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181-086
ti OF T� • 41- �,� THE STATE• ���\I//�,sAlaska Oil and Gas ���►;,� OfA LAsKA Conservation Commission x_=_ _= 333 West Seventh Avenue F GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS' I.' Fax: 907.276.7542 www.aogcc.alaska.gov March 15, 2018 Mr. Glen Pomeroy Pipeline Compliance and Conformance Mgr BP Exploration(Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 SCAISNED Re: No-Flow Verification Prudhoe Bay Unit M-16 PTD 1810860 Dear Mr. Pomeroy: On March 13, 2018 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit M-16, operated by BP Exploration (Alaska) Inc. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004—was rigged up on Prudhoe Bay Unit M-16 prior to the test and that the active offset injection wells remained in service. The well performance was monitored for three hours. Gas flow rates at the end of three separate flow checks preceded by 1- hour pressure build up periods ranged from 1700 to 2000 standard cubic feet per hour, declining to less than the allowed gas flow rate (900 standard cubic feet per hour)within 18 minutes. There was no liquid flow to surface during the test. Prudhoe Bay Unit M-16 may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit M-16 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, Re James B. Regg /I Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors AKDCWellIntegrityCoordinator@bp.com AKD&CDHDWe1IIntegri@bp.com Ryan Daniel, BPXA • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg `4t; SI 1611g DATE: March 13, 2018 P. I. Supervisor FROM: Brian Bixby SUBJECT: No Flow Test Petroleum Inspector PBU M-16 BPXA scow PTD 1810860 f 3/13/2018: I arrived location on got up with Ryan Holt(BP rep) and we discussed the No-Flow procedure they were going to use on this well. The procedure involved using a flow meter. We also discussed the well history and the bleed down prior to my arrival. The well was shut-in on 12/26/18 for slickline to pull the SSSV. It was placed on production 3/11/2018 and shut-in " 12/13/18 for the No-Flow test. The outer annulus has cement to surface. Not great cement as there is gas migrating up thru it. The DHD crew started bleeding the well at 1:00am 3/13/18: initial pressures were 480psi -' (tubing -T), 1710psi (inner annulus- IA), and 320psi (outer annulus - OA). They bled the flowline, tubing and IA to 0 psi (completed 8:20am). The well was opened to the bleed tank ',- when when I arrive at 8:45am. The flow meter was rigged up to the bleed tank when I arrived and the well was shut in to start the test. The following table shows test details: Time Pressures' Flow Rate2 Remarks (psi) Gas-scf/hr Liquid -gal/hr 0900 0/3/485 Shut in for 1 hour build up 0930 29/3/485 - Check pressures 1000 30/0/485 - 2000+ • 0 12 min bleed to 0 psi; 18 min to < 900 scf/hr; 25 min to 0 scf/hr 1025 0/0/485 - Shut in for 1 hour build up 1055 1/0/485 - Check pressures 1125 1/0/485 1800 0 20 sec bleed to 0 psi; 80 sec to < 900 • scf/hr; 2 min 40sec to 0 scf/hr 1155 1/0/485 Check pressures 1225 1/0/485 - 1700 0 15 sec bleed to 0 psi; 56 sec to < 900 - scf/hr; 2 min 20 sec to 0 scf/hr ' Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr PBU M-16 appears to meet the requirements of a passing no-flow test. Attachments: Photos (2) - PBU M-16 Well History(support documentation) - Calibration Reports 2018-0313 No-Flow PBU M-16_bb.docx Page 1 of 2 • • III.. P, 5 go -' ' - ''i , Z . 6, - ... ..,:m ti.,,ttlii, cn i .'.1:' '; 1 0 .,.,,, i t::1.,!:. .--; _ , t ': ; 1 C kUOb y x ey„ I N tin 40S. = 4N0.rI: v 5" F hir ry ..„ 1 'Ili vp.40. 010....a:— ' aO L (1) 0 Op_ `~000 ma L : Cill 0"CO U dpin cm U 0 ' 0 u) CO S t' m Illik L Q CD s O C---.1 • ZLLQ. M i • Last Update: 2/27/18 After updates have been made, please upload a copy to If you do not find the offset injectors for a No Flow Test please conta Esther.Fueg@bp.com Bernhard.Stechauner@bp.com Offset Injectors to NFT Offset Injectors Producer Injector 1 Injector 2 Injector 3 Injector 4 Injector 5 IlL:IML 12-27A 12-23 12-06A 12-25 12-02 17-06 17-13A 12-07A 12-25 12-30 17-13A 12-31 12-08 13-15A 13-06A 12-33 12-34 12-14 12-30 17-10A 12-31 12-18 13-21 12-27A 12-21 12-23 12-26 12-27A 12-02 12-25 17-13A 12-32 12-02 03-16A 13-03 13-21 12-21 12-20A 12-19 13-22 13-08 13-36 12-34 13-09 13-15A M-16 S-14A R-25A M-14 M-20A M-15 R-11A M-18B M-13A M-20A M-17 U-04A M-25 N-08A M-29A M-31 M-18B M-20A M-13A R-11A These wells are currently not in installed injection capacity, ie. don't • • • S-14 SI Not op suspended while drilling 2005 laal Su 4000 -2[0 3800• 150 3630. 1130 3400• 170 3200 100 3000• 150 2000 140 T10 Plot 2800• 130 + Tbg 2 430- 420 ; IA 2200- 110; + 0A 2000, 1W 00A + 000A 1.801 % e -On 1600• ■ Bleed ▪ Operable 1400 70 3 Not open 1200 • Under Eval Temperature 1.000 50 800- 40 600 30 400 20 200- -10 4 - 33l131' 0,77..17 0514117 M.141' 0'.11^.? 0071517 0315:17 101617 11^6'17 72"" a X7:10 021121 R-25 WAG injector woo R.26 4000 3800 230 220 3670 • ■ 210 3670 200 3 MO 193 3030 180 110 2$0 4 160 TIO Plot 2830{ 150 _+..Tbg 24004 141 B IA 22301 - 1300 A OA • 20001 1201 00A 0004 1.000 110: -21 0n 4600 • IW w &ecd 90 4 Operable 1 410 80 1 Not Oper 12301 Under Eval 1000 Tamperers. 60 E230 !110glom L .'-" Aear' . ' ar .._._.ate 03,13/7 041317 051417 061417 071$77 0213,17 4«11517 1016'17 1116^7 12717117 01.17.18• 0311710 • • • • . M-14 Not op WAG Secured with WRP 01/19/15 Well M44 6000 t1 200 38001 190 3600 180 3410 170 . 3200 iW 3000 150 2100 140 TIO Plot 202) 630 t Tbg 2470 120 IF IA 2230 110v —A—OA O00 2000 I00 i 000A 1930 90 a —On I U10 co a Bleed Operable tan 10 — Not Oper 7 • Under Eval Temperature 1000 50 PO a( I 120 j# 10 430 . 20 2920 lat.dl". —_ _l.. > Ili 10 031317 041317 0''..1417 051417 07.17.17 0615.17 041517 101597 1111117 121717 0117,12 0211/10 M-20 WAG injector 7*6.1.-20 4000 243 3700 230 3600 • 220 34 212 200 3200 190 3000 120 2100 170 110 Plot 2670 164 150 -BI--Tbg 2430110 0t IA 2200 , r 1 OA 130 00A 2000 120 6 0000 1000 1101 —On 1040 100 03 Bleed • Operable 90 1.430 Not Oper BO 1200 • Undo,Eva! n Temperature 1000I 60 ..' IP r..".."r."1„.a.... jr.tillell(4' it 0 I lr� 20 203 .......,_______„.. ,4 11�'I5 4 a ..5= to T 03+13n7 OL13n7 rel<v 061417 o7.1v/7 0915n7 046517 tour, 111s97 trrn'otnins O.Y17.9s • • Pt 0 Certificate This is to certify that this instrument has been calibrated for the fluid conditions specified on the purchase order and embossed on the nameplate. Measuring devices that are traceable to the United States National Institute for Standards and Technology(NIST- formerly National Bureau of Standards) were used for this calibration. 0 1---ks(•-,J 11/17 Technician Date 711S -/ Instrument Serial Number ERDCO Engineering Corporation 721 CusterAV• Post Office Box 6318 Evanston,IL 60204-6318 USA • t,OF Tit • Iy/,mss THE STATE Alaska Oil and Gas .41 „, of T (� Conservation Commission ALAV 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF I, 9� Fax: 907.276.7542 www.aogcc.alaska.gov April 27,2017 Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration (Alaska)Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: No-Flow Verification PBU M-16 PTD 1810860 SCp0E3 11M I': (. 1 r' Dear Ms. Cocklan-Vendl: On April 21, 2017, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit M-16. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit M-16. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(1)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank for 5 minutes, the well continued to vent gas, and was shut in. The tubing pressure monitored at the production tree was at 5 psi after shutting in following the 5 minute flow period. A subsurface safety valve is required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. Sincerely, VIcArkezt_atme..y.... Michael Quick Sr. Petroleum Engineer ecc: J. Regg P. Brooks AOGCC Inspectors AKOPSFF Wel lOpsCompRepnbp.com AKDC Wel lInte gri tyCoordi natorAbp.com Ryan Daniel,BPXA STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMAPION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Susp Well 0 Other:Micro Cement OA 63 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 181-086 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20613-00-00 7. Property Designation(Lease Number): ADL 0028257 8. Well Name and Number: PRUDHOE BAY UNIT M-16 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11750 feet Plugs measured feet true vertical 9319 feet Junk measured feet A P R 1 9 2017 Effective Depth: measured 11508 feet Packer measured See Attachment feet n.�� (� true vertical 9133 feet Packer true vertical See Attachment feetlJ �! Casing: Length: Size: MD: TVD: Burst Collapse: Structural Conductor 80 20"x 30" 27-107 27-107 Surface 2705 13-3/8"72#L-80 27-2731 27-2669 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment 10954-10984 feet 10984-10994 feet 10994-11000 feet 11000-11008 feet 11016-11036 feet Perforation Depth: Measured depth: 11036-11076 feet 11076-11080 feet 11100-11180 feet 11341-11356 feet True vertical depth: 8699-8723 feet feet 8723-8731 feet 8731-8735 feet 8735-8742 feet 8748-8764 feet 8764-8795 feet 8795-8799 feet 8814-8877 feet 9002-9014 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED MAI6 2017, At Surface Treatment descriptions including volumes used and final pressure: 15 Bbls Fresh Water,1.5 Gallons Musol Solvent,21 Gallons LockCem,Atmospheric Pressure. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 404 647 1128 1772 638 Subsequent to operation: 343 950 1366 1786 502 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory ❑ Development ® Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I3 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-443 Contact Worthington,Aras J Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Interventions&Integrity Engineer Signature y,/�i ti��� Phone +1 907 564 4102 Date e Form 10-404 Revised 5/2015 frit* 1/TL 57/0/1-7' RBDMS L.-t- M'I l - 3 LU li Submit Original Only • • Packers and SSV's Attachment PRUDHOE BAY UNIT M-16 SW Name Type MD TVD Depscription M-16 PACKER 1499.15 1499.14 9-5/8" BOT External CSG PKR M-16 TBG PACKER 9926.38 7916.12 4-1/2" Baker S-3 Hydro Set Packer M-16 TBG PACKER 10061.79 8016.43 4-1/2" Baker SABL-3 Packer M-16 TBG PACKER 10143.46 8077.1 5-1/2"TIW HBBP Packer • S d Q p p p p O O p p - r8 CO co C0 C` d O COU LU N C N cr CO r- ti c0 U i CO 0 0 00000 V' CO co co co 0~O co N v- V d' N- m V' CO C0 f- CO CO CO N- N. 0) Cn LU O N- O V- (.0 co co O N 0) CO v- (n N CO N •- CC CA O) C)) N- pCO I— CA In CO) I� N C7) I- (nONCr) CT) LC) N N N (n N N N CD O �- 00 CIO C)) I- CO C CO CC) CO (n r- O N COE I� N- (r0 (.0 CO CA C`7 LO CO N CA C O (() I- L CO ti O r = G CV O •- O O O 4 CA Cf) r C) co Q N- N- Cn N O C 7 CO N N- CQ NNNc, CVO O M H/1 uj I— 0 0 0 0 O O C0 CO OL 02 U U L L Ch co cco co j r r M aCi) 0C �a6 *U NMPs Cn fV CV N r r Eo I I LO N- O Imo- O al O O N- in O (A O C p N- In N d r) `- O C) r- JCV r ()) - `- O WW whH CC CC CC CC Z Z Z Z W W W W W m m m ODI"' _,F- ZZZDDD (/) 7.1JI- I- f • • a a LO (U � O o D 0 .� � � o To O 03 N C L- w L O 0 a as c>3 C a) 25 L w a L U N i E 0 c C 0 U O co a J 0 o 2 U C < Cl) N ; N U UE U>;3 = = 0 .° 00U2N v) c _tea) @� CF- i U) V () co o O O > _ (n c 'y u) > > - 0yi .- U O- !Z O O C �©�` /U�1 Q u) CL D a a O O LC) a) V v O cp C po Ococ O U O II m Cl) "C p 0 U II C d i ° 0 C - II (II 11 N O Q (6 C c O C J U) cm Q o i .a) D (0 C) O < co Q C a a C N E II O • u) N U) 7 .0 N 0 O4 d II a) O ._• a O a) I N d ` C 0 .� �_ io a a Q J Q N Q 0- o` ani 4- C C' Q a) 'U O O i 0 i < O 8 O O Oc\i D w N Q� G 2 i E 6 Y 06 a) •5 in hi o •a, O CEJ C 0 V a Q F- 2 .0 C 0 a) cam) as a c6 0 0 0 0 0 - c� . 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L O) O "O [h c) U) > 0 U) d > C U) Y IIfa_ o 0 u U II U II o 0 II o 0 n o .� U II a1°i m 0 C cn O F II p _ a II II > a) I I o U) \ Q i al N L C C - Q O ` 0 0 Q II O O O II p U coo i II u O o II1- coco I- (n I- cu .g. (n I- ON 1- (n I- N .M- co H ,- C o (n LL O 0 N O CD O O `- N N CD COO CN N C) N -ft. If) (0 j m M N N Z:-.6 Co M N N .i....0, (N M M M 'TREE= CNV • WELLHEAD= rut EVOY M-1 -1 6 [41111SAFETY NOTE: WELL REQUIRES A SSS V. ACTUATOR___..___..- BAKER C ***CHROME TBG&SCAB LNR*** OKB.ELEV= 52.3' BF.QEV= 27.58' 20"CONDUCTOR ? .�• T��i 1141 KOP= 2000 9518"Ii,, H14$7 �. i 1499' H13-3/8"X 9-5/8"BKR ECP Max Angle= 47°@ 4500' C R �� r��• Datum MD= 11148' / i , f 1982' H4-1/2"HES X NIP,ID=3.813" Datum ND= 8800'SS �_ 9-518"CSG,47#,L-80 HYD 563,D=8.681" 1535' / 2613' —19-5/8"DV FKR 9-5/8"FOC 2700' 2 GAS LET MANDRELS ST WD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80,ID=12.347" —{ 2733' iI 4 3597 3310 46 NAAG DONE RK 16 08/15/15 3 6860 5603 44 MNG DOME RK 16 08/15/15 Minimum ID = 3.725" 10098" 2 8609 6934 36 MVK3 DONE RK 16 08/15/15 4-112" HES XN NIPPLE 1 9815 7835 43 NMG SO RK 24 08/15/15 9896' H4-1/2"HES X NIP,D=3.813" [ Z IkA 9926' H9-5/8"X 4-1/2"BKR S-3 FKR,D=3.87" I I 9960' H4-1/2"FES X NP D=3.813" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, --I 10023' I-- 10019' H4-1/2"X 5.1/2"XO,0=-3.958 0152 bpf,0=3.958" 10032' H9-5/8"X 4-1/2"UNIQUE OVERSHOT 4-1/2"TBG STUB(12/18/08) --I 10029' ' I 10054' I-1 4-1/2"FES X NP,113=3.813" Z ICI 10064' --I 9-5/8"x 4-1/2"BKR S-3 PKR,D=3.875" ' I 10098' 1H4-1/2"FES XN NP,D=3.725" 4-1/2"TBG,12.6#, 13CR-SO VAM TOP, H 10019' 10128' H 9-5/8"X 5-1/2"UNIQUE OVERSHOT .0152 bpf,ID=3.958' r _( 10128' H 5-1/2"OTIS X NP,D=4.562" I 5-1/2"TBG STUB(05/27/00) — 10121' ' 10143' —I9-518"X 5-1/2"HBBP TNV FKR D=4.75" 10148' H7-5/8"MLLOUT EXTENSION,D=6.2" 10153' IH 7-5/8"X 5-1/2"XO,ID=4.892" TOP OF 5"SCAB LNR —1 10194' ' 10163' H5-1/2"O11S X NP,ID=4.562" 5-1/2"TBG, 17#,13CR NSCC, H 10196'j .0232 bpf,D=4.892" 10176' 5-1/2"OTIS XN NP,0=4.455" 10164'ELM D(08/03/91) TOP OF 7"LNR H 10314' 10203' —19-5/8"X 7"TAN HYD Lkii HGR,ID=? 9-5/8"CSG,47#,L-80 NSCC,ID=8.681" —I 10783' 10207' H 7"X 5"XO,ID=4.276" PERFORATION SUMMARY REF LOG:SWS BRCS ON 09/29/81 ANGLE AT TOP PERF:38'@ 10954' I. Note:Refer to Production DB for historical pert data SPF INTERVAL OPWSQZ DATE E 11123' —{7"MARKER JOINT' SEE PAGE 2 FOR PERFORATION i DATA ♦�'�'EtE•'Iy lil 11508' -1MID(5-1/2'SCAB LW) 5"SCAB LNR 18#,NT13CR-80 H 11594' I –i',F�.1.1.1.1.'i FL4S,.0177 bpf,ID=4.276" ......1....**.' 7"LNR 26#,L-80 U4S,.0383 bpf,ID=6.276" —j 11750' #'1'.'.'.'.'/.../ DATE REV BY COfMNTS DATE REV BY COMIVE JTS FRLDHOE BAY UNIT 10/05/81 ORIGINAL COMPLETION 05/24/16RWNYJML✓SETK/PB VALVE(03/31/16) WELL: M-16 05/25/00 N915 RWO 06/14/16 CJWJM3 FULLED K/PB VALVE(06/09/16) PERMT No:'1810860 12/28/08 D16 RWO 07/06/16 CJN/JM)SET PB VALVE(06/10/16) API No: 50-029-20613-00 08/31/15 JTG/JND GLV C/O(08/15/15) 04/05/17 DG/JM3 RILED PB VALVE(04/03/17) SEC 1,T11N,R12E,1607'FNL&606'FEL 08/31/15 JTG/JND RILED XX PLUG(08/16/15) 02/03/16 GRCJTLH K/PB VLV STATUS FER STATE REQS BP Exploration(Alaska) I • M -16ID 1 .4 11 1 1* 41 14 ..NA A. .... .. alli AO II A I-, p.m ii.i.T• - FERFORATION SUMMARY REF LOG:SWS BHC ON 09/29/81 I ANGLE AT TOP PERE:38°©10954' Note.Refer to Production DB for historical perf data SPF INTERVAL OPN/SQZ DATE 6" 10954-10984 0 01/06/92 4" 10964-11008 S 01/04/92 4" 11000-11008 S 07127191 4' 11016-11036 S 07/27/91 6° 11036-11076 S 07/27/91 a a 4" 11076-11080 S 07/27/91 4" 11100-11180 S 07/27/91 6" 11341 -11356 0 05/23/98 1 I E . . P P•••••tt 11/111*H 11...11/1 1.111.111 111..11.0 4111114/1 111/.1114 ..__ MA TE REV BY 0(.444E1TS DATE REV BY COMIMBsITS FRUDHOE BAY UNIT 10/05/81 ORIGINAL COMPLETION 05/24/16RVIA#JMC SET K/PB VALVE(03/31/16) Mal. M-16 05125/00 N9E5 RWO 06/14/16 CJN/JNID FULLED K/FB VALVE(06/09/16) PERMIT No-'1810860 12/28/08 D16 RWO 07/06/16 C-.114,8vID SET PB VALVE(06/10/16) AR No 50-029-20613-00 08/31715 JTGIND GLV C/0(08/15/15) 04/05/17 DG/JM) Ft.LLEID PI3 VALVE(04/03/17) — SEC 1,T11N,R12E,1607°RI&606FEL 08/31/15 JTGLIIAD PILLED XX RUG(08/16/15) . 02/03/16 OW/TU-1K/PB VLV STATUS FR STATE BEGS BP Exploration(Alaska) ____ • • w\����7, ,9 THE STATE Alaska Oil and Gas — �� n vfA TAsKA Conservation Commission x_ 333 West Seventh Avenue " �- /* GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 + Main: 907.279.1433 Fax: 907.276.7542 ALAS www.aogcc.alaska.gov Aras Worthington Interventions and Integrity Engineer SCkt*Eti PN I Lint, BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU M-16 Permit to Drill Number: 181-086 Sundry Number: 316-443 Dear Mr. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /P)"- J7L— Cath . Foerster Chair b " DATED this�day of September, 2016. RBDMS \� SEP - 1 2016 STATE OF ALASKA • 4111KLASKA OIL AND GAS CONSERVATION COMMI.1 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Micro OA Cement Sqz 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 181-086 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 6. API Number 50-029-20613-00-00 99519-6612 Stratigraphic 0 Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 J PBU M-16 . R 1: 9'- . 9. Property Designation(Lease Number): 10. Field/Pools: A U G 2 2 015 d ADL 028260&028257 PRUDHOE BAY,PRUDHOE OIL . /gi/j d 11. PRESENT WELL CONDITION SUMMARY 011QPCC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): 11750 9319 11508 9133 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 27-107 27-107 Surface 2705 13-3/8" 27-2731 27-2669 4930 2670 Intermediate 10761 9-5/8" 25-10786 25-8565 6870 4760 Liner 1436 7" 10314-11750 8204-9319 7240 5410 Scab Liner 1400 5" 10194-11594 8115-9199 10140 10490 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10954-11356 . 8699-9014 4-1/2",12.6#x 5-1/2",17# 13Cr80 23-10197 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment See Attachment See Attachment / 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0' Service 0 14.Estimated Date for Commencing Operations: September 15,2016 15. Well Status after proposed work: Oil 0 4 WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington( bp.com Printed Name Worthington,in�Aras J Title Interventions&Integrity Engineer Signature , ' Phone +1 907 564 4102 Date j f1ilJ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: L-(L-( Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other N 41 Post Initial Injection MIT Req'd? Yes 0 No EtiVi Spacing Exception Required? Yes 0 No fflf Subsequent Form Required: /3 — Q C# APPROVED BYTHE Approved by:agi P (�y` COMMISSIONER COMMISSION Date: 6_f // ORIGINAL RBDMS LL'- r - 1 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • a) U co a — a) a) Y 7.. o a U Q' "CfM (73 CL m a Q- a) MQm cl) > U) U) m_ > Y Y m cu co ammo — CV CV N N d 4 4 4 LiS E C.) COCOI- Q > O) O) OO N H 1— co c0 C Co N COM L CI co N p - Y2ODcDOO V CC a ce CC CC > Y Y d -J O O O 000Q > aaa ammm a) cocococo Z r r r r U) • • • bp M-16 Micro OA Cement Squeeze & Conductor Cement Top Job Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Matt Bergene (907) 564-4849 Expected Start Date: September 15th 2016 History M-16 is an original vertical well that was drilled in 1981. The well had its first RWO in 1991, which replaced the tubing and ran the 5" scab liner to PBTD, in prep for fracing the well. The well was on production nearly 100% of the time until 1995, when problems with the tubing and casing hangers were noted, at that time the well head was treated with a Fermenite wrap. In April 1999, the OA began to track the IA, and gas was observed at surface. At that time the well will pass a MIT on the OA/IA, but at a slower pump rate it would take fluid. Additionally, the tubing appeared to be in good condition based on caliper data from the late 1990's. In 5/2000 the second RWO was performed, replacing the 5-1/2" tubing with 4-1/2" 13CR-80 VAM Top tubing. The well was again turned on to production until on 5/19/06 when the Pad Op again reported bubbling in the cellar. On 6/19/06 the well failed an MIT-OA with N2 with bubbling in the conductor x SC annulus. On 1/7/07, 10/16/08, and 12/06/08 CMIT-TxIA (two to 3000 psi and one to 3500 psi) were performed, all passed. on 12/28/08 a RWO was completed which replaced the tubing as well as cut/pull -2600' csg and cementing the OA to surface. The well was again returned to production, and it wasn't until 10/2011 that bubbling was again reported by the Pad Op. The well passed an MIT-OA on 4/10/12 with 500 psi of N2. It was returned to production and broke MOASP on the IA on 6/29/12. After passing aTIFL the next month, the well failed a warm MIT-OA with fluid to surface on 7/12/12, and the well was SI. The OA was subsequently squeezed on 12/23/15, after POPing UE in 10/2015 and confirming bubbling in the cellar. After the OA squeeze, the well passed an MIT-OA with no FTS on 1/13/16. The well was POPd UE on 5/8/16, after being online for 12 hrs, bubbling was noted in the conductor. The well was on production until 5/18/16, bubbling throughout that time. On 6/10/16, a plug was set and a MIT-T and CMIT-TxIA were performed, both passed, the K valve was then reset. Currently the well is considered flow restricted with a closed K valve and passing integrity tests but is deemed inoperable by BP. Objective This proposal is to perform a second micro-OA cement squeeze as well as clean out the conductor and top off the cement in the conductor with an aim to seal-off the gas bubbling from the cellar/conductor. • • • Procedural steps DHD/Special projects 1. Strap TOC in OA. 2. Circulate microfine cement into OA until clean cement returns are observed. 