-199~. PI~DEO-!N 260 BLS SEAWATER BEFORE 50GGING AT 4-5 BPM. P!!~PED AT 1 BP~ WHILE BOG~ING. $ LTS FORMAT nATA PAGE: 26 TABI, E TYP~ : CO~!S CN A~Cn ~LaSKA, INC. CompaD¥ Name Fr PPUDBO~ BAY Field Name W~ DS 6 - 22~ Well Name AOI~, 50-02q-~0806-~1 ~PI Serial Number FL 584' NSL & q85' WKD Field [,ocation SFC· 2 Section TO~ 106 TowBsh~.p R~C i~E Ranoe CnO~, ~,:RRTH SLOPE County ,IS Tane Yerif!cation icblumher~er ;~las~:a Co~?ut~nc Center 26-0CT-!~994 20:~0 PAGE: ~7 WIT~,? d E~I) FT APb FT 74, E.~' FT TDD VT ~,0 TDL ~T BLI WT TLI FT 9480. DWT PU~-IN TLA~ 08:45 29-~AY-94 State or Province Nation Witness game Service Order Number Permanent datum Elevation o~ Permanent Datum Loq ~easured Fro~ Above Per~anent ~atum Elevation of Kelly Bushin~ Elevation of Derric~ Floor Total DeDth - Driller Total, Depth - Logger ~ottom Log InterVal Top. Log Interval Dril!ln~ Fluid TyPe ,Time Lodger at Bottom · D P n th uP~? Compensated ~!eutron Porosity, SS Matrix, eal~ & dead time eorr, RTN~ ~aw Thermal Neutron.~atlo~ T~R.~ Thermal ~eutron Ratio Ca!.tbrated RCNT ~AW NEAR CNT COUNTS RCF~ ~AW ~AR CNT COUNTS C~IC Correcte~ ~ear Detector Count 9ate CFTC Corrected Far Detector Count Gw ~P?-Corrected Gsmma ~a¥ TFNS Surface Tension CCL CCL DATA FmR~*AT SPECIFYCATION RErOPD ** ** SET TYPE *YD5 RKP~ CODE VALUE 2 66 0 3 73 44 4 60 5 66 6 ? 65 iS Ta~e Yer.tf~,catIon List:ina cblumberger A!as~a Computino Ce~ter 26-OCT-!. 994 20:40 o ~5 FT 1! 66 23 !~ 68 1~ 66 0 14 65 15 66 68 i, 6 66 0 66 ** SgT D PT Fm, 488 NPH? ~S3 PU ~B82 RT~ ~$3 4892 TMR~ PS3 4882 RCFT P$3 C~$ 4892 CNTC P$3 CPS 48~2 CFTC P$3 CPS 4882 GR PS3 GAP! a882 T~NS PS3 58 4882 CCL PSR V IC aPI API APl ~IbE NUMB ~.!UMB SIZE EPR P~rlCESS ~ ~ bog TYPE CbASS ~OP NUmB SA~P MbEM .CO~E (HEX) 16 O0 000 O0 n 7 1 ! 4 68 0000000000 16 00 000 00 0 7 1 1 4 68 0000000000 ~6 00 000 0O 0 7 1 I 4 68 0000000000 !6 O0 000 00 0 7 ! I 4 68 0000000000 !6 00 000 00 0 7 1 1 4 68 0000000000 ~6 00 000 00 0 7 1 ! 4 68 0000000000 16 O0 000 00 0 7 ! i 4 68 0000000000 ~.6 00 000 00 0 7 1 1 4 68 0000000000 !6 00 OO0 O0 0 7 ! i 4 68 0000000000 16 O0 000 O0 0 7 1 I 4 68 0000000000 O0 000 O0 O 7 I 1 4 68 0000000000 mmmmmmm~mmmmmm~mmmmmmmmmmmmmmmmmm~mmmm~m DwP~. 1. o5 . O0 ..... '29. 0 t,~PHI.PS3 RCNw. PS3 2858.561 RCFT.PS3 G,, PS3 ~1 84.~ ~ENS.~S3 DFpT. 10084.5o0 NPuI.P$3 RCN~.P$! ~404.u~.e PCFT.PS3 GP.~S3 177.~5 TEwS.PS3 27.3b! RTNR-PS3 4.500 TNRA.PB3 635.236 CNTC.PS3 301~.g23 CFTC.P$~ 1260.000 CCL.PS3 0.000 39.787 ~TNR.PS3 6.250 TNRA.PB3 384.3B4 CNTC.P$3 2610.98~ CFTC.PS3 14bo.no0 CCL.P$3 0.000 4.719 63B,287 6 170 44B~141 ** E~'D OW DATA ** ~.~lg()i~b : ii(]~ : ~i~~,~ Diq~ ; ~IA~3~ 6~ :3D~d O~:Og Pb6f-£OO-9g