3. Rig up pneumatic pump and squeeze microfine cement into OA up to 2700 psi. 4. Hot water/surfactant wash the Conductor x Surface Casing Annulus to top of good cement. 5. Circulate cement into the conductor from the top of existing cement to surface until clean cement returns are observed. 6. Wait on cement to cure. DHD/WeII Integrity Superintendent 1. POP well Under-Evaluation and monitor conductor/cellar for any bubbling/gas. 2 WELLHEAD Mt EV OY • M1 6 S/ f NOTE WELL REQUIRES A SSS V. ACTUATOR= BAKER C CHROME TBG&SCAB LNR"'** OKB.ELEV= 52.3' 20"CONDUCTOR ? 114II BF.ELEV= 27.58' t1d KOP= 2000 95thH 1487' 1431 -1338'X9 518`B HP L Max Angle= 47'@ 4500' a mil Daum MD= 11148' -'4112111111111111s -412 N�XM�a$I3 Datum TVD= 8800'SS .� ` " Asir -4-1/2'PBVALVE(06/10/16) 9-5/8"CSG,47#,L-80 HYD 563,D=8.681" H 1535' x— 2613' -19-5/8"DV FKR 9-5/8"FOC H 2700' GAS LFT MADS ST MD TVD DEV TY FE VLV LATCH PORT DATE 13-318'CSG,72#,L-80,ID=12.347" --I 2733' , 4 3597 3310 46 MAG DONE FE 16 08/15/15 3 6860 5603 44 MAG DONE RK 16 08/15/15 Minimum ID - 8.72b" 1409$' 2 8609 6934 36 MAG DONE FE 16 08/15/15 1 9815 7835 43 MAG SO RK 24 08/15/15 4-1/2" HES XN NIPPLE - ' 9$96' -14-112^HES X NF;D=3.813" F 1 9926' -19-5/8"X 4-1/2"BKR S-3 R R D=3.87' ' 9960' -1 4-112"HES X NP,D=3.813" 4-1/7 TBG,12.6#,13CR-80 VAMTOP, -{ 10023' 1 — 10019' H4-1/2"X 5-1/7 XO,D=3.958 ,0152 bpf,D=3.958" 10032' H9-5/8"X 4-12"U'1QUE OVERSHOT 4-1/2"TBG STUB(12!18108) -I 10029' ' 10054' -14-12"HES X NP,D=3.813" Z 10064' H 9-5/8"x 4-1/2"BKR S-3 PKR D=3.875" ' 10098' H4-12"HES XN NP,D=3.725' 4-12"TBG,12.6#,13CR-80 VAM TOP, -I 10019' 10128 -j9-5/8"X 5-1/2"LNIQUEOVERSHOT .0152 bpf,D=3.958' 1012$' -�5 12'OTIS X MP D=4.562" 5-12^TBG STUB(05127/00) -1 10121'_ ' 10143' -19-5/8"X 5-12"HBBP TIW FICR,Co=4.75" 10148' - 17-518"MLLOUT EXTENSION,D=6.7 10153' -I7-5/8"X 5-1/7 XO,D=4.892" TOP OF 5"SCAB LNR -I 10194' I III10163' -15-1/2"OTIS X NP,D=4.562' 5-1/2"TBG,17#,13CR NSCC, -{ 10196' 10176' -5-1/7 OTIS XN NP,D=4.455" .0232 bpf,D=4.892" 10164'ELMO(08/03/91) TOP OF r L142 -I 10314' 10203' -9-5/8"X 7"T1W HYD UR HGR,D=? 9-5/8"CSG,47#,L-80 NSCC,13=8.681' E- 10783' K 10207' y-7"X 5"XO,13=4.276" PERFORATION SUMMARY REF LOG:SWS BHCS ON 09/29/81 ANGLE AT TOP RERF:38'@ 10954' III Note:Refer to Ftoduction DB for historical perf data SFF INTERVAL OPWSOZ DATE 11123' --17'MARKE2JOINT SEEPAGE 2 FOR PERFORATION DATA I I IvtIllVI• 11508' -{PBTD(5-12"SCAB LNR) 01111111 5"SCAB LNR,18#,NT13CR-80 H 11594' 1.1.1.1.1.1.1.1.1 VAWAY1 FL4S,.0177 bpf,D=4.276" X1111111111111111 7"LNR,26#,L-80 U4S, 0383. bpf,D=6.276" -I 11750' 1�1�1�1�1'1'1'1�1 DATE REV BY COM/E NTS DATE REV BY COMvENTS PRUDHOE BAY UNIT 10/05/81 ORIGINAL COMPLETION 05/24/16RWN9JNC SET K/PB VALVE(03/31/16) WELL: M-16 05/25/00 N9ES RWO 06/14/16 CJNIJMD PULLED K/PB VALVE(06/09/16) FERMT No:'1810860 12/28/08 D16 RWO 07/06/16 CJWJMD SET PB VALVE(06/10/16) API No: 50-029-20613-00 08/31/15 JTG/JND GLV CIO(08/15/15) SEC 1,T11N,R12E,1607'FNL 8 606'FEL 08/31/15 JTG/JMD FULLED XX PLUG(08116/15) 02/03/16 GRC/TLH K/PB VLV STATUS FS2 STATE BEGS BP Exploration(Alaska) ill M-16 w' r I I 1. 1 1 _ L 1 I 1 1 ( 1 I 1 1 1 PERFORATION SUR/MARY REF LOG:SWS BRCS ON 09/29/81 ANGLE AT TOP R3RF:38"@ 10954' Note:Refer to Production DB for historical perf data SPF MS?VAL OPWSQZ DATE 6" 10954-10984 0 01/06/921 ch 4" 10964-11008 S 01/04/92 4" 11000-11008 S 07/27/91 4" 11016-11036 S 07/27/91 6" 11036-11076 S 07/27/91 4" 11076-11080 S 07/27/91 4" 11100-11180 S 07/27/91 6" 11341-11356 0 05/23/98 i ■ 4.991'11'1'1'1 1111111111111111 11111111111111111 11111111111111111 DATE REV BY CONSENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/05/81 ORIGINAL COMPLETION 05/24/16 RWIWJMC SET K/PB VALVE(03/31/16) WELL: M-16 05/25/00 N9E5 FIND 06/14/16 CJNIJMD PULLED K/PB VALVE(06/09/16) PERN(T No:'1810860 12/28/08 D16 FINO 07/06/16 CJNIJMD SET PB VALVE(06/10/16) API No: 50-029-20613-00 08/31/15 JTG/JMD GLV C/O(08/15/15) SEC 1,T11N,R12E,1607'FNL&606'FEL 08/31/15 JTG/JM) PULLED XX PLUG(08/16/15) 02/03/16 GRCJTLH K/PB VLV STATUS PER STATE BEGS BP Exploration(Alaska) • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, June 01, 2016 3:33 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale; AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; Regg, James B (DOA); AK, D&C Well Integrity Coordinator Subject: NOT OPERABLE: Producer M-16 (PTD #1810860) Post-Economic Evaluation and Monitoring of Surface Casing Leak All, Producer M-16 (PTD#1810860) is an artificially lifted producer with a known surface casing leak. The well passed both a MIT-T to 3000 psi on 11/12/14 and a CMIT-TxIA to 3000 psi on 11/13/14, indicating that the well has two competent barriers to formation. On 12/23/15 a squeeze was performed on the outer annulus to repair the surface casing leak. A PB SSSV was installed on March 31, 2016. On 05/07/16 well was reclassified as Under Evaluation to obtain additional well tests for economic evaluation and extended monitoring of the surface casing leak. The well was shut in on 5/18/16 with an active surface casing leak to gas and subsequently monitored. This well is now reclassified as Not Operable. Please call with any questions or concerns. Jack Lau (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent W: 0 W: 907.564.5102 S C: 907.943.0296 H: x2376 From: AK, D&C Well Integrity Coordinator Sent: Saturday, May 07`2016 8:01 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wel Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale; AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Wet-Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; 'Regg, James B (DOA)'; AK, D&C Well Integrity Coordinator Subject: UNDER EVALUATION Producer M-16 (PTD #1810860) Economic Evaluation Extended Monitoring Of Surface Casing Leak All, 1 • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, May 07, 2016 8:01 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale;AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; Regg,James B (DOA);AK, D&C Well Integrity Coordinator Subject: UNDER EVALUATION Producer M-16 (PTD #1810860) Economic Evaluation Extended Monitoring Of Surface Casing Leak All, Producer M-16 (PTD#1810860) is an artificially lifted producer with a known surface casing leak. The well passed both a MIT-T to 3000 psi on November 12, 2014 and a CMIT-TxIA to 3000 psi on November 13, 2014, indicating that the well has two competent barriers to formation. On December 23, 2015 a squeeze was performed on the outer annulus to repair the surface casing leak. The well was on production for no flow testing from October 02, 2015 to October 13, 2015 and again from January 10, 2016 until January 14, 2016. A PB SSSV was installed on March 31, 2016. At this time, the well is reclassified as Under Evaluation to obtain additional well tests for economic evaluation and extended monitoring of the surface casing leak. If any abnormal pressure response or cellar inflow is observed, immediately report the problem to the Well Integrity Engineer and shut in the well. Plan Forward: 1. Operations: Place well on production 2. Downhole Diagnostics: Continuous well cellar monitoring 3. Operations: Multiple well tests 4. Operations: Shut In 5. Slickline: Pull PB Valve, Set TTP A 6. Fullbore: CMIT TxIA SCANNED MAY 1 12016 Please call with any questions or concerns. Thank you, Ryan Holt (Alternate:Lee Grey) • BP Alaska-Well Integrity Engineer WIC Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinatorPBP.com 1 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION commit REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Re-enter Susp Well 0 Other:PB-Valve Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 181-086 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20613-00-00 7. Property Designation(Lease Number): ADL 0028257 8. Well Name and Number: PBU M-16 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11750 feet Plugs measureds EIVED feet true vertical 9319 feet Junk measured feet [� 8); Effective Depth: measured 11508 feet Packer -F." 2 6 Z O'eb measured See Attachment feet true vertical 9133 feet Packer true vertical See Attachment feet +, 1 .. ;, Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 27-107 27-107 Surface 2705 13-3/8"72#L-80 27-2731 27-2669 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10954-10984 feet 10984-10994 feet 10994-11000 feet 11000-11008 feet 11016-11036 feet 11036-11076 feet 11076-11080 feet 11100-11180 feet 11341-11356 feet True vertical depth: 8699-8723 feet feet 8723-8731 feet 8731-8735 feet 8735-8742 feet 8748-8764 feet 8764-8795 feet 8795-8799 feet 8814-8877 feet 9002-9014 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) PB Valve Not Currently Installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): EF F1''`t Treatment descriptions including volumes used and final pressure: 9 l SC k 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 311 939 1616 1309 197 Subsequent to operation: Well Shut-In 1660 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-092 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Ail — Phone +1 907 564 4424 Date 2/26/16 Form 10-404 Revised 5/2015 Vr L ��'"y//6 RBDMS ' � / ✓!f//{[i W FE13 2 5 2016 Submit Original Only . • Packers and SSV's Attachment PBU M-16 SW Name Type MD TVD Depscription M-16 PACKER 1499.15 1499.14 9-5/8" BOT External CSG PKR M-16 TBG PACKER 9926.38 7916.12 4-1/2" Baker S-3 Hydro Set Packer M-16 TBG PACKER 10061.79 8016.43 4-1/2" Baker SABL-3 Packer M-16 TBG PACKER 10143.46 8077.1 5-1/2"TIW HBBP Packer i • Q o o O o O O o O I- O O O •- N O O o0 — ( C L[) Ln C N r Lf) I- N- I,- CO U N O O o 0 0 0 0 0 v- CO CO CO 7 (A 00 CO CO CO CO ti 00 co 00 I� LO L() O N- C)) Ln I- O CO Cr) CO O N r- O O •- r CO LO LO N N CO CY) O N r CO 0) C)) 0) I- co CO 0 1 1 1 1 1 1 1 1 1 1 F- C)) LCA M 1� N C7) I. N Lt7 (NI r- O N CO C)) LO N N N L() r N N N O) O r CO 00 C)) N- CO I. r CO in O N O N- co M M o) CO Ln M N (A LO CflO r r N r 0 0 V CI (Q I I I . I I 4-0 Q CD V r O L70 f� LO N coN M O O r �C N N N Ln 0 0 r N O O • L• r r r • C▪ O a O 02 co O CD CO O O tlL0 00 0000 �jooUUU C) � JJJM0 LU (I) d M N *k *k `; J J I# 4* r N X F- 4t *k CO CO 4# 0• NNa\O � wNN � NN L() LO I� (` CV N r r r i 'Cr NY L() IC) +�+ LCA r N- O CA 0 O O r LO O r — 00 N- Lf) N M = C) CO CO J N r O) r W W 01 - - CF- LLJoo U U w w UOu_ CC � cc � IYZZZ Z W W W W W m 00 m Z _Z Z_ D D D 0 C/) J L-1 F- . • • a N a CO 0 _) oc0 2 ~ x W O Q p • * w a_~ 0 0 J w m O 1_ Ci N N U) U) Co D * 2 „.„-o _., N co O d Q' * LC) I- V O x O N Q' U) 0 W 6 c a) * N * a) x E Q H 8 m 2 '_cW co > � � ©-°aw QO v � w - H �0) H m w a LU -N p -t - -- 030. N co � pH � �,) � 0_ —MO � Z a� Qom J J < ,00 - 2 c 0 C > 7:-I - N w U) rn W Q J Q > c) a ;4- 0g_) = 1"-- 0 F- o Do) --- o M - 0 w 0 = O0 W a n I w I- Er to Q fyr- m � __J -- ,- HO O = a) N g-1-1-1 d 2 m@� ul rn > W 0w -2— OmD T > > pm c20 O rnz �y� @�U) F Q ~ � 0) > o * r 00r 2:), Np W ' '- J' ooU0 -1- W0 � W � O a) 2 Ow _ 92Q tU 7 wgp � 0z cz2z J >> NrnJ C7 1- -0-.) ' ,7,, c2,a E � p OXa c 0 °- U) j0) ' J Z W J * [' H � w 4- D * Z C/) 0 wQ * g .-7-- wJQ : t < - ALT O m W W V_ p ( � u) p J � Y � z > w Q � � � U ii Y � °' > mN0a ? a Vo ozJQaO N ___ O Oz . oO d EZ _ OkJa * ri , 1..0 — 2 jC� 00 \ 00W Xw Ce < ' vv) co _ = JO fX QotoWf- � J � OpQON QH � o`no a. � QI- � >, z � = � I- j • S c s O E E a) 0 z a Q co 5N D CD 0000 CC 2 2 2 2 O ti CP 0 co coco Q. O 2 2 2 o 2 2 *k CO 0002 W' a' W' E O v' >+ Q ft J J _>_I J M (O OO N > ww 000 co O fX >> 0Y Y Y Y Y Y Y o X Q Q Q Q w ctc Z - m H H H H M N J 0 r o a a 0 0 0 Q H J W ' W W W W H H H O W J J J J J W W 5 J H J H U V) * D W D D D D W W W * a) 0_ co d a a a. cn co co 1 0 N m TREE= VVe_LHEAD ktEVO • S��ETY NOTE WELL REQU/RES A SSSV. i _.__._ ,ACTUATOR= BAKER C "`CHROME TBG&SCAB LNR' OKB.ELEV= 52.3' BF.B EV= 27.58' 20"CONDUCTOR -r- .? '46 .0 I KOP= 2000' 9-5/8"HES H 1487' +4.• q0 1499' H 13-3/8"X 9-518'BKR ECP Max Angle= 47" 4500' �, X CENENTER 1982' -14-1/2"HES X NP,D=3.813" Datum MD= 11148' miliill Datum TVD= 8800'SS _ 1 't..,z' IN 1982' H4-112"KfP6VALVE CURRENTLY 9-5/8"CSG,47#,L-80 HYD 563,D=8.681" H 1535' -. 2613' H9-518-DJ PKR /—. 9-5/8"FOC --1 2700' / GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DA TT 13-3/8"CSG,72#,L-80,D=12.347" 3 1 H 273'-----__ I 4 3597 3310 46 MMG DOME RK 16 08/15/15 '0 3 6860 5603 44 MAG DO? RK 16 08/15/15 Minimum ID = 3.725" @ 10098'l 2 8609 6934 36 MMS DOME FE 16 08/15/15 f 1 9815 7835 43 MMC SO RK 24 08/15/15 4-1/2" HES XN NIPPLE I 1 1 9896' H4-1/2"HES x MP,D=3.813" x 9926' -19-5/8"X 4-1/2"BKR S-3 PKR,D=3.87" 1 1 9960' H 41/2"HES X NIP,D=3.813" 41/2"TBG,12.6#,13CR-80 VAM TOP, -{ 10023' }-- 10019' -14-1/2"X 5-1/2"XO,D=3.958 .0152 bpf,13=3.958" 1 10032' -19-5/8"X 41/2"MOUE OVERSHOT 4-1/2"TBG STUB(12/18/08) -1 10029' I ' 10054' H4-1/2"HES X NP D=3.813" Z >4 10064' H9-5/8"x 4-1/2"BKR S-3 PKR,D=3.875" 1 1 10098' H41/2"HES XN NP,D=3.725" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, -{ 10019' 10128' H9-5/8"X 5-1/2"UNIQUE OVERSHOT .0152 bpf,D=3.958" 10128' .H5-1/7'OTIS X MP,D=4.562" 5-1/2"TBG STUB(05/27/00) --1 10121' 1 10143' -19-5/8"X 5-1/2"FBBP TNV H(R 0=4.75" \ 10148' -17-5/8"_ MLLOUJT EXTENSION,D=6.2" 1o153' H7-5/8"X 5-1/2"xo,D=4.892" 10163' -5-1/2"ons X NP,ID=4.562" TOP OF 5"SCAB LNR H 10194' 5-1/2"TBG,17#,13CR NSCC, - 10196' 10176' 15-1/2"ons XN NP,D=4.455" .0232 bpf,13=4.892" 10164'BAD(08/03/91) 4"%\ TOP OF 7"LNC H 10314' 10203' H9-5/8"X 7"INV HY D LNC HGR,13=? 9-5/8"CSG,47#,L-80 NSCC,ID=8.681" H 10783' ' 10207' H 7"X 5"XO,D=4.276" PERFORATION SUMMARY IL REF LOG:SWS BHCS ON 09/29/81 ANGLE AT TOP PERF:38"©10954' IT Note:Refer tocINTERVAL OD Production DB fort I perfdATE 1 11123' --17"MARKER JOINT SEE PAGE 2 FOR PERFORATION DATA I 1 I I I ) 11508' H PBTD(5-1/2"SCAB LNC 5"SCAB LNR,18#,NT13CR 80 -1 11594' V/.'.'.....'. FL4S,.0177 bpf,13=4.276" ..�.�.�..�.�.�. 7"LNR,26#,L-80 LAS,.0383 bpf,D --1=6.276" � 11750' ......� .. 0. 0.1 DATE REV BY COMMENTS DATE REV BY CDMbENTs PRLDHOE BAY UNIT 10/05/81 ORIGINAL COMPLETION 08/31/15'JTG/JMD GLV CIO(08/15/15) VIE-L: M-16 05/25/00 N9E5 RWO 08/31/15 JTG/JMD PULLED XX RUG(08/16/15) PERMT No:'1810860 12/28/08 D16 RWO 02/03/16 GRCIILH K/PB VLV STARS PER STATE BEGS AR No: 50-029-20613-00 12/20/10 MB/JMD ADDEDSSSV SAFETY NOTE SEC 1,T11N,R12E,1607'FNL 8 606'FEL 04/22/12 MBI/PJC GLV CIO(4/17/12) 11/17/14.MG/JM)XX R.UG/GLV C/O(11/12-13/14) BP Exploration(Alaska) 0 M_16 • 1 j 1 • LI 1 1 PERFORATION SUIM ARY REF LOG:SWS BHCS ON 09/29/81 'I I ' ANGLE AT TOP PERF:38°@ 10954' Note:Refer to Ptoduction DB for historical perf data SPF INTERVAL OPWSOZ DATE (lij 6" 10954-10984 0 01/06/92 4" 10964-11008 S 01/04/92 4" 11000-11008 S 07/27/91 4" 11016-11036 S 07/27/91 6" 11036-11076 S 07/27/91 4" 11076-11080 S 07/27/91 4" 11100-11180 S 07/27/91 S‘'I 6" 11341-11356 0 05/23/98 ,i�-,�,1- n ,1.1.4...1 11.1.111.141.1.1 ►.4././.1!1.1!1./. DATE REV BY COMMENTS DATE REV BY COIMENTS PRUDHOE BAY UM - 10/05/81 ORIGINAL COMPLETION 08/31/15 JTG/JMD GLV CYO(08/15/15) WELL M-16 05/25/00 N9ES RWO 08/31/15 JTG/JMD PULLED XX PLUG(08/16/15) PERMIT No: 1810860 12/28/08 016 RWO 02/03/16 GRC/TLH K/PB VLV STATUS PBR STATE BEGS AR No: 50-029-20613-00 12/20/10 Pv /JMD ADDED SSSV SAFETY NOTE SEC 1,T11N,R12E, 1607'FNL&606'FE 04/22/12 MEM PJC/GLV C/O(4/17/12) ' 11/17/14 JMG/JM)XX FLUG/GLV C/O(11/12-13/14) BP Exploration(Alaska) VOF Thr • • alfr,Iyy,s. THE STATE Alaska Oil and Gas "A-i� te, of Conservation Commission :.,, ALASI�:A � ffF �� 333 West Seventh Avenue '2 r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 (4'ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Daniel Alaska Wells Integrity and Compliance Team Leader BP Exploration (Alaska), Inc. SCANNED MAR 0 3 2016 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU M-16 Permit to Drill Number: 181-086 Sundry Number: 316-092 Dear Mr. Daniel: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P-4 -,S& Cathy . Foerster Chair DATED this'e.--) day of February, 2016. RBDMS i - FEB 15 2016 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIOION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tabing 0 Change Approved Program LI Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other PB-Valve Design IZ • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 181-086 ' 3, Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development Q• 99519-6612 Stratigraphic El Service 0 6. API Number: 50-029-20613-00-00 7 If perforating: What Regulation or Conservation Order governs well spacing in this pool'? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU M-16 NEL9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028257 PRUDHOE BAY,PRUDHOE OIL * FEB 04 2016 11. PRESENT WELL CONDITION SUMMARY 075 Z 12-3//C. Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: I Effective Depth TVD: MPSP(psi): I Plugs(MD): Junk(MD): 11750 9319 - 9960 7941 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 27-107 27-107 Surface 2705 13-3/8"72#L-80 27-2731 27-2669 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: I Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic RI 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic El Development Q Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil Ef . WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG El Commission Representative: GINJ El OpShutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true a .the procedure approved herein will not Contact Daniel,Ryan be deviated from without prior written appr . . Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan Title Alaska Wells Integrity&Compliance Team Leader Signature // Phone +1 907 564 5430 Date d ‘ ow‘ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: C� 3\Le — O ` 2_ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance El Other: Post Initial Injection MIT Req'd? Yes 0 No El Spacing Exception Required? Yes❑ No IE1/ Subsequent Form Required: 1 U—4o 4 n APPROVED BYTHE Approved by: t /N t /_ COMMISSIONER COMMISSION Date:Z-� / 3. ORU3INAL RBDMS I-k-- FEB 2 5 2016 Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval Z`1q III. Submit Form licate and Attachments in Du A 2/,//f ,,s, z,i-/� • • 0 0 0 0 0 0 0 0 U o 0 0 0 0 0 0 0 0 67 CO CIO N N- (.0 CO r- co 00 co r- InO ti C) LCA 'Cr N- o CO M CO O N r O) CO (O CO L() N N CO O) O N— N-- N r CO O O) O) r- CO co I- N- N- N v O N Cr) 0) LO N N N Ln r N N N 0) O r CO CO 03 N- CO ~ M co CIO O) M LC) M N CA r� LO (O r- O r r N O r r r r 0 0 r r r r r N-- ▪C.) V 0 C Q• r O) Lf) _� r O) Cb to N M CO co O C N N N O O r N 0 0 r r r r r a▪mi 03 n. O o O O coo O a0 co a) _j _j0ooMcUU O J J M c0 CIO M •� 72.1 N x r` N- N- I-- *k *k co c0 co - - _ Z CO O) (NI N U oNMcoCO NNrr Lnll7 N- N- - - N r r r i LU r N- O r- O) 4 O O r L() 0 r CA O C co N- LL) CN V- (Y) r O O CIO N r O) r r d7 W W H Q Q O � a aNU OX 000 Z ZOLLXccc Z W W W W W m m m O H F _Z Z Z U U) Z Z J J J I— I— I— • • a, Co m COr CO 00 r ao (V) O) CA I- O Nt CO O r p, N O Ll7 r CYj t!7 a0 � � p CO CO CO CO CO CO CO CA a O CO co r CO r r CO « O I d r O V t jf a CA N O L() OO M Ln _'t N p p CO r O O C) CC) co CO CO CO CO CO CA 0 Luo 0 0 LU � O a o 0 m O O W Y Y F- = tt d' O CO CO CO o o Cfl J U U W W 4.0 J J J d d (/) Z Q w O O O O CD 0 r M < < < w C O O r r r r r r _U _U U J W W ° J r r r r r r r r Z Z Z O JJ J co ¢ ¢ ¢ _ 0 0 CL CL _ _= Z 0 r 0 0 00 w w w W a H < J < C.0 2 2 0 cn co co co co a Q E o = L �f O CO CO CO O Q Ll) CO Cr) O O m 00) 0) 0) 0000 ,— M 0 O O O r r r r r r = = = = = r r r r co L a) eC cn Y U 0 CO CC O co co con coco 0 a a, V 0 U i5WW ncncncnWM 0 t d a C, _ _ I- N N N N CA CT CC) CA CA CA C) C) 0) p p 0 C C� C� C� CA O) M C7) M CA W Z 0 r Z W ¢ W CSO M M M I� M O w p w p N U. a N N N N N Z U LL. W Oa ti N- N- Ln ¢ C] JJ 1 J J J 0' m 0 D W J J Q 0 W w ¢ ¢ CL CO L_ LL LL CO CL a, E as z co Co co CO CO CO CO co Co CO i r r r r r r r r LL LL co O LL N CY LL 2 2 2 2 m a d a U 2 2 w a ¢ ¢ mmL� � c� cna � • • I Packers and SSV's Attachment PBU M-16 SW Name Type MD TVD Depscription M-16 PACKER 1499.15 1499.14 9-5/8" BOT External CSG PKR M-16 TBG PACKER 9926.38 7916.12 4-1/2" Baker S-3 Hydro Set Packer M-16 TBG PACKER 10061.79 8016.43 4-1/2" Baker SABL-3 Packer M-16 TBG PACKER 10143.46 8077.1 5-1/2"TIW HBBP Packer • V 6/6/01 . IIWireline Work RequestM-� 6 ROW (Distribution Wireline(4) Well: M-16 AFE: APBWELIR Reading File Date: 4/12/2012 Engineer: Stan Groff IOR: 200 FTS: IOR AWGRS Job Scope: PB SV H2S Level: Problem Description According to new AOGCC regulations a subsurface safety valve needs to be e installed in this well.A Weatherford PB safety valve will be used. . NOTE: Prior to setting the PB valve a larger orifice gas lift valve should be installed. Initial Problem Review Remedial Plan -WIRELINE ACTION Install PB safety valve set to close of 479 psi at 60*F. NOTE this is for SHOP SETUP ONLY Operate well at>400 psi. Valve designed to close when FTP drops to 250 psi. Date Work Completed Well Status/Results Date by Problem Resolved ? Y _ N : Well Review(Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Expected NOB: Avg. WC (%) Actual NOB: Lift Gas (MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP (psi)/Steady? MAINTENANCE ONLY CLP (psi)/Steady? (e.g. Fix AC, Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth: (e.g. deepen, optimize orifice) IA Fluid Level: Post-Wellwork Date of FL Survey: / / Follow-up Recommendations: • "PB"Valve Calculation Sheet Well# M-16 Date: 04/12/12 Test Data Test Date 04/11/12 Gross Fluid Rate 1852 BLPD Flowing Well Head Pressure 432 psi Flowing Well Head Temperature 109 deg F GOR 2186 scf/bbl TGLR 2073 scf/bbl Setting pressures based on measured data taken at time of test. Flowing Pressure Calculations Based on Muk-Brill Multiphase Flow Correlation "PB"Valve Setting Depth TVD 1982 ft Flowing Tubing Pressure With Gas Lift 202 psi Flowing Tubing Pressure Without Gas Lift N/A psi Valve set to close at 255# Pwh Flowing Tubing Pressure @ 255# Pwh 550 psi PB"Valve Test Rack Set Pressure at 60 deg F I 479 Ipsi NOTE: Well needs to flow at>400# Pwh Valve set to close at 255# Pwh • • Tubing Pressure at Valve 550 BPT(psia) 564 >1238 <1238 Temperature(deg F)at Valves 131 a 1.306E-05 2.16834E-05 b 1.163158 1.137314 Base Pressure 496.595601 c -583.357 -564.56046 Base Temp (TV-60) 71 498.73491 491.786994 Corrected Pressure 491.786994 psia TCF 0.87134478 /olume Ratio for Valve Size = 1.257 Pb @ 60 = 479.239629 Test Rack Pressure = 381 Volume Ratios 4 1/2" & 5 1/2" 1.314 3 1/2" 1.257 2 7/8" 1.211 2 3/8" 1.204 I Idt= aw VNELLf€AD= INcEVOY • nn-16 SO E TBG&SCAB DESA SSSV. ACTUATOR BAKER C OKB ELEV= 52-3' 120'CONDICTOR IH ? 1 11 BF.at /= 27.581 �j. ! 0114 KOP 2000'1 f 9-Sirr Fc 1-1 1487' '7 � 1499' I- 13-3/8'X 9-5/8'BKR ECP I _ I Max Angle= 47° .4500 ♦. 1982' —I4-1/2"HES X 1P,D=3.813' Datum ID= 11148' Datum ND= 8800'SS , %ra: 1982' H4-1/2"K/PB VALVE CUIRBYTLY OUT 02/03/16 9-5/8"CSG,47#,L-80 HY D 563,D=8.681" i 1535' 7". 2613' H 9-5/6"DV PKR 9 5/8^FOC — 2700' GAS LFT MANDRELS ST AD ND DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80,D=12.347' —I 2733' ' I 4 3597 3310 46 MMG DCMiE FE 16 08/15/15 I 3 6860 5603 44 !MAG DOMNE FE DOME RK 16 08/15/15 iii 2 8609 6934 36 MAG DO16 08/15/15 Minimum ID = 3.725" @ 10098' "` 4-112" HES XN NIPPLE 1 9815 7835 43 MAG SO FE 24 08/15/15 ' ' 9896' -I 4-1/2"FES X NP,D=3.813" Z x 9926' —19-5/8"X4-1/2'BKR S-3 RKR,ID=3.87' ' 9960' —4-1/2"HES X NP,D=3.813' 4-1/2'TBG,12.6#,13CR-80 VAM TOP, H 10023' j---- 10019' H4-1/2'X 5-1/2"XO,D=3.958 .0152 bpf,D=3.958" 1 10032' —19-5/8"X 4-1/2"UNIQUE OVERSHOT 4-1/2"TBG STUB(12/18/08) 10029' I 10054' —I 4-112"HES X NP,D=3.813" 10064' H9-5/8"x 4-1/2"BKR S-3 PKR,D=3.875" I 10098' —14-1/2"I C^,XN NP,D=3.725" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, H 10019' 10128' I—9-5/8"X 5-1/2"UNIQUE OVERSHOT 0152 bpf,D=3.958' 10128' 5 112'OTS X NP,D " 5-1/2"TBG STUB(05/27/00) I— 10121' ' 10143' H- 9-518")(011:1/2.X 5-1/2 H3BP=TNV A4.562(' 0= 4.75" 10148' —17-5/8"MLLOUT EXTENSION,,D=6.7 10153' H7-5/8"X 5-1/7 XO,13=4.892' 10163' H5-1/2"OT1S X NP,D=4.562" TOP OF 5'SCAB LNf2 I- 10194' ,,..i 5 1/2"TBG, 17#,13CR NISCC, H 10196' 10176' —5-1/2'OTS XN NP,D=4.455' _0232 bpf,D=4.892" 10164'ELMD(08/03/91) I TOP OF 7"LW —I 10314' I--. , 10203' —9-5/8"X 7"TNN HYD LIR HGR ID=? 9-5/8"CSG,47#,L-80 NSCC,ID=8.681" I-- 10783' \ 10207' —17"X 5"XO,D=4.276" PERFORATION SUKOAARY y k REF LOG:SW5 BRCS ON 09/29/81 ANGLE AT TOP PERF:38°@ 10954' T Note:Refer to Production DB for historical perf data SFF INTERVAL OPWSO7 DATE 11123' —17"MARKER JOINTSEE PAGE 2 FOR PERFORATION DATA 11 11508' J PBTD 5-1/2"SCAB L ♦4.1'•'4.4"4'1'4 I ( ) 5'SCAB LNR,18#,NT13CR-80 —I 11594' 1.1.1.1♦1.1.1.1.1 FL4S,.0177 bpf,C=4.276" 11111111111111111 7"LNC 26#,L-80 U4S,.0383 bpf,D=6.276" H 11750' 1.1.1.1.1.1.1.1• DATE REV BY COMENTS DATE REV BY C0tBJTS PR.lDHOE BAY UNIT 10/05/81 ORIGINAL COMPLETION 08/31/15 JTG/JPA)GLV CIO(08/15/15) Mat: M-16 05/25/00 N9I S R#dO 08/31/15 JTG/JMD PUU_ED XX PLUG(08/16/15) PERMIT No:'1810860 12/28/08 D16 IMO 02/03/16 GRCJTLH K/FB VLV STATUS PER STATE BEGS API Nb: 50-029-20613-00 12/20/10 P /AU ADDED SSSV SAFETY NOTE SEC 1,T11N,R12E 1607'FN-8 606'FEL 04/22/12M3M,PJC GLV CIO(4/17/12) 11/17/14 JMG/JMD XX PLUG/GLV C/O(11/12-13/14) 813 Exploration(Alaska) 41 M-16 0 I 41 I '4 I_I _ I k LI U . z I I ( ) I I Z 23 I I PERFORATION SU V RY Fill LOG:SVVS BRCS ON 09/29/81 'I I ' ANGLE AT TOP PERF:38"©10954' Note:Refer to Production DB for historical perf data SPF NT RVAL OPt4VSQZ DATE (IA 6" 10954-10984 0 01/06/92 4" 10964-11008 S 01/04/92 4" 11000-11008 S 07/27/91 4" 11016-11036 S 07/27/91 6" 11036-11076 S 07/27/91 4" 11076-11080 S 07/27/91 4" 11100-11180 S 07/27/91 6" 11341-11356 O 05/23/98 S‘'l OL U I .tom. 1i1i11/111111��1 11111111111111111 11111111111111111 /*1*1*1*1*1*1*1*14 DATE Fel/BY COMENTS DATE REV BY COMMENTS R&OHOEBAY MT 10/05/81 ORIGINAL COMPLETION 08/31/15 JTG/JMt)GLV C/O(08/15115) WELL' M-16 05/25/00 N9ES F VO 08/31/15 JTG/JMD FULLED XXRIJG(08/16115) F$ZMTNo:'1810860 12/28/08 D16 MVO 02/03/16 GRCITLH K/PB VLV STATUS PM STATE BEGS API No: 50-029-20613-00 12/20/10 MB/JM) ADDED SSSV SAFETY NOTE SEC 1,T11 N,R12E, 1607'FPL&606'Fa 04/22/12 MOM PJC GLV C/O(4/17/12) 11/17/14 JMG/JM)XX RUG/GLV CIO(11/12-13/14) BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIIIIN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate `❑ , Alter Casing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well L� V Re-enter Susp Well 0 Other:OA Cement Squeeze fff 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 181-086 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20613-00-00 7. Property Designation(Lease Number): ADL 0028257 8. Well Name and Number: PBU M-16 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11750 feet Plugs measured feet RECEIVED true vertical 9319 feet Junk measured feet e Effective Depth: measured 11508 feet Packer measured See Attachment feet FEBCpp 0 9 2016 true vertical 9133 feet Packer true vertical See Attachment feet AOGGC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 27-107 27-107 Surface 2705 13-3/8"72#L-80 27-2731 27-2669 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10954-10984 feet 10954-10984 feet 10984-10994 feet 10994-11000 feet 11000-11006 feet 11036-11076 11016-11036 feet 11036-11076 feet 11076-11080 feet 11100-11180 feet True vertical depth: 8699-8723 feet 8699-8723 feet 8723-8731 feet 8731-8735 feet 8735-8742 feet 8764-8795 8748-8764 feet 8764-8795 feet 8795-8799 feet 8814-8877 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attach'rrierit true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): OA Squeeze at surface. Treatment descriptions including volumes used and final pressure: .Ai�9ll I ,y 9 Gallons Squeeze ueeze Crete,2168 psi. 0. i�9�I k 6 y i 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 292 230 1024 1801 659 Subsequent to operation: 0 341 40 1374 299 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations WI Exploratory 0 Development II Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-378 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ....i..._ et,/,---- Phone +1 907 564 4424 Date 2/9/16 Form 10-404 Revised 5/2015 I'TL z f 1 q I6 RBDMS L L FEB 1 0 2016 Submit Original Only 2,6446 • • Packers and SSV's Attachment PBU M-16 SW Name Type MD TVD Depscription M-16 PACKER 1499.15 1499.14 9-5/8" BOT External CSG PKR M-16 TBG PACKER 9926.38 7916.12 4-1/2" Baker S-3 Hydro Set Packer M-16 TBG PACKER 10061.79 8016.43 4-1/2" Baker SABL-3 Packer M-16 TBG PACKER 10143.46 8077.1 5-1/2"TIW HBBP Packer • • �p I� O CO CO o Ns 0 CO — CO 00000 f� cD i7011. t LO LO N U w 0 0 0 0 0 0 0 0 0 L CO f- V Cfl CO CO NY m co CO O ti CO CO CO f- O7 LC) LC) O I� O LC) cr r-- C.0 CO CO CO O N L- O) CO CO LO lO N N CO 0) 0 .- N a- CO 0) O O r- CO CO H 6) 10r-- N O) Lf) N O N CO 0) LO N N N LO N N N O) O CO 00 O) N- CO I. 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Q II r II p C 0 co -c ami wU O 3 ccarn . cnO a`) , Upo rn Uo� a) Ocnop_ v) � in 0Et 0 p N O N I I > `- U ' o U co `~ (a a 11 co N I I N p - -0 00 O ( II = N > O Q a) �- �p N °2S II -m II II O i E -0 II 2 (0 ai II coo —u, 0) - -c 1n a) a) Lc) i; C) > - O ,� O - r O - ca O N rn O 0 C ON- > Q > a`) ‘- i. Hso c -o 1- o co notsu) i- UOau 1- chi cc>nH _c co) cu) Hrn > cA1- > ._— u) CD CO CO CO co co CO O 0 p p C) C) o IC) f o(0 N CO 00N - N N N r ,- r r • • Cl) C _O 4' E a a) cn w ~ O - CD 5 � r � O m to O a a) o 0 a) N a) a) CT(Tco O a) ca 0 0 U) m TREE= ' ow • -- •WELLHEAD= Mc EV OY M -16 S NOTE: WELL REQUIRES A SSS V. ACTUATOR= BAKER C CHROME TBG&SCAB LNR• OKB.ELEV= 52.3' 20"CONDUCTOR ? 1 1 1 --J BF.ELEV= 27.58' ��6 91�1 KOP= 2000' 9-5/8'1-ES H 148T �� ��. 1499' H13-3/8"X 9-5/8"BKR ECP Max Angle= 47"@ 4500' CEMENTER 1982' H4-1/2"FES X NP,D=3.813" Datum ND= 11148' I __, Datum ND= 8800'SS 19$2' H4-112"K1P8 VALVE CURRENTLY OUT 02l03rts /— — 2613' --I9-5/8"DV PKR 9-5.18"CSG,47#,L-80 HYD 563,D=8.681" H 1535' 9-5/8"FOC 2700' -� GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80,D=12.347' I—I 2733' I d 4 3597 3310 46 MR+IS DOME RK 16 08/15/15 ' 3 6860 5603 44 MM3 DOME RK 16 08/15/15 Minimum ID = 3.725" @ 10098' 2 8609 6934 36 NM DOME RK 16 08/15/15 1 9815 7835 43 MMG SO RK 24 08/15/15 4-1/2" HES XN NIPPLE I I 9$96' --I4-1/2"FES X NP,D=3.813" Z x 9926' I—9-5/8"X 4-1/2"BKR S-3 PKR,D=3.87" ' ' 9960' I—4-1/2"FES X MP,D=3.813" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, —I 10023' 100191 —I4-1/2"X 5-1/2"XO,D=3.958 .0152 bpf,D=3.958" --I 10032' H9-5/8"X 4-1/2"MOLE OVERSHOT 4-1/2"TBG STUB(12/18/08) —I 10029' ' ' 10054' H4-1/2'FES X NP,D=3.813' Z Xr 10064 H9-5/8"x 4-112"BKR S-3 PKR,D=3.875" 1 ' , 10098' H4-1/2"FES XN NP,D=3.725" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, —I 10019' 10128' H9-5/8"X 5-1/2"UNIQUE OVERSHOT 0152 bpf,D=3.958" �' N 10128' J 5 112"OTS D X NP, =4.562" 5-1/2"TBG STUB(05/27/00) H 10121' 10143' H9-5/8"X 5-1/2"FBBP TNV PKR,D=4.75" 10148' 7-5/8"MLLOUT EXTENSION,D=6.2" - 1 10153' 7-5/8'x5-1/2"xo,D=4.892" TOP OF 5"SCAB LNC H 10194' 10163' „Till 5 112"OTS X NP.ID=4.562" 5-1/T TBG,17#,13CR NSOC, —{ 10196' 5-1/2"OTS XN NP,D=4.455" .0232 bpf,D-4892" 10164'B_M D(08/03/91) TOP OF 7"LN2 H 10314' J 10203' —I 9-5/8"X 7"TIW HYD LNC HGR,ID=? 9-5/8"CSG,47#,L-80 NSCC,13=8.681" H 10783' 10207' --17"X 5"X0,13=4.276" PERFORATION SUMMARY L REF LOG:SVVS BHCS ON 09/29/81 ANGLE AT TOP PITT:38"n 10954' 1-7 Note:Feer to Ptoduction DB for historical perf data 11123' J7'MAW�CJOM SR V1TERVAL O NSOZ .1 DATE l SEE PAGE 2 FOR PB;FORATION DATA I I I ♦•'tY'�"t"�'�'. 11508' I-1PBTD(5-1/2"SCAB LNZ) 5"SCAB LM,18#,NT13CR.80 H 11594' •iii.i.4 VVI FL4S,.0177 bpf,D=4.276" /444444444 44,44444 7"LNR,26#,L-80 U4S,.0383 bpf,13=6.276" H 11750' ......../.....0 DATE REV BY COMVENfTS DATE REV BY COMvIENTS PRUDHOE BAY UNIT 10/05/81 ORIGINAL COMPLETION 08/31/15 JTG/JMD GLV C/O(08/15/15) WELL: M-16 05/25/00 NOBS RWO 08/31/15 JTG/JMD PULLED XX PLUG(08/16115) FERMI No:'1810860 12/28/08 D16 RWO 02/03/16 GRC/TLH K/FB VLV STATUS PER STATE REQS API Pb: 50-029-20613-00 12/20/10 MB/JMD ADDED SSSV SAFETY NOTE SFC,T11N,R12E,1607'FN-&606'Fa 04/22/12 MBM PJC GLV CIO(4/17/12) 11/17/14 JMG/JMD XX PLUG/GLV 00(11/12-13/14) _ _i BP Exploration(Alaska) II • M-16 1 if Al 11 x 1 FERFORA11ON SUIVMARY REF LOG:SWS BRCS ON 09/29/81 ANGLE AT TOP PERF:38°@ 10954' Note:Refer to Ftoduction DB for historical perf data SPF NTER/AL OPWSOZ DATE ''1‘ (ij 6" 10954-10984 0 01106/92 4" 10964-11008 S 01/04/92 4" 11000-11008 S 07/27/91 4" 11016-11036 S 07/27/91 6" 11036-11076 S 07/27/91 4" 11076-11080 S 07/27/91 4" 11100-11180 S 07/27/91 _ 6" 11341-11356 0 05/23/98 — I, n ❖ ;❖;•01 • ►0000.,.o4 ••�0000001 DATE REV BY COMMENTS DATE 'REV BY COMMENTS PRUDHOE BAY UNIT 10/05/81 ORIGINAL COMPLETION 08/31/15 JTG/JMD GLV C/O(08/15/15) WELL: M-16 05/25/00 N9ES RWO 08/31/15 JTG/JMD PULLED XX PLUG(08/16/15) PERMIT No:'1810860 12/28/08 016 RWO 02/03/16 GRC/TLH K/PB VLV STATUS PER STATE REGS API No: 50-029-20613-00 12120/10 NES/JM) ADDED SSSV SAFE I Y NOTE SEC 1,T11 N,R12E, 1607'FNL&606 FEL 04/22/12 MBM'PJC GLV CIO(4/17/12) 11/17/14 JMG/JM)XX PLUG/GLV GO(11/12-13/14) BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday,January 15, 2016 7:35 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Peru, Cale;AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; Regg, James B (DOA) Subject: NOT OPERABLE: Producer M-16 (PTD#1810860) Rapid bubbling and LELs in cellar All, Producer M-16 (PTD#1810860) passed an MIT-OA to 1200 psi on January 13, 2016 with no signs of fluid to surface. The well also passed a non-witnessed no flow test(NFT) on January 14, 2016. However, when placed on production, the well began to exhibit rapid bubbling in the cellar with LEL readings upwards of 80%. There was no change in conductor bubbling or reduction in LEL levels while pressuring up and bleeding off the outer annulus during the MIT. When the inner annulus (IA) was bled for the NFT,the bubbling in the cellar stopped and the LEL levels dropped down between 3- 6%. At this time,the well is reclassified as Not Operable and shall remain shut in until integrity can be confirmed or restored. Plan Forward: 1. Downhole Diagnostics: Perform pressure fall off diagnostics on IA 2. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. Thank you, �. ;; [i .�ui� 0 32-016 Whitney Pettus (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator E tablet Wei,-. tarscwn WIC Office: 907.659.5102 WIC Email: AKDCWelIIntegrityCoordinator@BP.com Front: AK, D&C Well Integrity Coordinator Sent: Saturday, January 09, 2016 4:11 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;-AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale; AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; 'Regg, James B (DOA) (jim.regg@alaska.gov)' 1 • i Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, January 09, 2016 4:11 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale;AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer M-16 (PTD #1810860) Place on Production for Surface Casing Leak Evaluation and No Flow Testing All, Producer M-16 (PTD#1810860) is an artificially lifted producer with a known surface casing leak. The well passed both a MIT-T to 3000 psi on November 12, 2014 and a CMIT-TxIA to 3000 psi on November 13, 2014, indicating that the well has two competent barriers to formation. On December 23, 2015 a squeeze was performed on the outer annulus to repair the surface casing leak. At this time,the well is reclassified as Under Evaluation to obtain an updated no flow test (NFT) and determine if the surface casing repair was successful. This well requires a subsurface safety valve (SSSV) in order to flow. BP was granted permission by the AOGCC to flow this well without a SSSV for up to fourteen days before requesting a no flow test (NFT). The well was produced for twelve days between October 02, 2015 and October 13, 2015 in order to gather well tests and surface casing diagnostics. It was then shut in to treat the surface casing leak and is now ready to be placed back on production. As the well has two more days that it can be produced without a SSSV, a NFT will be requested by the integrity team no later than forty eight hours after the well is brought online. After state notification is made,the well can remain online for an additional five days before it must be shut in. This well shall not remain online for more than seven days total. If any abnormal pressure response or cellar inflow is observed, immediately report the problem to the Well Integrity Engineer and shut in the well. Plan Forward: SCANNED SEP 1 5 2016 1. Operations: Place well on production 2. Downhole Diagnostics:Warm MIT-OA to 1200 psi with liquid 3. Well Integrity Engineer: Request state witnessed NFT within 48 hours of well production 4. Downhole Diagnostics: Perform NFT within 5 days of state notification 5. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. Thank you, Whitney Pettus 1 • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, October 06, 2015 9:03 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale; AK, OPS Well Pad MN; Regg, James B (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric;Wallace, Chris D (DOA) Subject: UPDATE October 05, 2015: UNDER EVALUATION: Producer M-16 (PTD #1810860) Flow Well for Economic Evaluation All, Producer M-16 (PTD#1810860)test of the surface safety valve system passed on October 6th 2015. With this passing test, BP has been granted permission by the AOGCC to flow this well for up to fourteen days before requesting a no flow test (NFT). As this well also requires a subsurface safety valve (SSSV) in order to flow, BP with gather well tests and surface casing diagnostics over the remaining nine days of the evaluation period. This information will be used to determine if a NFT will be requested at the end of the 14 day clock or if the well status will be returned back to Not Operable. If any abnormal pressure response or cellar inflow is observed, immediately report the problem to the Well Integrity Engineer and shut in the well. Plan Forward: 1. Operations: Place well on production—DONE 10/02/15 2. Operations: Obtain well tests 3. Downhole Diagnostics: Warm MIT-OA to 1200 psi with liquid 4. Well Integrity Engineer: Evaluate for surface casing repair& request for a NFT by day 14 5. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. �u ��� G p 4 2,Q16, Thank you, S Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator OW WIC Office: 907.659.5102 WIC Email: AKDCWelIIntegrityCoordinator@BP.com From: AK, D&C Welf • -• •I, Coordinator 1 p - /8/ - og Loepp, Victoria T (DOA) From: Sayers, Jessica <Jessica.Sayers@bp.com> Sent: Tuesday,July 21, 2015 9:10 AM To: Loepp, Victoria T (DOA) Subject: RE: PBU M-16(PTD 181-086undry 315-378) Well Lock top job to micro annu a squeeze procedure Follow Up Flag: Follow up Flag Status: Flagged SCANNED AUG 1 3 2u1:1 Awesome! Thank you Victoria! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, July 21, 2015 9:07 AM To: Sayers, Jessica Cc: Daniel, Ryan Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) Well Lock top job to micro annular squeeze procedure Jessica, The proposed change to add a Well Lock top job to the micro annuli squeezes for the following sundries is approved. Please include this approved modification with the approved sundries. • A-34A: (PTD185-105, Sundry 315-412) • H-11: (PTD180-068, Sundry 315-413) • R-24: (PTD193-074 Sundry 315-414) - . TD 181-086, Sundry -37: Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeveaC.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Sayers, Jessica [mailto:Jessica.Sayersf bp.com] Sent: Tuesday, July 21, 2015 8:55 AM To: Loepp, Victoria T(DOA) Cc: Daniel, Ryan Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) Hi Victoria! 1 Just wondering if I can be of any further help. Would it be okay to move forward with the portion of these jobs we already have approval for(the SqueezeCrete portion only), while we wait for the WeIlLock piece to get sorted? Thanks! Jess Sayers From: Sayers, Jessica Sent: Thursday, July 16, 2015 2:33 PM To: 'Loepp, Victoria T(DOA)' Cc: Daniel, Ryan Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) The results and findings have not yet been released or finalized. WeIlLock is a Newtonian fluid that reacts exothermically. Preliminary findings suggest that the heat capacity of the overall system should be carefully considered. The heat of reaction, heat transfer capability of the medium in which it is placed, whether the system is open!closed and under pressure or open to the atmosphere are prime factors for this evaluation. Empirical data suggests that microOA squeezes and downhole treatments are suitable and effective applications of WeIlLock. As such, BP management has given approval to proceed with both microOA squeeze jobs, as well as downhole treatments. Let me know if you need more information. Thanks, Victoria! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepr @alaska.gov] Sent: Thursday, July 16, 2015 1:04 PM To: Sayers, Jessica Cc: Daniel, Ryan Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) What were the results of the investigation of the Well Lock incident on V-101? From: Sayers, Jessica [mailto:Jessica.Sayers@bp.com] Sent: Thursday, July 16, 2015 9:26 AM To: Loepp, Victoria T(DOA) Cc: Lastufka, Joseph N Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) Hi Victoria, Thanks for approving this requested 403. I have decided to add a conservative step to the well treatment for M-16 (this well is a well that has a fully cemented OA and we are using SqueezeCrete to remediate the surface casing leak). After the well is squeezed with SqueezeCrete, a nitrogen cap will be left on the OA. After the SqueezeCrete cures (going to allow 2 weeks) and before the MIT-OA, a WellLock top job will be added. This is for a couple of reasons: 1) we are more confident in the properties of WellLock to cure MicroOAs (it has no yield point because it is a Newtonian fluid) and 2)we have seen that we get the best WeIlLock jobs before MIT'ing with diesel (while WeIlLock will swap with diesel, it does not effectively do this in microannuli space- we therefore try to move forward with WeIlLock jobs without saturating the microOA with diesel). This step will be added to the other recently approved, similar jobs: • A-34A: (PTD185-105, Sundry 315-412) 2 • H-11: (PTD180-068, Sundry 315-413) • R-24: (PTD193-074, Sundry 315-414) Just wondering if you wouldn't mind helping us get navigated in the right direction here, in terms of the existing 403s? Are the already approved 403s ok, as is? If not, would we need to reapply for new 403s or would it be sufficient to update/add to the already approved 403s? Thank you so much for your time! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, June 19, 2015 2:12 PM To: Sayers, Jessica Subject: PBU M-16(PTD 181-086, Sundry 315-378) Jessica, What is the maximum squeeze pressure allowed at the discharge of the pumps for this procedure? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa�alaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 3 rs.„OF / sTHE STATE Alaska Oil and Gas UfALASKAConservation Commission iJIM 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279 1 433 OA, ALAS P Fax 907 276 7542 SCAN�tEn AUL - www.aogcc alaska.gov iJ Jessica Sayers © ��j Well Integrity Engineer S t v BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU M-16 Sundry Number: 315-378 Dear Ms. Sayers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / i))1e.,,-41-1- Cathy P. oerster Chair DATED this day of June, 2015 Encl. STATE OF ALASKA RECEIVED ALAS._ .OIL AND GAS CONSERVATION COMM BION I�N 17 ZO15 • APPLICATION FOR SUNDRY APPROVAL ors 2/ 1ls 20 MC 25.280 f�i OGGC 1 Type of Request. A"1Vt.1 t.r 0 Abandon 0 Plug for Redrill 0 Perforate New Pool ®Repair Well 0 Change Approved Program 0 Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension 0 Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other MicroOA Squeeze . 2. Operator Name 4. Current Well Class 5 Permit To Drill Number BP Exploration(Alaska) Inc. 181-086 • 3 Address: 0 Exploratory ❑Stratigraphic Alaska 99519 6612 ® Development 0 Service P.O. Box 196612,Anchorage, 6. API Number 50.029-20613-00-00 • 7. If perforating. 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU M-16 • Will planned perforations require a Spacing Exception? 0YesNo 9 Property Designator 10.Field/Pool(s): ADL 028257 • Prudhoe Bay/Prudhoe Bay • 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) 11750' • 9319' • 9960' 7941' 9960' None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20"x 30" 29'- 109' 29'- 109' Surface 2704' 13-3/8" 29'-2733' 29'-2671' 4930 2670 Intermediate 10761' 9-5/8" 25'- 10786' 25'-8565' 6870 4760 Production Liner 1437' 7" 10313'- 11750' 8203'-9319' 7240/8160 5410/7020 Liner(Scab Liner) 1400' 5" 10195'- 11595' 8115'-9200' 10140 10490 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade Tubing MD(ft). 10954'- 11356' 8699'-9014' 4-1/2", 12.6# x 5-1/2", 17# 13Cr80 10196' Packers and SSSV Type. 9-5/8"x 4-1/2"Baker S-3 Packer; Packers and SSSV 9927'/7916'; 9-5/8"x 4-1/2"Baker SABL-3 Packer MD(ft)and TVD(ft). 10062'/8016'; 9-5/8"x 5-1/2"TIW HBBP Packer 10143'/8077' 12 Attachments: 13 Well Class after proposed work: 0 Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 14 Estimated Date for 15 Well Status after proposed work: Commencing Operation July 1,2015 • 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative 0 WAG 0 SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact. Jessica Sayers,564-4281 Printed Name: Jessica Sayers Title. Well Integrity Engineer Email. Jessica Sayers@bp com IP Signature: , 017.ne: 564-4281 Date G//�/tc- Commission Use Only �u / Conditions of approval. N. �, Commission so that a rep--ntative may witness Sundry Number: f -3—I s ❑Plug Integrity 0 BOP Test ❑Mechanical Integrity Test 0 Location Clearance Other: Spacing Exception Required? ❑Yes Eg No Subsequent Form Required: /b — 4 D J /1. �/_ - APPROVED BY Approved By: c,(,� - _ COMMISSIONER THE COMMISSION Date. - _ /5 Form 10-403 Revised 10/2/12 Approved application is vali Rint t Irh a of approval Submit In Duplicate V7'l- io//8// BDM .v' '1) 4• /g_CJUN 3 0 1015 . ....._.._.___.....___ by 0 Date: 06-16-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: M-16 SqueezeCrete MicroOA Squeeze Objective This program is intended to guide the execution of a fully cemented OA, low injectivity, surface casing squeeze repair treatment with SqueezeCrete. This well exhibits bubbling in the conductor when on production and returns fluid to the conductor when pressure tested. As such, it is suspected that the parent leak (leak present prior to fully cementing the OA) from surface casing to conductor is the anomaly. SqueezeCrete has been chosen as the repair medium due to both the low injectivity squeeze capability and also the benign reaction conditions of returns that may be present in the conductor(in comparison to WellLock). Well Detail Current Status: Not Operable Previous Test: 07-03-12 MIT-OA w/diesel to 1200 psi, Fail (fluid returns in conductor) 11-13-14 CMIT-TxIA to 3000 psi, Pass Integrity Issues: Fully cemented OA; OA presents bubbling in conductor on production and returns fluid to conductor when pressure tested Last H2S Reading: 04-03-2012 18 ppm Well Operation Detail Fluid Density: 14 ppg Equipment: See rig-up diagram Slurry: SqueezeCrete Relevant History: > 07/13/12: MIT-OA Failed w/ diesel - Fluid to surface in conductor > 07/01/13: Cement in OA @ 24" > 11/09/14: PPPOT-T Passed to 5000 psi > 11/09/14: PPPOT-IC Passed to 3500 psi > 11/11/14: Pull SSSV @ 1982' MD, Set DGLV @ Sta# 2, 3, & 4 > 11/12/14: Set XX Plug @ 9960' MD MIT-T & CMIT-TxIA Passed to 3000 psi 1 of 3 Procedure: 1 D Remove blue goo and ice/material in conductor. 8 D Place, Squeezecrete in OA, until clean, 1:1 SqueezeCrete returns are observed. Take returns to a grounded bucket. 12 D Rig up diaphragm pump, and resume pumping operation by squeezing SqueezeCrete into well. Pump until bump or until SqueezeCrete returns are observed in the conductor. 14 D Let well cure for 7 days. 15 D MIT-OA to 1200 psi with diesel 2 of 3 WEE= C1W Wfl.LFEAD= PkEVOY M-16 SAFEIYN NOR- WELL REQUIRESA SSSV._ ACTUATOR- BAKER C ,"CI4 OME FBG&SCAR L)ft"' (X8,EtEI1= 52.3 I7°-CX3N-XXTOR ._-1. 7 -I f( '':x I B-.5LEV- 2f58' IIS SOP- 2000' 11'YH'SES - 1487' _' - _. 1495' —117-1-3/8-x 9-518-BECP i.6z A ng k = 4/'(#+]450(7 94# (Ck3J@ISSt i Datum#A7= 11I48' I I 1982' H4-112"FES x MP,D=3 813' Dalum ND- 6800'SS 2613' 0-W DV MR..'9-510 C'SG.476.1-80 HYD561. D=8.681' H 1535' r __ __ CAS LFTMAAF:REI_S 9.5/8•FOC- 2700' i''_I ST _ AO WE) DF/ TYPE VLV LATCH F47R1 DATE_ 4 3537 3310 46 1414G IAN RIC 0 11/13/14 I is we'CSC.,77i,L 6G,5D-12.347 H 2733' IM ' 1 FAO 5603 44 M.(' DMY IE 0 11/13114 2 8639 6934 36 Itl8G (MY RK 0 11/13114 —. -- 1 4815 7835 43 NAG F1 WSLV IMP 0 11/13114 Minimum ID= 3.726"to 10098' 4-1/2"HES XN NIPPLE t 5896• 1—(a lrrl£SxI&PU-381r] x --, 9926' 1 In 0.11'X.4 1/7'#404'. k i i<I1.U-3.8r _- I 995D' 14 Vr 2'IlxFi'1) 3813- -'"I 9960' -4-112'XX PLUG(11112/14)I d 112 TBG,1260.13CR/0 VAN TOP, -L. .10023' --{.-.10019' '-14-1/2^x 5-172'XO,D=3.958 0157 NV,ID=3 958' 10032' Ig_JO'x 4 112'LP801E OVCTxi)4lT I I4 trr-mu— fiz'ierC781 ; 29'100 - +----- � 10664' 14ter VIM x141!a e.e15- 1112111110114*x 1# 4' �I-.4DSIM z 4.1/2'FP&S 1 R(R L)=38/5' } 10098' I 14 FES XN NP.IDR 3.725 4-07'16A-1126#_13CR-90VAMTDP. H 10019' I -. 10129' 1--0518-X}1Pr9NCXlovucl101 I 0152bp1 D-a9s8' __ 101128' '—5I/2 0T1SXP D=4-ser I F.vi-FBG Snf- �-i1(0502700M _ 10121' ) 1y ___- 1oi43' _--9-518'x 5-12'F6BPTIN RIR.o=4 T5 I 1014V H7 g1t-IILLO ji 6010400k D-4.71 - 10153' --Ir-54r x 51/r xo p=4 s9a'} I OP OF 5'SCAB LIN}--I 1019-471,,, { 10153' S 112'OT15 X NP D=4-562 5 1/7 MG,178,13CR NSCC, 10196' ` 0232bpi.U-4TVF2- ---- 11 10176'_-5.112'OTISXN NP o=4.455' 10184'ELM 0(08/03/91) 1(18'15 r,1411 1-10314' 1 1 `y 10203' {9-54rX7"IAN HYDLfTHRGo=2 I L 9 576-(Z(3 4/N L.00 N(X:,D i 6 881' } .: 1078.3' • 1 1020T I-{r X 5'xo o=4276' R32FORATI0N SUMMARY I9J LOG SVYS BRCS ON 09129181 ANGLE AT TOP PEPE:38-@ 10964' role.Refer to Rodoc lion CB for hetoreal pert data _J _ SFr I I T6NAL I OPN'SOZ I GATE C I 11123' I—j 7'1441acs1 J08'IT. SFF 141(31-7,5 014 R)(- 114AIP)N[3AiA ` I i 11508' IR7T0(5 lir;CABLMI)J 5'SCAB LAIR 184 NTI3CRT8O - 11594" I INNEN FI4S, 0177 Opt:ID=4776' ctifi 411 7'LAR 264.1-801145. 0.1.91 hpf rt=13 778' 117,50' . it DA IF ,18V BY EDIAIMNIS ' 13AI5 RFV BY CX769.t641S )'I4JA3MDF HAY(Hf 10/06/81 ORIGINALCOMPtE1TON '12R0110 NOIJAro!ADDEDSSSV SAFETY NOTE MIL 1-16 0525100 N9ES RWO 472/12 MIM PJ[GLV(20(4117112) F6(i!No'1810860 12128!08 016 RWO 11/17/14 JMG/JIX1XX RDG'CB V C/a(11/12 13/14) ARF, 50 029 20613 00 04:28109;cei AO () G 614A-TrcoRFIEcrous SEC 1,T1/N RI2E,1607'FNL&606'Fa 09.281.9' PJC f7RAW119G C)I8 T01.e. 11/08/39 PJC DRAWING ODI0 TIONSi BP Exploration(Alaska) 3of3 •toepp, Victoria T (DOA) From: Sayers,Jessica <Jessica.Sayers@bp.com> Sent: Wednesday,June 24,2015 10:32 AM To: Loepp,Victoria T(DOA) Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, thanks for getting back to me. This well has a fully cemented OA, near surface. Unlike the wells we have submitted 403s for with WellLock, this well has fluid returns to the conductor when pressure test-which differentiates the integrity anomaly from a microOA(where pressure is unmanageable online) vs a surface casing leak. I hope I explained that in a sensible manner. More to your point below, we aren't sure what to expect during this operation. When we squeeze the well with SqueezeCrete, we anticipate two scenarios: SqueezeCrete returns to the conductor or the SqueezeCrete will squeeze in the cement and will have an effective squeeze situation. If we run into a squeeze situation, the situation in which we would apply the most pressure, the target squeeze pressure is 2500 psi, with no greater than 3000 psi at any time (to allow for residual pump pressure). However, we did see returns to the conductor during a recent pressure test near 800 psi, so we are anticipating this as the treating pressure in which we are likely to see returns. I hope this makes sense. Thanks, Victoria! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, June 19, 2015 2:12 PM To: Sayers,Jessica Subject: PBU M-16(PTD 181-086, Sundry 315-378) Jessica, What is the maximum squeeze pressure allowed at the discharge of the pumps for this procedure? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 Victoria Loepp at alaska.Qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • OF T I/�%% I—dis STA1 v, 333 West Seventh Av nLe .�� (-ON' :RNC,R SFAX 1 ahNFII Anchorage Alaska 99501 3572 �_iaBtz?/ mair 907 279 1/3? �z swr.0F` SCANNED MAY 2 0 2014 Aaron Ramirez r,,, Well Intervention Engineer j3 l— 0 (/17 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU M-16 Sundry Number: 314-037 Dear Mr. Ramirez: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this�day of January, 2014. Encl. M STATE OF ALASKA tiA !.:,N 1. 2:1,14 • ALASKA OIL AND GAS CONSERVATION COMMISSION iI, 0-7"S. 112 1 II 4-, APPLICATION FOR SUNDRY APPROVALS ' AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well • Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number BP Exploration(Alaska),Inc. Exploratory ❑ Development Q • 181-086-0 • 3.Address: Stratigraphic El Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20613-00-00 • 7.If perforating: 8.Weil Name and Number. What Regulation or Conservation Order govems well spacing in this pool? PBU M-16 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028257 • PRUDHOE BAY, PRUDHOE OIL • 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): 11750 9319 • 11508 9133 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 25-105 25-105 Surface 2708 13-3/8"72#L-80 25-2733 25-2671.06 4930 2670 Intermediate None None None None None None Production 10761 9-5/8"47#L-80 25-10786 25-8565.49 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment II Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(14 See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 5/15/14 Commencing Operations: Oil Q • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 'WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aaron Ramirez Email Aaron.Ramirez@BP.Com Printed Name Aaron Ramirez Title Well Intervention Engineer Signature ---- YO Phone 564-5943 Date 003 A Prepared by Garry Catron 564-4424 NN 14 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number J\ - d2S-1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RBDMS 1fY/AY o 9 ' i7 2014 Other: pho /o G/© eUp-jen rei it Spacing Exception Required? Yes ❑ No R/ Subsequent Form Required: /0 —4 ti 4 I p APPROVED BY /Approved by: , / / C� /y- -__ COMMISSIONER THE COMMISSION Date: /- 2 Z-/ Form 10-403 Revised 10/2012 Ap o i i li 2 months from the date of approval. Submit Form and chments in DupllCate ,\"' vs-P 1 /i /1 �'� °t iAt 411#°//06 v 000 -a OOOOOO (202ce Co co coco °o °o °oUUU J J J J J J C�) ey) M r • F (I) Q 0) CD 0 0 0 00 0 0 a . . : N CD CD f- O OocoO o �ON co r- o 0 0 0 0 0 0 0 0 0 CD f- f- M M Nr Ch N F Cto CO O) f- m O co co Co Co F- O u) CA • O I- O) to to F Nr CD Cr) mp C CMf) CD (D 00) �- O N- a O) O) O) L C10 cc I� Co C1 O _ F_ Cn O N CC) 0 0 01 0 CO • NCO CO CD N N N CO N- co E Lf) M . E N tl) v OCochN (0 (0 cV CO 0 CO r M r- M O co 0FFF Cna " aaa CO 0 2 r r r r N C J • Q 0 vco co U O N p O F N N N N 0 0 2 r r r O c70 O O O O OOIO CoO00 OJO M M OJ w CO J J J *k N X # *k *k ti CO 4t Co N F N N 7 700 CO _X) F ' C co -- a) o) rr rr L' r- O) _O (10Oo a) c co Tr co • O O� O co 0) J N e-- 0 O O CAS— H W U coiD • 0 CLCGCLU O u_ Z Z Z Z W W W Octm m m OZ Z Z 0Jaac�n - I-- H Perforation Attachment ADL0028257 Well Date Perf Code MD Top MD Base TVD Top TVD Base M-16 1/6/92 RPF 10954 10984 8699 8723 M-16 1/3/92 SQZ 10984 10994 8723 8731 M-16 1/3/92 SQZ 10994 11000 8731 8735 M-16 1/3/92 SQZ 11000 11008 8735 8742 M-16 7/27/91 SQZ 11016 11036 8748 8764 M-16 7/27/91 SQZ 11036 11076 8764 8795 M-16 7/27/91 SQZ 11076 11080 8795 8799 M-16 7/27/91 SQZ 11100 11180 8814 8877 M-16 5/23/98 RPF 11341 11356 9002 9014 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN I SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028257 Well Facility Type MD Top Description TVD Top M-16 PACKER 1499 9-5/8" BOT External CSG PKR 1499 M-16 PACKER 9926 4-1/2" Baker S-3 Hydro Set Packer 7916 M-16 PACKER 10061 4-1/2" Baker SABL-3 Packer 8016 M-16 PACKER 10143 5-1/2"TIW HBBP Packer - 8077 TREE_ , OW '----- [WELLHEAD= McEVOY M-16 S r_.f NO T: WELL SCABLNR"QESA SSSV. 'ACTUATOR= BAKER C KB. ELEV= 52.28' 20'CONDUCTOR �_?� I BF ELEV= 27.58' KOP= 2000' 9-5/8"HES - 1487' 1499' H13-3/8"X 9-5/8"BKR ECP Max Angle= 47°@ 4500' CSVENTER Datum MD= 11148' ' ' 1982' -14-1/7'HES X NIP, ID=3.813" Datum TVD= 8800'SS 2613' 9-5/8"DV R(R 9-5/8"CSG,47#,L-80 HY D 563, ID=8.681" H 1535' GAS LIFT MANDRELS 19-5/8"FOC-1 2700' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3597 3310 46 MMG DOME RK 16 01/13/09 f- 13-3/8"CSG,72#, L-80,ID=12.347' H 2733' _ 3 6860 5603 44 MMG DOME RK 16 01/13/09 2 8609 6934 36 MM3 DOME RK 16 01/13/09 1 9815 7835 43 RAW SO RK 24 04/17/12 Minimum ID = 3.725" @ 10098' 4-1/2" HES XN NIPPLE I I 9896' -I4-1/7'HES XNIP, 1D=3.813" S �—f 9926' H9-5/8"X 4-1/2"BKR S-3 PKR,ID=3.87" ' 9960' -14-1/2"HES X NIP,ID=3.813" 4-1/2'TBG,12.6#,13CR-80 VAM TOP, - 10023' 10019' -14-1/2"X 5.1/2"X0, ID=3.958 .0152 bpf,ID=3.958" 1 10032' H9-5/8"X 4-1/2"UNIQUE OVERSHOT 4-12 TBG STUB(12/18108) H 10029' O ' 100554' -14-12"HES X NIP, ID=3.813" Z. E10064' -19-5/8"x 4-1/2"BKR S-3 PKR,ID=3.875" ' 10098' -14-12"HES XN NIP,ID=3.725" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, -1 10019' 10128' H9-5/8"X 5-12"UNIQUE OVERSHOT 0152 bpf,ID=3.958 10128' H5-1/2"OTISX NIP,ID=4.562' 5-1/2"TBG STUB(05/27/00) H 10121' ...-----"--(1 10143' H9-5J8"X 5-12"HBBP TM/R(R,ID=4.75" 10148' -17-5/8"MILLOUT EXTENSION,ID=6.2' 10153' _H7-5/8"X 5-1/2"XO,ID=4.892' TOP OF 5"SCAB LNFL1-1 10194' 10163' -15-1/2"OTIS X NIP,ID=4.567' 5-1/2"TBG, 17#,13CR NSCC, -I 10196' 10176' 15.112'OTIS XN NIP, ID=4.455" .0232 bpf, ID=4.892' 10164'EL M O(08/03/91) TOP OF 7'LNR H 10314' 10203' H9-5/8"X 7"TW HYD LNR HGR,ID=? 9-5/8"CSG,47#, L-80 NSCC, 10=8.681" -{ 10783' 1020T -,T'X 5"XO, ID=4.276" PERFORATION SUMMARY L REF LOG, SWS BHCS ON 09/29/81 ■ ANGLE AT TOP PERF 38°@ 10954' Note.Refer to Roduction D8 for historical perf data a 11123' -17"MARKER JOINT SFF INTERVAL 1 ORWSQZ DATE SEE PAGE 2 FOR PERFORATION DATA ##Y•#•#•#•#Y• 11508' -i PBTD(5-1/2"SCAB LNR) 5"SCAB LNR, 18#,NT13CR-80 - 11594' 4.1.1.1.1.1.1.1.1 FL4S, .0177 bpf,ID=4.276" 111111111111/111' 1/111/1/1111111A 7"LNR,26#,L-80 U4S, 0383 bpf, ID=6.276" -1 11750' • ................01.1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY WIT 10/05/81 ORIGINAL COMPLETION 12/20/10 MB/JMO ADDED SSSV SAFETY NOTE WELL. M-16 05/25/00 N9 ES RWO 04/22/12 MBW PJC GLV C/O(4/17/12) PERMIT No:'1f 12128/08 016 RWO API No 50-029-20613-00 04/28/09 DB/JMD DRLG DRAFT CORRECTIONS SEC 1,T11 N,R12E, 1607'FNL&606'FEL 04/28/09 PJC DRAWING CORRECTIONS 11/08/09 PJC DRAWING CORRECTIONS BP Exploration(Alaska) M-16 1 I j 1 1 1 _ I PERFORATION SUMMARY I I I REF LOG:SWS BRCS ON 09/29/81 ANGLE AT TOP PERF:38°CO 10954' Note Refer to Production DB for historical perf data SPF INTERVAL OPN/SQZ DATE 6" 10954-10984 0 01/06/92 7;4" 10964- 11008 S 01/04/92 4" 11000-11008 S 07/27/91 4" 11016-11036 S 07/27/91 J 6" 11036-11076 S 0727/91 J(—� 4" 11076- 11080 S 07/27/91 4" 11100-11180 S 07/27/91 6" 11341 -11356 0 0523/98 I L n 1 1 .►•o••••.**1 •••00000•1 •••• •••••••• 4484 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/05/81 ORIGINAL COMPLETION 12/20/10 MB/JMD ADDEDSSSV SAFETY NOTE WELL: M-16 05125/00 N9ES RMtO 04/22/12 MBM/PJC GLV C/O(4/17/12) PERMT No:If 12/28/08 016 R NO API No 50-029-20613-00 0428/09 DB/JMD DRLG DRAFT CORRECTIONS SEC 1,T11 N, R12E,1607'FNL&606'FEL 04/28/09 PJC DRAWING CORRECTIONS 11/08/09 PJC DRAWING CORRECTIONS BP Exploration(Alaska) r bp Date: January 2, 2014 To: AOGCC �SubjFrom: Aaron J. Ramirez, Well Intervention Engineer #6 -- Subject: ect: Sundry Notice 10-403 Approval Request BPXA GPB M Pad, Well 16 (M-16) This application for Sundry approval for BPXA Well M-16 is for the inspection and repair of surface casing. Currently, part of the surface casing on this well is exposed to atmosphere, most likely due to corrosion. M-16 has been determined to have a surface casing leak at an unknown depth from surface. BPXA requests approval to inspect and repair the surface casing. .i With approval, inspection and repair of the surface casing will follow the general, outlined procedure below: 1. Secure the well from the reservoir with plug(s), kill weight fluid and BPV. 2. Remove the cellar, wellhouse, tree, flowline and other equipment necessary for repair. 3. Survey existing utilities and other critical infrastructure, including the wellhead. 4. Drive piles to support the wellhead and well support frame. Drive sheet piling for excavation around well. 5. Install wellhead and well support frame. 6. Excavate inside the parameters of the sheet piling, to an estimated bottom depth of 20 feet. 7. Install nitrogen purge equipment for conductor (and OA if needed) so that hot work may be conducted in a safe manner. 8. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC inspector for opportunity to inspect. 9. Install repair patch needed to return the casing to operational integrity. 10.Patch will be inspected for acceptance. 11.Perform MIT-OA. 12.Install external wrap on casing to safeguard against future, potential corrosion. 13.Backfill and compact around well and install cellar. 14.Demobilize wellhead and well support frame. 15.Reinstall tree, flowline and wellhouse. Remove plug(s), BPV and hand well over to well integrity for evaluation. 16.File 10-404 with AOGCC post repair, complete with pictures demonstrating repair. 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg , ; %O1 -? Alaska Oil and Gas Conservation Commission AU M L / 333 West 7 Avenue Q _Q $ K7 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB M -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad M 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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) M -pad Date: 04/14/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal M -01 1690780 50029200420000 Sealed NA NA NA NA NA M -03A 2011470 50029201020100 0.25 NA 0.25 NA 0.85 6/3/2009 M -04 1710230 50029201050000 0 NA 0 NA NA 4/14/2012 M -05A 1970810 50029201940100 0.5 NA 0.5 NA 2.6 6/3/2009 M -06A 1930930 50029203670100 0.25 NA 0.25 NA 0.85 6/3/2009 M -07 1790370 50029203730000 0.25 NA 0.25 NA 0.85 6/3/2009 M -08 1800860 50029204990000 1.75 NA 1.75 NA 10.2 6/24/2009 M -09B 2022200 50029205630200 6.25 NA 6.25 NA 44.2 6/3/2009 M -10 1810290 50029205670000 0.25 NA 0.25 NA 2.6 6/4/2009 M -11 1810570 50029205890000 0.25 NA 0.25 NA 1.7 6/4/2009 M -12A 2001510 50029205930100 0.25 NA 0.25 NA 1.7 6/4/2009 M -13A 2011650 50029205220100 2.75 NA 2.75 NA 17 6/4/2009 M -14 1801090 50029205120000 1 NA 1 NA 5.1 6/4/2009 M -15 1810850 50029206120000 6.75 NA 6.75 NA 55.3 6/4/2009 ", M -16 1810860 50029206130000 0.25 NA 0.25 NA 1.7 6/4/2009 M -17A 2000320 50029206280100 0.5 NA 0.5 NA 2.6 6/3/2009 M -18B 1930540 50029208550200 10 NA 10 NA 73.1 6/24/2009 M -19B 2081980 50029208970200 Sealed NA NA NA NA 4/13/2012 M -20A 1971990 50029209120100 8 NA 8 NA 52.7 6/24/2009 M -21A 1930750 50029209230100 0.5 NA 0.5 NA 3.4 6/24/2009 M -22 1830540 50029209360000 16 NA 16 NA 117.3 6/23/2009 M -23 1830550 50029209370000 0.25 NA 0.25 NA 1.7 6/4/2009 M -24A 2011260 50029209390100 0.25 NA 0.25 NA 0.85 6/24/2009 M -25 1860650 50029215700000 8 NA 8 NA 55.3 6/3/2009 M -26A 1920280 50029220040100 2.75 NA 2.75 NA 18.7 6/3/2009 M -27A 1930860 50029219920100 0.25 NA 0.25 NA 2.6 6/24/2009 M -28 1860740 50029215780000 1 NA 1 NA 4.3 6/3/2009 M -29A 2000990 50029219040100 1 NA 1 NA 4.3 6/3/2009 M -30 1920300 50029222550000 0.5 NA 0.5 NA 3.4 6/3/2009 M -31 1920320 50029222560000 0.5 NA 0.5 NA 3.4 6/4/2009 M -32 , 1920330 50029222570000 0.25 NA 0.25 NA 0.85 6/4/2009 M -33 1941160 50029225040000 20 NA 20 NA 133.45 6/24/2009 M -34 1941330 50029225140000 6.25 NA 6.25 NA 25.5 6/3/2009 M -38A 2011320 50029225190100 21.3 NA 21.3 NA 210.8 11/26/2009 ~%> vt ~ STATE OF ALASKA ~~~~ ~ ~ ?~ ~ ~ ALA OIL AND GAS CONSERVATION CO~ I r ~ ~~ REPORT OF SUNDRY WELL OPERATI~~~ ~' ' Alaska Oil & Gas Goes, ~;or~r~issior°. /~ 1. Operations Performed: ~ttGi'l~?°~~~ ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ~ ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development - ^ Exploratory 181-086 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20613-00-00 - 7. KB Elevation (ft): 52 3' ~ 9. Well Name and Number: M-16 - 8. Property Designation: 10. Field /Pool(s): - ADL 028257 ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11750' - feet true vertical 9319' ' feet Plugs (measured) None Effective depth: measured 11508' feet Junk (measured) None true vertical 9133' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2709' 13-3/8" 2733' 2671' 4930 2670 Intermediate 10762' 9-5/8" 10786' 8565' 6870 4760 Production Liner 1437' 7" 10313' - 11750' 8203' - 9319' 7240 5410 Liner (Scab Liner) 1398' 5" 98' 10140 10490 1 10194' - 11592' 8115' - 9 ~y (~ tt"~ Perforation Depth MD (ft): 10954' - 11356' Perforation Depth TVD (ft): 8699' - 9014' 4-1/2", 12.6# x 5-1/2", 17# 13Cr80/NT13Cr80 10196' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): (2) 9-5/8" x 4-1 /2" Baker'S-3' packers; 9926' & 10064 ; 9-5/8" x5-1/2" TIW'HBBP' packer 10143' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut, pull and dress off tubing stub to -10029'. Cut, pull and dress off 9-5/8" casing to -1530'. Run 9-5/8" tieback, cement w/ 114.8 Bbls Class'G' 645 cu ft / 556 sx . Run new Chrome com letion. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 727 1,368 1,588 1,700 300 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ~ Development ^ Service ^ Exploratory ® 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. t=xempt: Contact David Bjork, 564-5683 308-409 Printed Name T rrie Hubble Title Drillin Technologist ~ Prepared By NameMumber. O, Si nature ~ Phone 564-4628 Date ~ Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 ! ~„~ P .4. t ;; ~C~<< ~~~ Submit Original Only .~--_ M-76, Well History (Pre Rig Workover) Date Summary 12/3/2008 T/I/O=N/A /0/0, Temp=S1. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. No scaffold ladder on well head. PPPOT-T: External check installed. Stung into test port (0+ psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. PPPOT-IC: External check installed. Stung into test port (50 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 12/4/2008 T/I/0=150/0/0 MIT-T PASSED to 1000 psi (RWO prep) Pumped 1 bbl crude down Tbg to reach test pressure for MITT. Tbg lost 20 psi in 1st 15 min and 10 psi in 2nd 15 min for a total pressrue loss of 30 psi in 30 mins. Pumped 12.6 bbls into IA to reach test pressure for MITIA. 12/5/2008 WELL S/I ON ARRIVAL. PULLED "P" PRONG FROM PXN PLUG BODY ~ 10 091' SLM. PULLF_D 4- 1/2" PXN BODY FROM 10 095' SLM. ATTEMPTED TO SET 4 1/2 XXN PLUG. 12/5/2008 CMIT TxIA PASSED to 3500 psi (Pre RWO) Pumped a total of 13 bbls crude down IA to reach test pressure for CMIT TxIA. T/IA lost 20/20 psi in 1st 15 min and 20/10 psi in 2nd 15 min for a total pressure loss of 40/30 psi in 30 mins. Bled T/IA. FWHP's=50/0/0 12/6/2008 UNABLE TO PASS THROUGH SVLN W/ 3.805" G-RING. BRUSH & FLUSH TBG W/ 4.5" BRUSH & 3.5" G-RING TO 10,150' SLM SET 4-1/2" XXN PLUG C«~ 10 097' SLM MIT-T TO 3500 PSI (PASSI. DUMP 2 BAGS OF SLUGGITS ON XXN PLUG C~ 10097' SLM. SET JUNCK CATCHER C~3 10076' SLM. 12/6/2008 T/I/0= 150/0/0 Temp=Sl Assist Slickline. MIT T PASSED to 3500 psi_ (Pre RWO) Pumped 5 bbls methanol & 165 bbls 190°crude down tbg while slickline RIH w/brush. SSL set TTP. Pumped 3.8 bbls of crude to achieve test pressure. T lost 190 psi 1st 15 mins and 90 psi 2nd 15 mins for a total loss of 180 psi in 30 mins. Bled back (-4 bbls) FWHP's=0/vac/20 12/7/2008 INITIAL T/I/0= 700/0/0 JET CUT 4.5" TBG C~3 10.038' MD W/ SLB 3.65" POWER JET CUTTER. GOOD INDICATION OF SUCCESSFUL CUT. CORRELATED TO TBG TALLY DATED 25-MAY-00. INFORMED PAD-OP OF WELL & TREE VLV'S STATUS. FINAL T/I/0= 0/0/0 WELL LEFT S/I, JOB COMPLETE. 12/9/2008 Circ Out (Pre RWO) Pumped 5 bbl neat meth spear & 1112 bbls 3% KCL down tbg to IA down flowline. Freeze protected well w/ 150 bbls 110° diesel. U-tubed T/IA. Freeze protected surface lines and flowline per WOA recipe. Pumped 5 bbls neat meth & 103 bbls crude & 10 bbls diesel.down flowline. Final WHP's 0/0/0 Valve positions SV = S/I, SSV =Open, MV =Open, WV = S/I, IAV =Open, OAV =Open. 12/10/2008 T/I/0= 0/0/0 Set 6-3/8 CIW J bpv# 403 pre Doyon 16. 1-2" ext. used, tagged 0108' no problems. Page 1 of 1 BP EXPLORATION Page 1 of 12. Operations Summary Report Legal Well Name: M-16 Common Well Name: M-16 Spud Date: 9/10/1981 Event Name: WORKOVER Start: 12/10/2008 End: 12/28/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2008 Rig Name: DOYON 16 Rig Number: Date 12/14/2008 From - To ', Hours Task '. Code ~ NPT I Phase Description of Operations 00:00 - 01:00 1.00 MOB P 01:00 - 01:30 0.50 MOB P PRE Bridle up. Clean up in cellar. Prepare to move off of 4-45. PRE PJSM on moving rig with Rig crew, Doyon Toolpusher and BP WSL. Assign people to positions, discuss hazards of moving, remind everyone to wear anti-slip devices and warm clothing when working outside. During inspection of moving system, discover driver controls are not getting any power. RREP PRE Rig Electrician troubleshoot problem with driving controls. PRE Move off of 4-45 and spot rig in center of pad for upcoming work in the Derrick. PRE Hold PJSM with Rig crew, Doyon Toolpusher, BP WSL and CH2MHill Crane operator and crew on removing belly board from derrick. Discuss Critical lift, lifting plan, communication between crane operator and signalman, and hazards of lift. PRE Remove Belly board from Derrick using CH2MHill crane. Derrickman rigging up slings and removing pins from belly board. Floorhand watching from monkey board to ensure crane clears windwalls. Spotter and signalman on rig floor. Clear rig floor of all non-essential personnel while removing belly board. PRE PJSM about laying the derrick over. Discuss hazards, positions of people. Remove derrick pins. Prep rig floor for laying derrick over. Lay Derrick down. PRE Prepare to remove Fast Line Sheave. Secure blocks and remove drilling line from sheave. Hold PJSM on Fast Line Sheave removal with Rig Crew, Doyon Toolpusher and WSL. Discuss hazards, positions of people and good communication. Remove Fast Line Sheave. Remove BOP stack from cellar and install on transport cradle. Install rear booster wheels. PRE Install Fast Line Sheave on shaft. PRE Hold PJSM on Fast Line Sheave Installation with Rig Crew, Doyon Toolpusher and WSL. Review procedures, communication and positions of people during installation. While installing new sheave, rest of rig crew work on addressing items identified in Rig Safety Audit. PRE Inspect derrick while layed down. Take slack out of drilling line and unchain blocks. PRE Function and inspect moving system. Everything looked good. WAIT PRE Wait on Security to begin move to M-16. PRE Move rig from DS 4 to M pad. At 2100-hrs, just past East checkpoint access road. At 2330-hrs, between Lisburne access road and Oxbow Road. PRE Move rig to M-16. At 0200-hrs, rig is at DS-15 access road. At 0300-hrs, rig is at FS #3. At 0400-hrs, rig is at Skid 50. 0800-hrs, BOC. 1000-hrs, Price Pad. 1200-hours, J-pad, parked and waiting on 9ES to get to R-pad access road. Arrive on M-pad at 1430-hours. PRE Toolpusher checked wind speed at 35-MPH constant velocity at 1430-hours. Decided to lay down rig mats, then move rig over well, but weather began to worsen with only the Herculite and 4-mats laid down. WAIT PRE Decided to shut-down all operations with visibility of less than 5' at the rig. The crew brought extra food with them when they started their tour. The Rig Crew head count: Andrew Honea, 01:30 - 02:00 0.50 MOB N 02:00 - 02:30 0.50 MOB P 02:30 - 03:00 I 0.501 MOB I P 03:00 - 04:30 I 1.50 I MOB I P 04:30 - 06:00 ~ 1.50 ~ MOB ~ P 06:00 - 12:00 6.00 MOB ~ P 12:00 - 12:30 0.50 MOB P 12:30 - 16:30 4.00 MOB P 16:30 - 17:00 0.50 ~ MOB ~ P 17:00 - 17:30 0.50 MOB P 17:30 - 18:30 1.00 MOB N 18:30 - 00:00 5.50 MOB P 112/15/2008 ~ 00:00 - 14:30 ~ 14.50 ~ MOB ~ P 14:30 - 16:30 I 2.001 RIGU I P 16:30 - 00:00 I 7.501 RIGU I N Printetl: 1/5/2009 11:18:00 AM ~ i BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: M-16 Common Well Name: M-16 Spud Date: 9/10/1981 Event Name: WORKOVER Start: 12/10/2008 End: 12/28/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2008 Rig Name: DOYON 16 Rig Number: Date. From - To Hours ' Task Code NPT Phase Description of Operations -- 12/15/2008 16:30 - 00:00 7.50 RIGU N WAIT PRE Toby Pickworth, Isaac Reed, Seth Burson, Mike Kysar, Doug Royal, Jesse Charley, Orville Williams, Don Petruska, Leon Nollner. Roustabout Harlan Sweetsir had started for the rig camp before the storm and was in a convoy as of 1700-hours. Harlan Sweetsir arrived at camp at 1830-hrs. Phase 3 called at 1900-hrs. 12/16/2008 00:00 - 02:00 2.00 RIGU N WAIT PRE iti .Pickworth crew and Doyon Toolpusher Honea are on the rig. Moses crew on standby in camp. 02:00 - 10:00 8.00 RIGU N WAIT PRE Weather downgraded to Phase 2 on all roads, but remains Phase 2, Level 3 on pads. Call IMT and get permission to do crew change using the rig loader as an escort off of M-pad. Convoy to rig. Moses crew and Toolpusher Glenn Hermann on location at M-pad at 0345-hrs. Pickworth crew and Toolpusher Honea back at rig camp at 0430-hrs. Work will not commence on the rig until pads are downgraded to Phase 2, Level 2. 10:00 - 13:00 3.00 RIGU P PRE PJSM with crew, Tourpusher, and WSL to resume R/U for M-16. Complete laying down the rig mats, then move rig up onto mats, observed by Pad Operator. Line up, centered over well. Rig up in cellar: double annulus valves, circulating manifold. Conduct Derrick inspection for snow and ice build-up before raising derrick. 13:00 - 16:00 3.00 RIGU P PRE PJSM to raise Derrick. Raise Derrick and install Derrick pins. Check Fastline Sheave after raising Derrick. R/U Rig Floor and Top Drive. Spot Mud Pump #2 module and auxilliary generator module. R/D bridle lines. 16:00 - 17:00 1.00 RIGU P PRE Rig up circulation manifold. 17:00 - 18:00 1.00 KILL P DECOMP Pick u Lubricator. Pressure test at 500 si. Pull BPV. Lay down same. TP = 0 psi, IAP = 0 psi, OAP = 0 psi. 18:00 - 19:00 1.00 KILL P DECOMP Rig up lines to tree. Pressure test lines at 3,500 psi. Good test. Test Mud Pump #2 at 3,500 psi. 19:00 - 21:30 2.50 KILL P DECOMP PJSM with all to discuss Well KIII operations. Pump a 20 bbl Hi•Vis Pill. followed by 732 bbls of hot Sea Water (8.5 Ib/gal) at 7.0 bpm/650 psi. (Note: took 8.5 bbls to catch returns). Saw no return in celler 21:30 - 00:00 2.50 KILL P DECOMP Monitor Well. Set TWCV. Test from above at 3 to t from below at 1 000 ' 12/17/2008 00:00 - 00:30 0.50 WHSUR P DECOMP PJSM to Nipple down tree. 00:30 - 06:00 5.50 WHSUR P DECOMP Blow down lines. Nipple down the Production Tree and Adaptor Flange. 06:00 - 06:30 0.50 WHSUR P DECOMP Inspect LDSs and find two tight LDSs; work them loose. Inspect hanger threads, good condition. Run in 7'° NSCC XO for 9-turns. 06:30 - 10:00 3.50 BOPSU P DECOMP N/U BOPE and support cradle. Replace lower air boot. Toolpusher supervising Rig Camp move from Mukluk Yard to Price Pad commencing at 0900-hours. 10:00 - 16:30 6.50 BOPSU P DECOMP PJSM with crew and WSL. Pressure Test BOPE to 250-psi low, 3500-psi high; use 4" and 4-1/2" test joints. Test the Hydril with only the 4" test joint. Each test chart-recorded for 5-minutes. Test with the 4-1/2" test joint a multiplicity of times. 1630-hours, decide to change the VBRs from 3-1/2" x 6" to 2-7/8" x 5". 16:30 - 20:00 3.50 BOPSU P DECOMP Install 2 7/8" x 5" Pine Rams. Test with 4 1/2" and 4" test joints Printed: 1/5/2009 11:18:00 AM BP EXPLORATION Page 3 of 12 Operations Summary Report Legal Well Name: M-16 Common Well Name: M-16 Spud Date: 9/10/1981 Event Name: WORKOVER Start: 12/10/2008 End: 12/28/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours I Task Code NPT Phase ' Description of Operations 12/17/2008 16:30 - 20:00 3.50 BOPSU P DECOMP at 250/3500 psi. Good test. Lay down test joints. Perform Koomey test. 20:00 - 21:00 1.00 WHSUR P DECOMP t st. Pull TWCV. Lay down same. 21:00 - 21:30 0.50 WHSUR P DECOMP Make up Landing Joint. BOLDS. Pull Tubing Hanger to floor at 152K with no problems. 21:30 - 22:30 1.00 PULL P DECOMP Circulate well at 15 bpm/940 psi. Total bbls pumped = 546. No fluid returns in cellar. No fluid loss. Monitor Well. Well remains static. 22:30 - 00:00 1.50 PULL P DECOMP Lay down Tubing Hanger and Pup Joints. Begin to single down 4 1/2" Completion. 12/18/2008 00:00 - 07:00 7.00 PULL P DECOMP Continue to sin le down 4-1/2" Com letion in Pipe Shed. All 234 full joints, 5-GLMs and the 3.88' cutoff joint with 5" flare recovered at 0700-hrs. The flare is as smooth a cut as we've ever seen for a jet cut. 07:00 - 08:00 1.00 PULL P DECOMP Clear and clean Rig Floor. Install wear ring. PT hardline to flowback tank to 2000-psi; no leaks in line; blowdown the hardline to the flowback tank. 08:00 - 09:30 1.50 CLEAN P DECOMP Bring dress-off BHA to Rig Floor and check all components. Find that the ball/rod to open the Pump Out sub won't pass through the XO that had been screwed into the floor valve. R&R the XO and recheck with ball/rod, OK. 09:30 - 13:00 3.50 CLEAN P DECOMP P/U M/U Dress-off BHA: 5-9/16" Shoe (to pass over the 4.957" collar at 6' from stub), Washpipe Extension, 4-1/2" Dressing Mill, 9-5/8" Casing Scraper, Bumper sub, Oil Jar, and RIH on 9-ea 6-1/4" DCs from Pipe Shed. DCs packed with snow from outside storage. 13:00 - 18:00 5.00 CLEAN P DECOMP RIH Dress-off BHA on DP from Pipe Shed. 30-joints RIH at 1400-hours. 75-jts ~ 1520-hrs. 150-jts at 1720-hrs. 18:00 - 21:15 3.25 CLEAN P DECOMP Continue to single in with BHA #1 ancj 4" Drill Pipe from Pipe Shed. 21:15 - 22:00 0.75 CLEAN P DECOMP PUW = 204K, SOW = 147K, RTW = 170K, PR = 5.4 bpm, PP = 575 psi, RPMs = 80. Tag top of 4 1/2" iet cut stump at 10 029. 'and i Dr ss ff Swallow down to 10,036.25'. 22:00 - 23:00 1.00 CLEAN P DECOMP Pump a 20 bbl High-Vis sweep. Chase sweep back t surface at 11.5 bpm/2360 psi. Work Casing Scraper across expected Packer setting area (-9,948') while circulating. Total bbls pumped = 702 + sweep. No fluid returns in cellar. 23:00 - 00:00 1.00 CLEAN P DECOMP Monitor Well static. Blow down lines. Trip out with 4" Drill Pipe and BHA #1. Stop with 10 stands out. Driller and WSL flow check hole. Well remains static. Continue TOH. 12/19/2008 00:00 - 03:30 3.50 CLEAN P DECOMP Finish tripping out with BHA #1 standing back 4" Drill Pipe in Derrick. 03:30 - 04:30 1.00 CLEAN P DECOMP Stand back 6 1/8" Drill Collars. Lay down BHA #1. Saw normal wear on inner MIII. Clear and clean Fioor. 04:30 - 06:30 2.00 EVAL P DECOMP Spot SWS E-Line Unit. PJSM. Rig up SWS logging equipment. 06:30 - 08:30 2.00 EVAL P DECOMP RIH with USIT and CCL logging tools. Make two deep passes from 3050' to 2700' to ensure tool calibration. Make full pass from 3000' to surface in Cement and Corrosion Mode. See a top of cement at about 2000' and also a section at -1800' to 1550' that appears to have some cement behind the 9-5/8" casing. Schlumberger transmit data to town at 0830-hrs for Nnmea: u5izuua 17aif:UU HM BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: M-16 Common Well Name: M-16 Spud Date: 9/10/1981 Event Name: WORKOVER Start: 12/10/2008 End: 12/28/2008 Contractor Name: DOYON DRILLI NG INC. Rig Release: 12/28/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/19/2008 06:30 - 08:30 2.00 EVAL P DECOMP evaluation. 08:30 - 09:30 1.00 EVAL P DECOMP PJSM. R/D Schlumberger equipment and send out through Pipe Shed and Beavalator. ADW engineers agreed to 1530' as the cut depth. This will also require 9.8-oog brine for all, o erations throu hand includin the cementin o erations. Start dumping seawater out of pits into cuttings tank. Order 3-truckloads of hot (110F to 120F) 9.8-ppg brine. 09:30 - 10:30 1.00 CLEAN P DECOMP Clear and clean Rig Floor, service Top Drive, inspect Crown Sheave. 10:30 - 12:00 1.50 DHB P DECOMP P/ H - ..off Pipe Skate and prepare to RIH and Set Center of Element at 1671'. top of the tool is at 1 FF,R', 12:00 - 13:00 1.00 DHB P DECOMP Pressure test casing to 3500-osi. recorded for 10-minutes. for 13:00 - 15:30 2.50 CLEAN P DECOMP Dump 44-sacks of 20-40 River Sand down DP using sand hopper on top of DP. Circulate sand down to top of RBP, 1-BPM at 30-psi. 15:30 - 16:00 0.50 CLEAN P DECOMP Wait for 1/2-hour then RIH to tag top of sand on RBP at 1611'. 16:00 - 18:00 2.00 CLEAN P DECOMP Wait on 9.8-ppg brine to be made up and delivered from MI. 18:00 - 21:30 3.50 CLEAN P DECOMP Continue to wait on 9.8-ppg brine. 21:30 - 22:30 1.00 CLEAN P DECOMP Take on first load of hot 9.8-ppg Brine. Displace well bore from -1,570' with 9,8-ppg brine at 7.0 bpm/240 psi. 22:30 - 23:00 0.50 CLEAN P DECOMP Trip out with 4" Drill Pipe and Halco Running Tool. Lay down Running Tool 23:00 - 23:30 0.50 CLEAN P DECOMP Make up BHA #2 as follows: Baker MS Gutter. XO, Stablizer, Pump-Out-Sub, XO, 1 Jt Drill Pipe. (Second load of Hot Brine on loacation). 23:30 - 00:00 0.50 CLEAN P DECOMP Trip in with BHA #2 and Drill Pipe from Derrick. 12/20/2008 00:00 - 00:45 0.75 CLEAN P DECOMP Continue to trip in with Baker MS Cutter on 4" Drill Plpe. 00:45 - 01:15 0.50 CLEAN P DECOMP locate 9 5/8" Casing collars at 1,553' and 1,515'. Park MS Cutter with blades at 1 530'. 01:15 - 08:00 6.75 CLEAN P DECOMP Pressure test line from OA to Arctic Pack recovery tank. Circulate hot 9.8-ppg Brine at 2.0 bpm while waiting for final load of Hot Brine. Spot Lil' Red. Pre-heat Diesel. Final truck load of 9.8-ppg Brine on location at 0730-hrs. 08:00 - 08:30 0.50 CLEAN P DECOMP PJSM with MI Engineer, Baker Fishing Techs, Lil Red crew, CH2MHill Drivers, Rig Crew, Toolpusher, and WSL to discuss the play-by-play for the casing cut and the Arctic Pack cleanout. Everyone participated and we also discussed the duties of each person as well as the PPE required inside and outside the rig during the entire process. 08:30 - 09:00 0.50 CLEAN P DECOMP PT the Lil Red lines to 2500-psi and find a leaking Halliburton valve on the Cement riser. Replace valve and retest Lil Red lines to 2500-psi for good test. 09:00 - 09:30 0.50 FISH P DECOMP Get parameters for Multi-String cutting: 100-RPM, 5.5-BPM, 600-psi, 3-4K-Ib-tt free torque, 65K hanging weight. Cutter engage at 0911-hours, increase rate to 6.5-BPM, 890-psi. Cutters through casing at 0921-hours. See returns to the Flow-back Tank outside. Stop cutting operations, Shut-in OA and take returns to pits. 09:30 - 10:30 1.00 FISH P DECOMP Open to Lil Red and pump 18-Bbls of 100E diesel at 1.5-BPM, 600-psi down DP. Close Hydril and open OA to outside choke manifold and Flowback tank. Pump remainder of diesel (57-Bbls) down DP and into OA, 1.5-BPM, 600-psi. Shut down Printed: 1/5/2009 11:18:00 AM BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Name: M-16 Common Well Name: M-16 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To I, Hours Task ' Code ~~ NPT 12/20/2008 109:30 - 10:30 I 1.001 FISH I P 10:30 - 12:30 2.00 FISH P 12:30 - 14:30 2.00 FISH P 14:30 - 15:30 ~ 1.00 ~ FISH ~ P 15:30 - 16:00 0.50 FISH P 16:00 - 17:00 1.00 FISH P 17:00 - 18:00 1.00 FISH P 18:00 - 18:30 0.50 FISH P 18:30 - 19:00 0.50 FISH P 19:00 - 20:00 1.00 FISH P 20:00 - 00:00 I 4.00 I PULL I P 12/21/2008 100:00-01:45 01:45 - 03:30 03:30 - 04:45 1.75 PULL P 1.75 PULL P 1.25 FISH P 04:45 - 06:00 06:00 - 07:00 07:00 - 08:00 1.25 FISH P 1.00 FISH P 1.00 FISH P 08:00 - 09:00 1.00 FISH P 09:00 - 10:30 1.50 FISH P 10:30 - 11:00 0.50 FISH P 11:00 - 12:30 1.50 CASE P 12:30 - 13:00 0.50 CASE P Spud Date: 9/10/1981 Start: 12/10/2008 End: 12/28/2008 Rig Release: 12/28/2008 Rig Number: Phase ~ Description of Operations DECOMP Lil Red. S/1 OA and DP. MI Engineer took samples from the flowline between the OA valves and the outside choke manifold during the diesel displacement and got thick Arctic Pack slurry. DECOMP Let -75-Bbls of 100E diesel soak in the 89-Bbl OA. DECOMP Circulate 40-Bbls Safe-Surf-O sweep mixed with hot freshwater at a pump rate of 2-BPM and 30-psi through the 9-5/8" x 13-5/8" annulus and out to the Flowback tank, get diesel and Arctic Pack in samples. Continue until Sweep is around and into Flowback tank. Circulate 9.8-ppg brine through OA, beginning at 5-BPM, 500-psi, then increase to 8.5-BPM, 1800-psi. Returns samples to Flowback tank appear to be clean 9.8- brine. Stop circulation with 360-Bbls pumped and very clean returns to Flowback Tank. Close OA and opn Hydril and circulate bottoms Up to move any diesel out of the DP x 9-5/8" annulus. DECOMP POH and S/B 17-stands of DP in Derrick. DECOMP B/O and UD Multi-String Cutter BHA. Pull Wear Bushing. DECOMP Make-up BHA #3: 9 5/8" Casing Spear. Plant Spear. BOLDS DECOMP Pull 9 5/8" Casing Hanger free at 130K. String weight 105K. DECOMP Circulate bottoms up at 10.0 bpm/210 psi. DECOMP Pull Casing Hanger to floor. Break out, lay down Spear and landing joint. Lay down Casing Hanger and Pup Joints. DECOMP Rig up Casing Tongs. Single down 9 5/8" Casing in Pipe Shed. (Number and tally). Have 27 joints laid down at midnight. Average break-out torque = -45K fUlbs. DECOMP Continue to lay down 9 5/8" Casing in Pipe Shed. Recovered. DECOMP DECOMP Clear and clean floor. Break down Casing Spear from BHA #3. Set Wear Bushing. Clear Pipe Shed. Load next BHA. DECOMP P.isti^ Make uo BHA #4 9 5/8" Dress Oss Assy as follows: Dress Off Shoe, Washpipe Extention, Dress Off Mill, Washpipe Boot Basket, XO, 13 3/8" Casing Scraper, XO, Float Sub, Bumper Sub, XO, 3 ea 6 1/8" Drill Collars, XO, XO. DECOMP Trip in with BHA #4 and 4" Drill Pipe from Pipe Shed. DECOMP Obtain parameters: Up wt 70K-Ibs, Dn wt, 72K-Ibs, Rot wt 71 K-Ibs, Free Torque 3-4K-Ib-ft, 4-BPM ~ 80-psi. Slowly RIH and tap 9-5/8" stub at 1529' DPM. Dress-off stab to 1524.5' DPM with 60-RPM, 5K-Ib-ft, 5K-Ibs WOB. P/U of stub, stop rotating and slowly RIH to easily swallow the stub, stacking -5K-Ibs. P/U and get ready to circulate. DECOMP Circulate a 40-Bbls Safe-Surf-O sweep, 100F, 8.5-BPM at 300-psi. Chase all the way around with 9.8-ppg brine from pits. Get globs of Arctic Pack over the shakers with the lead fluid, then it cleans u . Circulate a 20-Bbls HiVis sweep, chased all the way around with 9.8-ppg brine from pits, 11-BPM at 500-psi. Get a few small globs of Arctic Pack across the Shakers and some metal shavings on the ditch magnets. DECOMP POH and S/B DP and DCs in Derrick. Monitor well, well dead. DECOMP B/O and UD BHA. Pull Wear Ring. DECOMP Clear and clean Rig Floor. TIE61 R/U 9-5/8" casing handling equipment. TIE61 PJSM with Halliburton Techs, Baker Techs, Rig Crew, Toolpusher, and WSL to cover P/U and RIH the 9-5/8" Casing. Printed: 1/5/2009 11:78:00 AM • C~ BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: M-16 Common Well Name: M-16 Spud Date: 9/10/1981 Event Name: WORKOVER Start: 12/10/2008 End: 12/28/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operatjons 12/21/2008 13:00 - 15:00 2.00 CASE P TIEB1 P/U Baker/Bowen Casing Patch and M/U to Baker ECP Assembly, BakerLok and torque to 11,500-Ib-ft. P/U and M/U crossover pup joint to the ES Cementer, BakerLok and attempt to torque, but the pin end of the cementer sloped turning. Back out slightly and retry. Box is made up, but pin end M/U 1/2 way. Back out the cementer from the pin end and steam clean box of the ECP aassembly as well as the pin end of the cementer. 15:00 - 18:00 3.00 CASE P TIE61 Continue RIH with 9-5/8" 47# L-80 H dril 563 Casin .Use Jet Lube Seal Guard thread dope and torque all connections to 15,800-Ib-ft. These 13-3/8" tongs would not consistently M/U to the optimum recommended torque of 15,800-Ib-ft. Change out ~ to 10-3/4" tongs which are new tongs. 18:00 - 18:30 0.50 CASE P TIEB1 P/U Wt = 107,000 Ibs ; S/O Wt = 107,000 Ibs Tag top of 9 5/8" Casin Stum at 1 532'.. Space out. Set 40K down and swallow stump (3'). Pull up too 250K to enguage slips. Slack of to 207K (100K over string weight). 18:30 - 21:30 3.00 CASE P TIEB1 Install Wiper Plug in Cement Head. Install Cement Head. Rig up chart recorder. Test Cement Head and Casina at 1.000 nsi x 10 min .Bum ressure u to 1 200 i x 2 m'n t begin inflatino Backer ECP. Bump pressure to 1,400 psi x 2 minutes. Bring pressure to 1,800 psi. Did not see ECP shear and inflate. Bump to 2,000 psi. Still no joy. Discuss plan forward with Anch Eng. Continue with cementing program. Attem tone more time to shear ECP t 2 20 i. N Shear o en Halco Cementer at 2 800 si. Circulate well with 9.8-ppg Brine at 5.0 bpm/270 psi. Full returns with an initial return temp of 61 degs F. Continue to circulate well to bring temp up. 21:30 - 21:45 0.25 CASE P TIE61 Pre-job safety and operation meeting with All. 21:45 - 22:30 0.75 CASE P TIEB1 Continue to circulate well. Temp has stabilized at 78 degs F. End circulating with rig pump. 22:30 - 00:00 1.50 CEMT P TIEB1 Pressure test SWS lines at 4,500 psi. Good test. SWS batch up cement. Start cement down hole. Initial rate 3.0 bpm/330 psi, 16.0-ppg, WHP = 140 psi. At 25 bbls pumped 5.0 bpm/810 psi, 15.9-ppg, WHP = 300 psi. At 50 bbls pumped 5.0 bpm/740 psi, 15.8-ppg, WHP = 270 psi. At 75 bbls pumped 5.2 bpm/778 psi, 15.9-ppg, WHP = 285 psi. At 100 bbls pumped 5.1bpm/730 psi, 15.9 ppg, WHP = 280. Reduce rate. At 110 bbls pumped 1.5 bpm/100 psi, 16.0-ppg, WHP = 75 psi. Final cement pumped 114.8 bbls (119.8 bbls on mechanical counter . Shut d w .Plug gone. SWS pump 5 bbls to chase plug. End SWS. Bring rig pump on line to displace cement and bump plug with 9.8-ppg Brine. Displace at 5.0 bpm/230 psi. Reduce rate 4.0 bpm/1000 psi. Reduce rate to 2.0 bpm/700 psi. Saw aood cement returns with 4 I Bumped plug (23:34 hrs) at 1025 strokes (103.3 bbls). Calculated displacement to bump plug (with Rig Pump) was 104 bbls of Brine (total displacement 109 bbls: 5 FW 104 Brine). Closed plug with 1350 si. Bring pressure up to 1,800 psi and hold for 5 minutes. Release pressure and check float. No flow back. Blow down lines. Rig down SWS equipment. Begin WOC at Printed: 1/5/2009 11:1 tf:UU AM i BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: M-16 Common Well Name: M-16 Spud Date: 9/10/1981 Event Name: WORKOVER Start: 12/10/2008 End: 12/28/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2008 Rig Name: DOYON 16 Rig Number: I Date From - To Hours Task Code NPT Phase Description of Operations 12/21/2008 22:30 - 00:00 1.50 CEMT P TIEB1 23:34 hrs. Fstimata 14 hhls of,~~nd r.Pment ret~rnad. Est 100 bbls behind pipe. Calculated volume from Cementer to surface = 86 bbls. No returns in cellar during iob. However, near the end of the job, it was noticed that a small steady stream of bubbles was coming from the threaded nipple that is screwed into the Conductor Pipe. 12/22/2008 00:00 - 00:30 0.50 CEMT P TIEBi Circulate a citric pill across BOP Stack through choke mainiford and line to flowback tank. Blow down choke and line to flowback tank. 00:30 - 04:00 3.50 CEMT P TIEB1 Nipple down and lift BOP Stack. Saw cement just below the IA Valve. Set Emergency Slips with 100k overpull on casing._ RILDS. Cut and dress off Casing with WACHS Cutter per Cameron Serviceman. 04:00 - 05:00 1.00 CEMT P TIE61 Continue with Rig down. Lay down 9 5/8" Casing stub (16.58'). Nipple BOP stack back up (with 4 bolts). Rig down Casing handling equipment. Lay down long bails. Pick up short bails. Pick up "Johnny Wacker"and clean out inside of BOP Stack. 05:00 - 08:30 3.50 WHSUR P TIEB1 Nipple down Tubing Spool. Prep to install 9 5/8" Pack-off. N/U new tubing spool, install pack-off and test to 3800-psi for 30-minutes. 08:30 - 10:30 2.00 WHSUR P TIEB1 N/U Tubing Spool. 10:30 - 12:00 1.50 BOPSU P TIEB1 P/T BOP break to 250-psi low, 3,500- si hi h. AOGCC did not return aknowledgement of planned BOP breaks pressure test. Change out test plug and retest for solid, straight-line test. 12:00 - 13:00 1.00 CASE P TIE61 M/U cement track drill-out BHA: 8-1/2" Bit, 2-ea Boot Baskets, Float Sub. RIH on 3-stands of DCs from Derrick. 13:00 - 16:00 3.00 CASE P TIEB1 RIH Drill-out BHA on 3-stands of DCs and DP from Derrick. Hang off at -1400' and wait for UCA test to achieve 1000-psi compressive strength before drilling out the cement track starting at the ES Cementer at 1484'. 16:00 - 18:30 2.50 DRILL P TIEB1 Get parameters:Up wt 75K-Ibs, Dn wt 80K-Ibs, Rot wt 80K-Ibs, 80-RPM, 6-BPM, 140-psi. Stop rotating and RIH to soft tag at 1483'. P/U and start rotating at 80-RPM and RIH to control drill the cement track. Start seeing fine rubber shavings and cement over shakers. Drilled through shoe Track. Continue down to top of sand at 1,616'. Dry drill on top of sand with 3K on bit. 18:30 - 19:00 0.50 DRILL P TIEB1 Pump a 20 bbl Hi-Vis sweep and chase to surface. Saw cement cuttings, rubber pieces, and some sand in the returns. 19:00 - 20:00 1.00 DRILL P TIEB1 Monitor well. Blow down lines. POOH. 20:00 - 21:00 1.00 DRILL P TIEB1 Lay down BHA #5. Clean Junk Baskets. Recovered a small amount of cement debris and bits of rubber. 21:00 - 22:00 1.00 EVAL P TIEB1 Rig up test equipment Test 9 5/8" Casina at 3 500 osi x 30 minutes. Monitor o en OA and Conductor Flutes. No flow. Good test. Ri down test a ui ment. 22:00 - 22:30 0.50 FISH P DECOMP Make u BHA #6 RCJB as follows: 8 1/2" RCJB, 9 5/8" Casing Scraper, Bit Sub, PUmp-Out Sub, XO. 22:30 - 23:45 1.25 FISH P DECOMP Trip in with BHA #6 and 4" Drill Pipe from Derrick. Work RCJB and wash sand from 1,616' down to 1,632'. 23:45 - 00:00 0.25 FISH P DECOMP Pull back above tagged sand top. Pump 20 bbl sweep. 12/23/2008 00:00 - 00:30 0.50 FISH P DECOMP Chase sweep back to surface at 7.5 bpm/1,725 psi. Recovered much sand and a few bits of rubber. 00:30 - 01:30 1.00 FISH P DECOMP Trip out with 4" Drill Pipe and BHA #6. Nnntea: v5izoua n:~a:uuHnn • BP EXPLORATION Page 8 of 12 Operations Summary Report Legal Well Name: M-16 Common Well Name: M-16 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To II Hours Task Code 12/23/2008 101:30 - 02:00 0.501 FISH ~ P 02:00 - 03:00 I 1.001 FISH I P 03:00 - 03:45 I 0.751 FISH I P 03:45 - 04:30 0.75 FISH P 04:30 - 04:45 0.25 FISH P 04:45 - 05:00 0.25 FISH P 05:00 - 06:30 1.50 FISH P 06:30 - 09:15 09:15 - 09:30 09:30 - 10:30 2.75 FISH P 0.25 FISH P 1.00 FISH P 10:30 - 12:30 12:30 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 15:30 15:30 - 16:30 16:30 - 17:00 17:00 - 18:00 18:00 - 22:00 22:00 - 22:45 22:45 - 23:15 23:15 - 23:30 23:30 - 00:00 12/24/2008 00:00 - 00:15 2.00 FISH N 0.50 FISH N 1.00 FISH N 0.50 FISH N 1.00 FISH N 1.00 FISH N 0.50 FISH N 1.00 FISH N 4.00 FISH N 0.75 FISH N 0.50 FISH N 0.251 FISH I N 0.50 FISH N 0.25 FISH N Spud Date: 9/10/1981 Start: 12/10/2008 End: 12/28/2008 Rig Release: 12/28/2008 Rig Number: NPT Phase Description of Operations DECOMP Break out RCJB. Recovered lar a feces of the Landin Rin (95% complete), one large piece of Hydril element rubber, several rubber pieces of the landing plug, the three brass pins, and some small pieces of wire. No sign of the lower sleeve, yet .Make up RCJB for run #2 (take out Casing Scraper. Had problems getting it through the well head for run #2. Most likely due to sand behind the pads). DECOMP Trip in with BHA #7 RCJB #2 and 4" Drill Pipe from Derrick. Tag top of sand at 1,632', right where expected. Work and wash RCJB from 1,632' down to 1,652'. DECOMP Pull back above tagged sand top. Pump 20 bbl Hi-Vis sweep. Chase back to surface at 7.5 bpm/1,800 psi. Recovered much sand again. DECOMP Trip out with 4" Drill Pipe and BHA #7. DECOMP Break out RCJB. RCJB clean. Lay down BHA. DECOMP Make u Halco Retrievin Tool. DECOMP Trip in with Halco Retrieving Tool and 4" Drill Pipe from Derrick. Called AOGCC with 24-hr update for weekly BOPE test for 24 December. Jeff Jones, AOGCC Inspector, returned the call and waived State's right to witness the weekly BOPE test. DECOMP Circulate sand off the RBP and wait for pit cleanout to changeout the brine to seawater. DECOMP PJSM to displace 9.8-ppg brine from well with hot seawater down to the RBP at 1671'. DECOMP Wash down to 1,163' at 6.5 bpm/200 psi. Pump a 20 bbl Hi-Vis sweep. Displace sweep and 9.81b/gal Brine back to surface with clean Sea Water. DPRB DECOMP Attem t to latch 9 5/8" Halco RBP. Top of tool at 1,661' (center element at 1,671'). Retrieving Tool keeps jumping off. DPRB DECOMP Trip out with 4" Drill Pipe and Retrieving Tool. Break out tool and inspect. Saw no indication of any problems with tool. DPRB DECOMP Pick up Baker RCJB again. DPRB DECOMP Trip in with RCJB and 4" Drill Pipe. DPRB DECOMP Wash over top of RBP at 7.0 bpm/2810 psi. Pump a 20 bbl Hi-Vis sweep and chase back to surface at 7.0 bpm2825 psi. DPRB DECOMP Blow down Top Drive and lines. Trip out with 4" Drill Pipe and RCJB. DPRB DECOMP Break out RCJB. Clean. Nothing recovered. DPRB DECOMP Pick up Halco Retrieving Tool and trip in with 4" drill pipe to top of RBP at 1,661'. DPRB DECOMP Continue to attempt get a solid catch on RBP. Circulate. Reverse circulate. Discuss plan forward with Anch Eng and Day WSL. Continue to attempt to make a solid catch. No-joy. DPRB DECOMP Trip out with 4" Drill Plpe and Halco Retrieving Tool. DPRB DECOMP Break out Retrieving Tool. Inspect tool. Marks in the "J" slot indicate that the tool is getting over the control arm of the RBP. However, it lacks about 1 inch of allowing the tool to completly "J" to make the catch so the RBP can be released. Clear floor DPRB DECOMP Make u BHA #8, Baker Overshot as follows: Bowen Series 70 Overshot (3.5" grapple), XO, Bumper Sub, Pump-Out Sub, XO. DPRB DECOMP Trip in with BHA #8 and 4" Drill Pipe from Derrick. DPRB DECOMP Finish trip in. PUW = 68K. SOW =68K. PflntBtl: 1/5/2UUy 11:1 tS:UU AM • BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Name: M-16 Common Well Name: M-16 Spud Date: 9/10/1981 Event Name: WORKOVER Start: 12/10/2008 End: 12/28/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase .Description of Operations _ - 12/24/2008 - 00:15 - 00:45 - 0.50 - FISH N DPRB DECOMP Tag top of RBP at 1,666'. Bring pump on line at 3.0 bpm. Plant Overshot. Saw pump pressure increase. Pull -20K over. RBP jumped up hole. Unable to go down hole. Pull up to next tool joint. RBP dragging up hole (unable to completly release RBP without the chance of backing off Overshot and possibily dropping RPB). WSL discuss plan forward with Fisherman, Halco Serviceman, and Rig Crew before POOH. 00:45 - 01:45 1.00 FISH N DPRB DECOMP Blow down Top Drive and lines. Monitor Well. Static. Start__ POOH slowely dragging RBP. 01:45 - 03:15 1.50 FISH N DPRB DECOMP Stop with 1 stand left. Monitor hole. Static. Drain stack. Finish POOH. Fish at surface. Discovered that the internal sliding seal sleeve (complete) from the ES-Cementer fell down hole when drilling throught the ES Cementer (why?). The sleeve (-8.6" OD x 7" ID) ran ahead of the RCJB when cleaning out the sand on top of the RBP. It eventually fell over the control arm and was sitting on top of the RBP body, not allowing the retrieving tool to get deep enough to completly "J". Recovered Halco RBP complete. Release Overshot. Lay down Fish. Break out and lay down BHA #8. Clear and clean floor. 03:15 - 05:45 2.50 FISH P DECOMP PJSM. Make-uo BHA #9 Itco Spear Assy as follows: Itco Spear, Spear Ext, Stop Sub, XO Sub (Total length = 6.04'. Note: this assy rides inside Shear Guide Assy). 8 1/8" Cutlip Guide, W P Ext, Bushing, Shear Guide Assy, 3 Jpints of 2 7/8" PAC Drill Pipe, Xo Sub, XO Sub, Bumper Sub, Oil Jar, Pump-Out Sub, XO Sub, 9 joints of 6 1/8" Drill Collars, XO Sub, XO Sub. 05:45 - 11:30 5.75 FISH P DECOMP Trip in with BHA #9 and 4" Drill Pipe from Derrick. 11:30 - 12:30 1.00 FISH P DECOMP PJSM, Slip and Cut Drilling Line 12:30 - 13:00 0.50 FISH P DECOMP Continue in the hole with Stand Number 100 and 101. 13:00 - 13:30 0.50 FISH P DECOMP M/U Stand Number 102. Take Initial Parameters, P/U Wt = 220,000 Ibs S/O Wt = 137,000 lbs. Pump Pressure = 1210 psi at 4 bpm with Pump #1. Continue to Slack Off and SLide over Tb Stub with Shear Pin Guide. Tag Up on Junk Catcher at 10071ft and No Go with Itco Spear on Junk Catcher at 10076 ft with 15,000 Ibs Down. P/U to 50,000 Ibs over string wt, Junk Catcher not moving. P/U to 80,000 Ibs over string wt, Junk Catcher not moving. S/O to cock the jars and P/U seeing only -5,000 Ibs over string wt initially and then dropping off. Junk Catcher Free. 13:30 - 15:00 1.50 FISH P DECOMP POOH and Stand Back one stand. Drop ball /rod to open circ sub. Pump Open Circ Sub and Clrc Bottoms Up at 10 bpm and 2000 psi. Nothing seen in returns. Monitor Hole. 15:00 - i 9:30 4.50 FISH P DECOMP B/O Top Drive and Blow Down. POOH and Stand Back DP in Derrick. Lay down Drill Collars. 19:30 - 21:30 2.00 FISH P DECOMP Break down and lay dow BHA #9. Recovered Junk Catcher Sub complete. Lay down Sub. Clear and clean floor. 21:30 - 22:00 0.50 BOPSU P DECOMP Set test plug. Rig up test equipment. Prep for weekly BOPE test. 22:00 - 00:00 2.00 BOPSU P DECOMP Perform week) BOPE test er BP/AOGCC re uirements. Test at 250/3500 psi. Test Pipe Rams with 4" and 4 1/2" Test Joints. Tested Annular with 4" Test Joint. The State's right to rnrnea: v~zuva i is ia:w r{m • • BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: M-16 Common Well Name: M-16 Spud Date: 9/10/1981 Event Name: WORKOVER Start: 12/10/2008 End: 12/28/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2008 Rig Name: DOYON 16 Rig Number: Date From - To li Hours Task Code NPT Phase Description of Operations 12/24/2008 22:00 - 00:00 2.00 BOPSU P __ DECOMP witness the test was waived by J. Jones. 12/25/2008 00:00 - 02:00 2.00 BOPSU P DECOMP Complete weekly BOPE test. Good test. 02:00 - 02:15 0.25 BOPSU P DECOMP Blow down lines. Rig down test equipment. 02:15 - 06:30 4.25 PULL P DECOMP Make up Mule Shoe on stand #1. Trip in hole Drill Pipe from Derrick. (prep to lay down Drill Pipe). 06:30 - 15:00 8.50 PULL P DECOMP Circulate Bottoms Up once all drill pipe in the hole. CBU at 3 bpm and 150 psi. Continue to circ and stand down for Christmas Dinner. 15:00 - 15:30 0.50 PULL P DECOMP PJSM on POOH and UD Drill Pi a Sin 15:30 - 18:00 2.50 PULL P DECOMP B/O Top Drive and Blow Down. POOH and UD DP in Pipe Shed. 18:00 - 00:00 6.00 PULL P DECOMP Have -80 joint laid down at 18:00 hrs. Continue to single down 4" Drill Pipe in Pipe Shed. Finish POOH. Pull Wear Bushing. Prep for 4 1/2" Completion. 12/26/2008 00:00 - 02:15 2.25 BUNCO RUNCMP Rig up to handle 4 1/2" Completion. Rig up Torque Turn Equipment. Perform final Jewelry inspection. Double check running order and tally. 02:15 - 02:30 0.25 BUNCO RUNCMP Safety and operations meeting for running completion with all. 02:30 - 03:00 0.50 BUNCO RUNCMP Make up Jewelry as follows: 9 5/8" x 4 1/2" Unique Overshot, 1 joint 4 1/2" 12.6 Ib/fti 13Cr-80, Vam Top Tubing, X-Nipple Assy (Note: Due to a critical space-out target, the RHC-M Plug has been removed for a planned S-line drift after the completion is landed. It will be re-installed after the drift run and before the packer setting ball/rod is dropped), Baker S-3 Packer Assy, X-Nipple Assy. All connections below the packer were BAKERLOK'd. 03:00 - 13:30 10.50 BUNCO RUNCMP n ' r nnin 4 1/2" 12.6 Ib/ft 13Cr-80 V m To Com letion as desi ned. Jet Lube Seal Guard pipe doped and Stabbing Guide with Compensator used. Make-up all joints to Optimal Torque = 4,440 ft/Ibs. Completion String Consisted of 9-5/8" x 4-1/2" Unique Overshot, X Nipple, Baker S-3 Packer, X-Nipple, (4) 4-1/2" x 1-1/2" MMG GLM's, 231 Joints of Tbg with X Nipple for SSSV, and Camerion 13-5/8" x 4-1/2" Tbg hanger. All connections made up correctly w/ no remakes or rejections. 13:30 - 15:00 1.50 BUNCO RUNCMP P/U Wt = 157,000 Ibs S/O Wt = 117,000 lbs. P/U Jt #232 with Circ Head. M/U to Completion String and Establish Circulation at 1.5 bpm and 50 psi. Slack Off with Joint #232 and Circulating at 1.5 bpm. See Top of Tbg Stub at 26.5 ft in on Jt #232 (10030 ft), slight bobble on Wt Indicator and pump pressure increased by 30 psi. Shut Down Pumps and continue to slack off. First set of shear pins seen at 29 ft in on Jt #232 and second set seen at 31 ft in on Jt #232, pins sheared 8,000 Ibs down. No Go on Tbg Stub at 33 ft in on Jt #232 with 15,000 Ibs down. P/U and Repeat process. Top of Tbg Stub seen at same spot and No Go at 31.5 ft in on Jt #232 with 3,000 Ibs down. Use 31.5 ft for Space Out. 15:00 - 16:00 1.00 BUNCO RUNCMP UD Jt #232 and Jt #231. M/U 2.08 ft Space Out Pup and M/U Jt #231 again. P/U 4-1/2" TC-II Landing Joint and M/U to Cameron Tbg Hanger. M/U Tbg Hanger to Completion String and RIH. Land Out Cameron Tbg Hanger in Tbg Spool and_ RILDS. Bottom of Unique Overshot at 10032.4 ft. 16:00 - 17:00 1.00 BUNCO RUNCMP PJSM with SLB Slick Line and Rig Crew. R/D Tbg Handling rnntea: voizuua 11:1 C:UU HM • • BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: M-16 Common Well Name: M-16 Spud Date: 9/10/1981 Event Name: WORKOVER Start: 12/10/2008 End: 12/28/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours ~'I Task Code NPT Phase Description of Operations 12/26/2008 16:00 - 17:00 1.00 BUNCO RUNCMP Equipment and prep for running Slick Line. 17:00 - 18:30 1.50 BUNCO RUNCMP Install Dutch Riser in Rotary Table and Lock Down. R/U Slick Line Sheaves and Wire. 18:30 - 00:00 5.50 BUNCO RUNCMP S-line RIH with a 3.50" LIB, 3.70" Centralizer, Weight Stem, and a 3.60" Centralizer, Spang Jars, Oil Jars, Weight Stem. Set down at 10,042' slmd. POOH. Inspect LIB. Saw "smiley face just barely on edge of LIB. Make 1 1/2" Sample Bailer. RIH with SB, 3.70" Centralizer, Weight Stem, 3.60" Centralizer, Spang Jars, Oil Jars Weight Stem. RIH. Had no problems getting thrugh the Unique Overshot/4 1/2" Tubing Stump lap. Set down in X-Nipple (installed during RWO 05/2000) at 10,055 slmd'. Work Bailer. POOH. Empty Bailer. No Sluggets or debris recovered, just Sea Water. Discuss findings with Day WSL. Make up same Sample Bailer and change out Centralizers to a 3.250" and a 3.150". RIH. Tagged at 10,090'. Start POOH. NOTE: SEE COMMENTS in REMARKS SECTION. 12/27/2008 00:00 - 01:15 1.25 BUNCO RUNCMP POOH with Sample Bailer. Empty Bailer. Recovered sand and bit of metal shavings. Discuss next run. 01:15 - 06:00 4.75 BUNCO RUNCMP RIH with 3.70" Tapered Drift and a 3.15" Centralizer. Stand-off between the two ODs = 6'. Tagged bottom at 10,090'. Had no problems (not even a bobble) at the Unique OvershoU4 1/2" Tubing Stump lap or at the X-Nipple. POOH. Also ran a 3.80" Tapered Drift with the same top Centralizer to drift the lower 05/2000 completion X-Nipple to make sure that S-Line can get down to their plug with a GS pulling tool. POOH. Make up the RHC-M and RIH. Set the RHC-M plug ,below the Packer, in the -Nipple at 9,960' K 06:00 - 06:15 0.25 BUNCO RUNCMP Lay down tool string. Rig down S-Line. Nipple down Dutch System. 06:15 - 07:00 0.75 BUNCO RUNCMP Pick-u Landing Joint and TIW Valve. Rig up lines to reverse circulate. Spot Vac Tucks. est Ines to 3,500 psi. 07:00 - 11:30 4.50 BUNCO RUNCMP Reverse Circulate 155 bbls of 140 deg SW followed with 540 bbls of 140 deg SW with Corrosion Inhibitor. Pump fluid at 3 bpm and 300 psi. 11:30 - 14:00 2.50 BUNCO RUNCMP Drop Packer setting ball/rod. Pressure up on tubing to set; Packer. Bring tubing pressure up to 3,500 psi. Test Tubing at Casing and Packer for 30 minutes. Good test. Dump tubing pressure and shear DCR-Valve. Recorded all tests on chart. Pump both directions through shear vale with no problems. 14:00 - 16:00 2.00 WHSUR P RUNCMP Pull Landing Joint and rig down test hoses. Cameron Rep set 4" H TWC in Tb Han er. Pressure Test TWC from below to 10 mins - ood test. Pressure Test TWC from above to 3500 psi for 10 mins. Pressure slowly bleeding off, make multiple attempts. Double Check all surface equipment, IA, and OA. Found blind rams leaking by. Reset Landing Joint and Screw into Tbg Hanger. Ri U ressure Test eauipment to Landing Joint. Pressure Test TWC from a ove t 500 si for 10 mins. - ood test. Blind rams will be pulled and inspected prior to rigging up on next well. Printetl: 1/5/loos 1t:1 S:00 AM • BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: M-16 Common Well Name: M-16 Spud Date: 9/10/1981 Event Name: WORKOVER Start: 12/10/2008 End: 12/28/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 12/28/2008 Rig Name: DOYON 16 Rig Number: Date From - To ,Hours Task ~ Code NPT Phase Description of Operations 12/27/2008 16:00 - 18:30 2.50 BOPSU P RUNCMP PJSM on N/D BOP's. Blow Down Choke and Kill Lines. Suck Out BOP Stack. Bleed Down Hydraulic Pressure to BOP"s and lock Out Tag Out. Two Barriers in place for N/D BOP's, Test TWC set in Tbg Hanger ,Ball & Rod on seat with kill weight fluid on top. 18:30 - 19:30 1.00 BOPSU P RUNCMP Nipple down BOP Stack and set back on stump. 19:30 - 20:30 1.00 WHSUR P RUNCMP Nipple up Cameron Adaptor Flange. Test hanger void at 5,000 psi x 10 minutes. Good test. (Note: the small steady stream of bubbles coming from the threaded nipple in the Conductor, continues). 20:30 - 22:30 2.00 WHSUR P RUNCMP Nipple up Cameron Production Tree. Fill tree wiith diesel. Test tree at 5,000 psi. Lost 200 psi in 10 minutes. No visible leaks. Cycle tree valves and re-test with same results. Acceptable test. Record on chart. 22:30 - 23:15 0.75 WHSUR P RUNCMP Pick up and test Lubricator. Pull TWCV. Lay down same. 23:15 - 00:00 0.75 BUNCO RUNCMP Spot Li'I Red Hot Oil Unit. PJSM. Rig up Li'I Red. Test circulating maniford and lines line to 3,500 psi. 12/28/2008 00:00 - 03:15 3.25 BUNCO RUNCMP Reverse circulate in with 150 bbls of diesel at 2.0 bpm/300 psi. Shut down Li'I Red pump. Allow diesel to U-Tube. Suck back lines. Rig down lines. 03:15 - 04:00 0.75 WHSUR P RUNCMP Install BPV. Test BPV from below at 1,000 six 10 minutes. Good test. Record on chart. Bleed pressure to "0". Suck back line. Li'I Red rig down. 04:00 - 05:00 1.00 WHSUR P RUNCMP Secure Tree. Rig down cellar. Release Rig Printetl: 1/5/2009 11:18:00 AM i M-16, Well History (Post Rig Workover) Date Summary 1/1/2009 T/I/O=Vac/0/0. Pull 4-1/16" CIW H BPV thru tree, post rig. 1-2' ext used, tagged C~ 108". No problems. 1/11/2009 WELL SHUT IN ON ARRIVAL. PULL B&R FROM 9947' SLM. PULL RK-DGLV STA.1 C«3 9815' MD. PULL RK-DGLV STA.2 C«~ 8609' MD. PULL RK-DGLV STA.3 C«~ 6860' MD. 1/12/2009 PULL RPK-DCR STA.4 C~3 3597' MD. SET RK-LGLV STA.4 C~ 3597' MD. SET RK-LGLV STA.3 C~ 6860' MD. SET RK-LGLV STA.2 C«~ 8609' MD. 1/13/2009 SET RK-OGLV IN STA.#1 @ 9815' MD. PULL 4-1/2" RHC FROM 9960' MD, MISSING BRASS NUBBIN & 3 PIECES OF PACKING. SIT DOWN HIGH C~3 9910' SLM W/ 3.80" CENT. & 3.5" LIB CENT HAD BRASS MARKS AND ROUGHED UP O.D, NO IMPRESSION ON LIB. RAN 2.5" P. BAILER TO 10076' SLM, RECOVER 2-GAL. METAL SHAVINGS/SLUGGITS. 1/14/2009 BAIL 14 GALLONS OF SLUGGITS W/ 3" P-BAILER FROM 10,079'SLM. (GOOD METAL MARKS ON BAILER BOTTOM.) BAIL 1/2 GALLON OF SLUGGITS W/ 2.25" P-BAILER FROM 10,079'SLM. MADE ONE ATTEMPT TO EO- XXN PLUG AT 10,079'SLM. 1/15/2009 BAIL 1 CUP OF SLUGGITS W/ 2.25" P-BAILER FROM XXN PLUG AT 10,079' SLM. PULL 4-1/2" XXN PLUG BODY FROM 10080' SLM. DRIFT W/ 3.60" CENT, AND 2.5" DRIVE DOWN BAILER TO 11390' SLM, BAILER EMPTY. WELL LEFT SHUT IN, PAD OP NOTIFIED. Page 1 of 1 VELLHEAD = McEVOY ACTUATOR =~ OTIS :B. ELEV =~ 52.28' 3F. EL'~V = 27.58' OP = 2000' -- Aax Angle = 47 @ 4500' Yatum MD = - 11148' ?atum TVD - 8800' SS 9-5/8'° x 13-318" CSG, ECP 1499' ~ 9-5l8" Casing Patch 1531' 13-318" CSG, 72#, L-80, ID = 12.347" 2733' Minimum ID = 3.725" @ 10098' 5-112" OTIS XN NIPPLE 4-1/2" TBG, 12.6#, 13CR, 10023" VAM TOP.0152 bpf; ID = 3.958" 4-1/2" TBG STUB (12/18/08) 10029' (4-1/2" TBG, 12.6#, 13CR, I 10121' VAM TOP.0152 bpf, ID = 3.958" 5-1/2" TBG STUB (05/27/00) 10121' TOP OF 5" SCAB LNR 10194' 5-1/2" TBG, 17#, 13CR, ID = 4.892" 10196' TOP OF 7" LNR 10314' 9-5/8" CSG, 47#, L-80, ID = 8.681" 107$4' PERFORATION SUMMARY REF LOG: SWS BHCS ON 09/29/81 A NGLE AT TOP PERF: 38 @ 10954' Note: Refer to Production DB for historical perf data SPF INTERVAL OPN/SOZ BATE 6" 10954 - 10984 O 01 /06/92 4" 10964 - 11008 S 01/04/92 4" 11000 - 11008 S 07/27/91 4" 11016 - 11036 S 07/27/91 6" 11036 - 11076 S 07/27/91 4" 11076 - 11080 S 07/27/91 4" 11100 - 11180 S 07/27/91 6" 11341 - 11356 O 05/23/98 5" PBTD PRE-RWO PBTD 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1j 1508' ~ 11592' 11595' 11750' S =NOTE: ***13 CHROME TBG &LNR*** M -16 19$2' ~4-1/2" HI=S X NIP, ID = 3.813" I ~ 2613' --~5/8" DV PKR 2700' FOC GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3597 3310 46 (v1MG DOME RK 16 01(13/( 3 6860 5603 0 MMG DOME RK 16 01(13/( 2 8609 6934 36 MMG DOME RK 16 01/13/( 1 9815 7835 0 MMG SO RK 20 01113!( 989$' 4-1/2" HES X NIP, ID = 3.813" " 9926' 9-518" x 4-1/2" BAKER S-3 PKR, ID = 3.87 9960' 4-1 /2" HES X NIP, ID = 3.813" 10032' 9-518" x 4-112" UNIOUE OVERSHOT; ID =4.625' 10053' ~1 /2" HES X NIP, ID = 3.813" 10064' 9-5/8" x 4-1/2" BKR S-3 FKR, ID = 3.875" 10088' -~DUMPSLUGGffS (12J06/08~ 10098' 4-1/2" XN N~, ID = 3.725" 10098' 4-1/2" PXN PLUG (09/11/06) 10128' 5-1/2" CUSTOM OVERSHOT 10129" 4-1/2" HES X NIP, ID = 3.813" 10143' 9-5/8" X 5-1/2" HBBP TNV PKR, ID = 4.75" 10163' 5-1/2" OTIS X NIP, ID = 4.562" 10164' 1/2" OTIS XN NIP 08/03/91 ELMD 5 - 10176' S-1/2" OTIS XN NIP, ID = 4.455" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/05/81 ORIGINAL COMPLETION 12/28/08 MJA RWO - Doyon 16 05/25/00 RIG WORKOVER 01/02/09 /SV CORRECTIONS 11/05/01 RN/TP CORRECTIONS 01/15/09 DAV/SV GLV C/O (01/13/09) 10/14/02 JAL/KK WAIVER SAFETY NOTE 11/21/02 BM/KAK WAIVER SAFTY NOTE DELETED 09/11/06 JRP/TLH PXN PLUG SET PRUDHOE BAY UNIT WELL: M-16 PERMIT No: 1810860 API No: 50-029-20105-00 SEC 1, T11N, R12E, 606' WEL & 1606' SNL BP Exploration (Alaska/ ~chlum6erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,~'` Alaska Data & Consulting Services / 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: .- tE r t ~, R, ~~,, )) ± . NO.5020 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 12/29/08 well Job # 4-20/M-35 12014059 STATIC SURVEY/PERFo Descri lion Date gL 12/11/08 Color CD W-18 11968978 PRODUCTION PROFILE 1 1 Y-07A 12103704 INJECTION PROFILE _ ~ 12/20/08 1 1 P2-35 12031533 SCMT 12/18/08 1 1 M-16 12111931 SCMT _ ~ L~ 12/18/08 1 1 P2-i5A 40015006 OH MWD/LWD EDIT ~ 12/19/08 1 1 P2-15APB3 40015006 OH MWD/LWD EDIT ~ _ ~`~ 04/01/07 2 1 P2-15AP62 40015006 OH MWD/LWD EDIT a- 9 03/27/07 2 °~~ a ~ OD 03/24/07 2 1 P2-15APB1 40015006 OH MWD/LWD EDIT 1 W-31A 40017846 OH MWD/LWD EDIT ~~ ( 03/22/07 2 1 W'29 11549353 CH EDIT (USIT) _' _ ~ 09/27/08 2 1 H-05A AXBD-00002 MCNL 12/18/06 1 11/20/08 1 1 g PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 • • o ~ o o ~ SARAH PAUN, GOVERNOR oii[1-7~ O~ ~ a7ray7 333 W. 7th AVENUE, SUITE 100 COI~TSFiRQA'1'I011T COMI~'IISSI011T ~ ANCHORAGE, ALASKA 99501-3539 JJJ PHONE (907) 279-1433 David Reem FAx (907) 276-7542 Engineering Team Leader BP Exploration Alaska Inc. PO Box. 196612 ,~,d..~~~ ~ ~~~ f_ ~~ ~~~~ Anchorage, AK 99519-6612 O $~ ~~~ Re: Prudhoe Bay Feld, Prudhoe Bay Oil Pool, M-16 Sundry Number: 308-409 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of November, 2008 Encl. Sincerely, c` ~ /.~ STATE OF ALASKA //-/ ~~~ ~ ~ ~~~ A~ OIL AND GAS CONSERVATION C011~SION ~`~ ,~ ~ APPLICATION F R SUND Y APPROVAL ~tv ~ ~~~ ti ~ ~~~ O R 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time ExtensieM ' ®Atter 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 181-088 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: " P.O. Box 196612, Anchorage, Alaska 99519-6612 SO-029-20613-00-00 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: M-16 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): O'~ ADL 028257 " 52.3' - 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): 11750' . 9319' ~ 11508' 9133' 10098' None i rl , „ , 7 /" 4 7 /" 4 i i n r 4 7" 1 ' ' r i 1 1 1 '-1 1 '- 1 1 Perforation Depth MD (ft): Perforation Depth TVD (it): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 10954' - 11356' 8699' - 9014' 4-1/2", 12.6# x 5-1/2", 17# ~3Gr80 / NT13Cr80 10196' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'S-3' packer; Packers and SSSV MD (ft): 10064'; 9-5/8" x5-1/2" TIW 'HBBP' packer 10143' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ' ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: January 7, 2009 ®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 David Bjork, 584-5683 Printed Na David R em Title Engineering Team Leader Prepared By Wartre/Number Signature ?^- Phone 564-5743 Date !i iy wpg Terrie Hubble, 564-4628 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: ~~~ ~ `5 ~ ~ ~ ~ C `~~ Subsequent Form Required: APPROVED BY -/~ ~~ A roved B : MISSIONER THE COMMISSION Date a V Form 10-403 Revised 06/2Q0¢ . E t,,/ `/ -4~~~AL K ~~~ ~~ '~ ~ ~ ~ ~DO~ Submit In Duplicate • • by GPy,~y, M-16 Expense Rig Workover Scope of Work: Pull 4-'h" 13Cr-80 completion, cut and pull 9-5/8" casing, run and cement to 9-5/8" surface casing, test 9-5/8" casing, run 4-1/2" 13Cr80 "stacker-packer" completion. MASP: 2380 psi Well Type: Producer Estimated Start Date: Production Engineer: Intervention Engineer: January 07, 2009 Don Brown David Bjork Pre-Rig Work Reauest: F 1 MIT-T to 1,OOOspi CMIT-TxIA to 3,500psi, MIT-OA 2000psi and determine LLR if necessa . S 2 Drift tubin for 4-1 /2"Jet cutter, set 'unk catcher on to of PX lu at 10098'MD E 3 Jet Cut 4-1/2" 12.6# 13Cr80 Tubing at 10038' MD in the middle of the second pup above the X ni le at 10,053' MD. Reference tubin tall dated 5-25-2000 F 4 Circulate well through the cut with seawater (8.6ppg) and diesel freeze protect to 2000' MD. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. V 6 Set BPV in the tubin han er. O 7 Verify that the well has a competent cellar. Add spray in liner for secondary containment. Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 3-'/z" x 6" VBR pipe rams. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-~/z" tubing string to the cut. 3. Run USIT log to determine top of cement in 9 5/a" x 13-3/8" annulus. 4. Set retrievable bridge plug 100' below the top of cement and pressure test to 1500 psi for 15 minutes. 5. Cut and pull 9-5/8" casing from above the top of cement. Note: Pipe rams will not be changed to 9-5/8" as the well has two tested barriers (PX Plug at 10,098' MD and RBP) to the reservoir. 6. Run and fully cement new 9-5/8" casing to surface. 7. Retrieve bridge plug. 8. Run 4-~/z" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at 9948' MD. 9. Displace the IA to packer fluid and set the packer. 10. Test tubing and IA to 3500 psi. Freeze protect to 2000' MD. 11. Set BPV. ND BOPE. NU and test tree. RDMO. I TREE _ . 6" McEV OY WELLHEAD McEVOY ACTUATOR = OTIS KB. ELEV = _ 52.28' BF. ELEV = 27.58' KOP = 2000' Max Angle = 47 @ 4500' Datum MD = 11148' Datum TV D = 8800' SS ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ -16 S NOTE: ***13 CHROME TBG ~ LNR*** 2011' 4-1/2" HES X LAND. NIP, ID = 3.813" 2700' FOC GAS LIFT MANDRELS Minimum ID = 3.725" @ 10098' 5-1/2" OTIS XN NIPPLE ~ ~4-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" ~ 10125' ~ TOP OF 5" SCAB LNR ~ TOP OF 7" LNR ~- j 10314' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 1p7$3' PERFORATION SUMMARY REF LOG: SWS BRCS ON 09/29/81 A NGLE AT TOP PERF: 38 @ 10954' Note: Refer to Production DB for historical perf data SPF INTERVAL OPWSQZ DATE 6" 10954 - 10984 C 01/06/92 4" 10964 - 11008 S 01/04/92 4" 11000 - 11008 S 07/27/91 4" 11016 - 11036 S 07/27/91 6" 11036 - 11076 S 07/27/91 4" 11076 - 11080 S 07/27/91 4" 11100 - 11180 S 07/27/91 6" 11341 - 11356 C 05/23/98 5" PBTD 11508' 5" SCAB LNR 18#, NT13CR-80, .0177 bpf, ID = 4.276" 11592' PR~RWO PBTD 11595' 7" LNR 26#, L-80, .0383 bpf, ID = 6.276" 11750' ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3167 2954 41 MMG DOME RK 16 06/08/00 4 4285 3757 45 MMG SO RK 20 06/08/00 3 7033 5691 44 MMG DMY RK 05/00 2 8654 6935 37 MMG DMY RK OS/00 1 10025 7962 42 MMG DMY RK 05/00 10~ 053' I~ 4-1/2" HES X NIP, ID = 3.813" 10064' 9-5/8" x 4-1/2" BKR S-3 PKR, ID = 3.875" 10098' 4-1/2" XXN NIP, ID = 3.725" 10098' 4-1/2" PXN PLUG (09/11/06) 10125' 5-1/2" TBG STUB 10128' -j 5-112"CUSTOMOVERSHOT 10143' 9-5/8" X 5-1/2" HBBPTMI PKR ID = 4.75" 10163' 5-1l2" OTIS X NIP, ID = 4.562" 10176' 5-1/2" OTIS XN NIP, ID = 4.455" 10164' ELMD 5-1/2" OTIS XN NIP 08/03/91 DATE REV BY COMMENTS DATE REV BY COMMENTS 10!05/81 ORIGINAL COMPLETION 05/25!00 RIG WORKOV 62 11/05/01 RNITP CORRECTIONS 10/14/02 JAUKK WANER SAFETY NOTE 11/21/02 BM/KAK WANERSAFTY NOTE DELETED 09/11/06 JRPlfLH PXN PLUG SET PRUDHOE BAY UNff WELL: M-16 PERMR No: 1810860 API No: 50-029-20105-00 SEC 1, T11 N, R12E, 606' WEL & 1606' SNL BP 6cploration (Alaska) TREE _ 6" Mc EV OY WELLHEAD = McEVOY ACTUATOR = OTIS KB. ELEV = 52.28' BF. E1EV = 27.58' KOP = 2000' Max Angle = 47 @ 4500' Datum MD = 11148' Datum TV D = 8800' SS ~ M-16 Proposed 9-5/8" x 13-3/8" CSG, ECP -2380' 9-5/8" Casing Patch 2400' , 13-318" CSG, 72#, L-80, ID = 12.347" 2733' 4-1/2" TBG, 12.6#, 13CR VamTop, 10290' Minimum ID = 3.725" @ 10098' 5-1 /2" OTIS XN NIPPLE 4-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 10125' TOP OF 5" SCAB LNR 10194' - TOP OF 7" LNR 10314' 9-5/8" CSG, 47#, L-80, ID = 8.681 " 10783' PERFORATION SUMMARY REF LOG: SWS BHCS ON 09/29/81 ANGLE AT TOP PERF: 38 @ 10954' Note: Refer to Production DB for historical pert data SPF INTERVAL OPWSQZ DATE 6" 10954 - 10984 C 01 /06/92 4" 10964 - 11008 S 01 /04/92 4" 11000 - 11008 S 07/27/91 4" 11016 - 11036 S 07/27/91 6" 11036 - 11076 S 07/27/91 4" 11076 - 11080 S 07/27/91 4" 11100 - 11180 S 07/27/91 6" 11341 - 11356 C 05/23/98 5" PBTD 11508' 18#, NT13CR-80, .0177 bpf, ID = 4.276" 11592' PRE RWO PBTD 11595' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~ 750' rnci icrnuNnaci c 1 9-5/8" x 4-1/2" BKR S-3 PKR, ID = 3.875" I I 4-1 /2" XXN NIP, ID = 3.725" I 10128' -{ 5-1/2" CUSTOM OVERSHOT 10125' 5-1/2" TBG STUB 1 9-5/8" X 5-1/2" HBBPTNV PKR, ID = 4.75" I 10163' I~ 5-1/2" OTIS X NIP, ID = 4.562" I 5-112" OTIS XN NIP, ID = 4.455" I 10164' ELMD 5-1/2" OTIS XN NIP 08/03/91 DATE REV BY COMMENTS DATE REV BY COMMENTS 10/05/81 ORIGINAL COMPLETION 05/25/00 RIG WORKOVER 11/05/01 RNITP CORRECTIONS 10/14/02 JAL/KK WANER SAFETY NOTE 11/21/02 BM/KAK WANERSAFTY NOTE DELETED 09/11/06 JRP/TLH PXN PLUG SET PRUDHOE BAY UNff WELL: M-16 PERMfT No: 1810860 API No: 50-029-20105-00 SEC 1, T11N, R12E, 606' WEL & 1606' SNL BP Exploration (Alaska) S NOTE: *'*13 CHROME TBG &LNR"** 2000' 4-1/2" HES X NIP, ID = 3.812" Surface OA Cemented to Surface ~ 2700' FOC 1 ST MD ND DEV TV PE VLV LATCH PORT DATE 4 3583 3300 45 MMG DCK 3 6856 5600 44 MMG DMY 2 8629 6950 36 MMG DMY 1 9873 7877 43 MMG DMY ~ 9938' 4-1/2" HES X NIP, ID = 3.812" ~ 9948' 9-5/8" x 4-1 /2" BAKER S-3 PKR 9975' 4-1/2" HES X NIP, ID = 3.812" 10040' 9'5/8" X 4-1/2" UNIQUE OVERSHOT 10053' 4-1/2" HES X NIP, ID = 3.813" STATE OF ALASKA ALASKA( _AND GAS CONSERVATION COMI~ ~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate B Pull Tubing [] Alter Casing B Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 52.30' [] Exploratory 7. Unit or Properbj Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1606' SNL, 606' WEL, SEC. 01 T11N, R12E, UM ,~'"~ ..... , ........ ~ ......~ ~.~ ~. ....... M-16 At top of productive interval fi ~. ~. ~/.~ % ......~ ~ .,, 9. Permit Number / Approval No. ....... 181-086 4184' NSL, 1155' WEL, SEC. 36, T12N, R12E, UM 10. APl Number At effective depth,.:!~:.j '~'i~ 2 0 ~000 50- 029-20613-00 4521' NSL, 1078' WEL, SEC. 36, T12N, R12E, UM 11. Field and Pool · ,,~ ,~, ~,~,.,. ~ At total depth ,.~[[~i~,a ~i 0;t ~ Coits~ Coi~,~'~J$$ioR Prudhoe Bay Field / Prudhoe Bay 4674'NSL, 1058' WEL, SEC. 36, T12N, R12E, UM A~C~0,r~8. Pool i12. Present well condition summary Total depth: measured 11750 feet Plugs (measured) true vertical 9319 feet measure. ,,.0.,ee, .un.,measure., ORIGINAL true vertical 9133 feet Casing Length Size Cemented MD 'I'VD Structural Conductor 110' 20" x 30" 8 cu yds concrete 110' 110' Surface 2709' 13-3/8" 3767 cuff Permafrost II 2733' 2671' Intermediate 10762' 9-5/8" 1564 cuft Class 'G', 130 cuft PF 'C' 10786' 8565' Production Liner 1437' 7" 456 cuft Class 'G' 10313'- 11750' 8203' - 9319' Liner Tieback (Scab) 1398' 5" 208 cuft Class 'G' 10194' - 11592' 8115' - 9198' Perforation depth: measured 10954'- 10984', 11000'- 11008', 11016'- 11080', 11100'- 11180', 11341'- 11356' true vertical 8699' - 9014' (five intervals) Tubing (§ize, grade, and measured depth) 4-1/2", 12.6#, 13Cr to 10128'; 5-1/2", 17#, NT13Cr80 from 10111'- 10196' ' Packers and SSSV (type and measured depth) 4-1/2" HES 'X' nipple at 2011'; Baker 'SABL-3' packer at 10064'; 9-5/8" TIW 'HB-BP' packer at 10143' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil r'l Gas [] Suspended Service [] Daily Report of Well Operations 17., hereby certify that ,he~.~8~,oing is tr~n.~ct ,o the best of my knowledge Si,ned Terrie Hubble-'~/~)j~/~ Title Technical Assistant I,1 Date " Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Progress Report Facility PB M Pad Date/Time 23 May 00 03:30-06:00 03:30-06:00 06:00-08:30 06:00-08:30 08:30 08:30-17:00 08:30-09:30 09:30 09:30-10:30 10:30 10:30-11:00 11:00 11:00-14:30 14:30 14:30-15:00 15:00 15:00-17:00 17:00 17:00-23:30 17:00-20:00 20:00 20:00-23:30 23:30 23:30-01:30 23:30-01:30 24 May 00 01:30 01:30-06:00 01:30-03:00 03:00 03:00-03:30 03:30 03:30-06:00 Well M-16 Page 1 Rig Nabors 9ES Date 30 May 00 Duration 2-1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr Move rig Rig moved 50.00 % Move rig along well row to M-16RWO Move rig (cont...) Rig moved 100.00 % At well location - Slot /~nch0r~e Move and spot rig over well M-16 RWO. Spot camps, pit complex and workshop. ,..'.ui,,, 2 0 201 Oil & Gas Cons, 8-1/2 hr lhr lhr 1/2 hr 3-1/2 hr 1/2 hr 2hr 6-1/2 hr 3hr 3-1/2 hr 2hr 2hr 4-1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr Accept rig @ 0830 hours on 23rd May 2000. Wellhead work Installed Kill manifold Equipment work completed Install secondary annulus valve and rig circulating manifold. Retrieved Hanger plug Equipment work completed RFLI DSM and pull TWC with lubricartor- no pressure. Held safety meeting Completed operations Hold Prespud meeting and conduct evacuation drill. Circulated at 10111.0 ft Obtained bottoms up (100% annulus volume) Circulate out Freeze Protect and bottoms up @ 7.6 BPM/900 psi. Installed Hanger plug Equipment work completed Install TWC and test from below to 500 psi. Rigged down Xmas tree Equipment work completed N/D Tree and adator checking for trapped pressure. BOP/riser operations - BOP stack Installed BOP stack Equipment work completed Nipple up B OPE. Tested BOP stack Pressure test completed successfully - 3500.000 psi Test BOPE to 300/3500 psi. Lou Grimaldi of AOGCC waived witness of test. Wellhead work Retrieved Hanger plug Equipment work completed R/U DSM and pull TWC @ second attempt. Pull Gas lift completion, 5-1/2in O.D. Retrieved Tubing hanger Equipment work completed MFLI drillpipe landing joint and screw into hanger. BOLDS. Pull hanger to rigfloor- no over pull- up weight @ 190 klbs. Monitor well- static. L/O hanger and landing joint. Rigged up Completion string handling equipment Equipment work completed Laid down 1400.0 ft of Tubing POOH laying down 5.1/2" tubulars. 33 out of 252 '-:-' .... '~ report time- llole fill good IdlU. ULIL ~ 0 intuition Facility PB M Pad Progress Report Well M-16 Page 2 Rig Nabors 9ES Date 30 May 00 Date/Time 06:00-19:00 06:00-06:30 06:30 06:30-07:00 07:00 07:00-17:30 17:30 17:30-19:00 19:00 19:00-22:00 19:00-22:00 22:00 22:00-00:00 22:00-00:00 25 May 00 00:00 00:00-03:30 00:00-03:30 03:30 03:30-06:00 03:30-06:00 06:00-08:00 06:00-08:00 08:00 08:00-22:45 08:00-11:00 11:00 11:00-14:30 14:30 14:30-15:00 15:00 Duration 13hr 1/2 hr 1/2 hr 10-1/2 hr 1-1/2 hr 3hr 3hr 2hr 2hr 3-1/2 hr 3-1/2 hr 2-1/2 hr 2-1/2 hr 2hr 2hr 14-3/4 hr 3hr 3-1/2 hr 1/2 hr Activity Pull Gas lift completion, 5-1/2in O.D. (cont...) Laid down 2000.0 ft of Tubing Stopped: At sub-assembly Lay out 48 joints 5.1/2" Chrome tubing. 25 rubber clamps and 2 stainless steel bands. Rigged down sub-surface equipment - SCSSSV Equipment work completed Laid down 10111.0 fi of Tubing Completed operations Pull remaining completion. 252 joints of 5.1/2"- in good condition. 4 x GLM's. Cut off 3.13 ft. Stub remaining = 6.58 fi. Rigged down Handling equipment Equipment work completed Rig down handling equipment- clean rigfloor. Strap BHA while clearing up rig. BHA run no. 1 Made up BHA no. 1 BHA no. 1 made up Make up cleanout assembly and RTTS. Set same 15 ft below wellhead. Test RTTS to 1000 psi- good. BOP/riser operations - BOP stack Removed BOP stack Equipment work completed Pull Mousehole and bell nipple. N/D BOP and Tubing Head. Stand back out of way. Wellhead work Installed Seal assembly Equipment work completed, seal energised Remove old pack-off. Came out in pieces. Clean up seal area and install new pack-off. Test same to 5000 psi/10 minutes- good. BOP/riser operations - BOP stack Installed BOP stack Nipple up BOP, bell nipple. Run test plug and test flange to 3500 psi- good. Preparing to recover RTTS. Perform integrity test Tested Casing Pressure test completed successfully - 3000.000 psi Recover RTrS. Test wellbore to 300/3000 psi- good. 8.5 bbls pumped and returned. Lay down RTTS. BHA run no. 1 Singled in drill pipe to 3745.0 ft 117 joints picked up Single in 4" drillpipe. R.I.H. to 10030.0 ft RIH to above tubing stub @ 10,111 At Top of fish: 10030.0 ft Washed to 10111.0 ft Stopped: To circulate Wash down last stand @ 4.5 BPM/310 psi. Observe pressure increase @ 10,111'. Tag no go @ 10,117'. Facility PB M Pad Date/Time 15:00-16:30 16:30 Duration 1-1/2 hr 16:30-21:30 21:30 5hr 21:30-22:45 22:45 1-1/4 hr 22:45-06:00 7-1/4 hr 22:45-23:30 23:30 23:30-00:00 26 May 00 00:00 00:00-06:00 3/4 hr 1/2 hr 6 hr 06:00-00:30 06:00-16:30 16:30 18-1/2 hr 10-1/2 hr 16:30-18:00 18:00 18:00-23:00 23:00 1-1/2 hr 5hr Progress Report Well M-16 Page 3 Rig Nabors 9ES Date 30 May 00 23:00-00:30 27 May 00 00:30 00:30-01:30 00:30-01:30 01:30 01:30-02:30 01:30-02:30 02:30 02:30-06:00 02:30-05:00 05:00 05:00-06:00 1-1/2 hr lhr lhr lhr lhr 3-1/2 hr 2-1/2 hr lhr Activity klbs. Circulated at 10111.0 ft Hole swept with slug - 100.00 % hole volume Sweep hole w/40 bbls Hi vis while working scraper over packer setting depth. 12 BBM/1700 psi. Pulled out of hole to 200.0 ft AtBHA POOH laying out 54 singles leaving enough dp in derrick for next workover. Pulled BHA BHA Stood back Pull BHA standing back drillcollars. Pull wear ring. Run Gas lift completion, 4-l/2in O.D. Rigged up Completion string handling equipment Equipment work completed Held safety meeting Completed operations Ran Tubing to 2450.0 ft (4-l/2in OD) Run 4.1/2" Chrome new vam completion. No rejects. 56 joints out of 234 run @ report time. Run Gas lift completion, 4-1/2in O.D. (cont...) Ran Tubing to 10121.0 ft (4-1/2in OD) Stopped: To pick up/lay out tubulars Run 4.1/2" Chrome-80 Completion w/New Vam threads. Up weight= 143 klbs, down weight= 112 klbs. Wash down and observe pressure increase and no go- both 1 ft deeper than pipe tally. Take 50 klbs o/pull coming off stub- probably overshot on collar. Space out tubulars Completed operations Confirm tag depth. Space out tubulars and pick up hanger. Rig up to reverse circulate inhibited brine. Reverse circulated at 10121.0 ft Obtained req. fluid properties - 100.00 %, hole vol. Reverse circulate 700 bbls of clean seawater and inhibited seawater to the annulus @ 3 BPM/160 psi. Ran Tubing on landing string to 10121.0 ft Hanger landed Run landing string and land hanger. RILDS. Coduct test on hanger seals from above to 1000 psi- good. Wellhead work Installed Hanger plug Equipment work completed Install TWC and test to 500 psi from below and to 1000 psi from above. BOP/riser operations - BOP stack Rigged down BOP stack Equipment work completed Wellhead work ,JUN 2 0 2000 Installed Xmas tree Equipment work completed ~aska Install Xtree and test same to 5000 psi. Retrieved Hanger plug RAJ DSM and pull TWC @ report time. Facility PB M Pad Progress Report Well M-16 Page 4 Rig Nabors 9ES Date 30 May 00 Date/Time 06:00-08:00 06:00-07:15 07:15 07:15-08:00 08:00 08:00-10:00 08:00-10:00 10:00 10:00-06:00 10:00-12:00 12:00 Duration 2hr 1-1/4 hr 3/4 hr 2hr 2hr 20 hr 2hr Activity Run Gas lift completion, 4-1/2in O.D. Set packer at 10064.0 ft with 3000.0 psi Packer set at 10064.0 ft R/U HB & R and surface manifold. Test lines to 3000 psi. Drop ball and rod. Pressure up and set packer w/3000 psi/2.1 bbls. Loose 190 psi/30 minutes. Bleed to 1500 psi. Tested Permanent packer - Via annulus Pressure test completed successfully - 3000.000 psi Pressure up on annulus and test to 3000 psi/30 minues. 6.4 bbls. Good test. Bleed tubing to zero and shear RP with 2200 psi differential. Fluid system Freeze protect well - 150.000 bbl of Diesel Completed operations Freeze protect well with HB & R with 150 bbls. Allow to U-tube. Wellhead work Installed Hanger plug Equipment work completed Install BPV with DSM and test from below to 500 psi. RDMO and secure tree. Rig REleased to M-15 RWO @ 1200 hrs on 27th May 2000 STATE OF ALASKA ALASI~' .... L AND GAS CONSERVATION COMMISSIOI~ REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate x Plugging Pull tubing Alter casing Repair well Perforate Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 1606'SNL. 606' WEL, SEC. 01, T11No R12E. UPM At top of productive interval 1096' SNL, 1158' WEL, SEC. 36, T12N, R12E, UPM At effective depth 895' SNL, 1073' WEL, SEC. 36. T12N, R12E, UPM At total depth 606' SNL. 1060' WEL, SEC. 36, T12N, R12E, UPM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 52,28 AMSL 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number M-16 (41-36-12-12) PBU 9. Permit number/approval number 81-86 / 10. APl number 50- 029-20613 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11750 feet BKB 9319 feet 11585 feet BKB 9192 feet Plugs (measured) Junk (measured) junk in hole (20' perf gun) Casing Length Size Cemented Measured depth Structural .. Conductor 110 20 x 30 8 c.v. 134 Surface 2709 13 3/8 3767 c.f. 2733 Intermediate 10762 9 5/8 1694 c.f. 10786 Production .. Liner 1398 5 208 c.f. C/ass "G" 10194-11592 Perforation depth: measured 10954'-10984', 11000'-11008', 11016'-11080', 11100'-11180', 11341'-11356' True vertical depth BKB 134 2671 8565 8114-9197 true vertica§ubsea 8646'-8862' (five intervals) Tubing (size, grade, and measured depth) 51/2",17#,NT13CR.80 NSCC tubing to10196,MD © I G I N A I Packers and SSSV (type and measured depth)9 5/8" T/W 'HB-BP' b/g bore Packer@ 101431'~ 4-1./2" Ot/s S..~V@ 1999'MD 13. Stimulation or cement squeeze summary See Attachment ' G8 1999 Intervals treated (measured) 14. Treatment description including volumes used and final pressure Gas Cons, Commissiot'~ AnchOrarqa Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4210 8060 33 0 334 Subsequentto oper~ion 6131 12079 16 0 350 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run ~ I Daily Report of Well Operations Oil× Gas Suspended 17. I hereby certi,~,~hat, t!~e forf~bin, g is true a!~orrect to the best of my knowledge. Signed ~/~'~ ~/~ _~~~-,~ TitleTechnicalAssistantlV Form 10-404 Rev 06/15/88 Service Date /'/~//~ SUBMIT IN DOPLI(~/~TI~~'~ M-16 DESCRIPTION OF WORK COMPLETED Stimulation Operation O5/O5/98 A Acid Stimulation Treatment was performed using the following fluids: SUMMARY Ran in hole and dry tagged TD at 11,325'. Approx. 100' of frac sand had settled out. Utilized filtered 2% KCL and 50 bbls Biozan in 2 sweeps to clean out liner to 11,450' ctmd. Had trouble maintaining good returns. No sand in returns was noted. Shut down and dry tagged at starting depth of 11,325'. Decision made to proceed with acidization of perf interval 10,954' to 10,984'. Pertformed acid wash and displaced acid to perfs with 200 bbls of filtered 2% KCL. Fluids Pumped BBLS. Description 111 Methanol 1600 Filtered 2% KCL water with friction reducer 320 2% KCL 140 Biozan 26 15/10 HCL/Xylene (Design per Program) 2197 Total Pumped STATE OF ALASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdOWnpull tubing Alter casin?mulate- --Repair Pwl~ging Othe~e~°rate x '/~,/ I 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ,~ BP Exploration (Alaska) Inc. D_evel,opm. ent 3( KBE = 52.28 AMSL fe~'t,~~ 3. Address Stratigraphicl:Xp~°ra~°rY ~" ~ P. O. Box 196612, Anchorage, Alaska 99519-6612 Servk:e Prudhoe Bay Unit J 4. Location of well at surface 1606' SNI., 606' WEI., SEC. 01, T11N, R12E, UPM At top of productive interval 1096' SNL, 1158' WEL, SEC. 36, T12N, R12E, UPM At effective depth 895' SNL, 1073' WEL, SEC. 36, T12N, R12E, UPM At total depth 606' SNL, 1060' WEL, SEC. 36, T12N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2709 Intermediate 10762 Production -- Liner 1398 Perforation depth: measured 11750 feet BKB 9319 feet 11585 feet BKB 9192 feet Size 8. Well number M-16 (41-36-12-12) PBU g. Permit number/approval number 81-86 / 10. APl number 50- 029-20613 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Junk (measured) Cemented junk in hole (20' perf gun) 20x30 8 c.y. 13 3/8 3767 c. f. 9 5/8 1694 c.f. Measured depth True vertical depth BKB 134 134 2733 2671 10786 8565 5 208 c.f. Class "G" 10194-11592 8114-9197 10954'-10984', 11000'-11008', 11016'-11080', 11100'-11180', 11341'-11356' true vertical subsea 8646'-8862' (five intervals) Tubing (size, grade, and measured depth) 5 1/2", 17#,NT13CR-80 NSCC tubing to 10196'MD Packers and SSSV (type and measured depth) 9 5/8" TIW 'HB-BP' big bore Packer@ 10143'MD,4-1/2" Otis SSSV@ 1999'MD 13. Stimulation or cement squeeze summary 14. See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED AU G 1 1 199;5 Reoresentative Daily Average Production or In!ection Dat~ .~l)Ch0r~3.qe OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ~ uD~ng ~'ressure Prior to well operation Subsequent to operation 4210. 8060 33 0 334 6131// 12079 16 0 350 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ×. Gas Suspended .. Service 17. I hereby certify that the foregoing, is tr~e/~nd correct to the best of my knowledge. Signed /~/~ .,, /¥-~Z/[/t/~, Title Senior TechnicalAssistant I Form 10-40~ Re~ 06/15/8~ ~'-~- Date SUBMIT ~N DdPdCATE 1/03/92 1/06/92 1/13/92 fjh 5/11/93 WELL M-16(41-36-12-12) NRWO/Reperf/Frac A NRWO (ACID) was performed using the following fluids: 480 bbls PW to load well 5 bbls PW 24 bbls ACID 36 bbls PW 5 bbls EW(Preflush) 16 bbls Cement 24 bbls EW(Spacer) 24 bbls Duo Polymer(Contaminant) 10 bbls PW(Displacement) 187 bbls PW (Reverse Out) 75 bbls PW (Jet Pass) 35 bbls PW(Final Reverse Out) 65 bb;s Recovered(N2 Displacement) 33 bbls MEOH(Freeze Protection CT) Well Cleaned out to 11430' 310 bbls Load fluid behined pipe Today 13 bbls Cement Recovered ACID: 15% HCL W/10% XYLENE, 1% WS-36, .4% HAI-85, .45% FERCHEK-A CEMENT: 15.5 PPG Class G Cement Containing, .2% CFR-3, .15% HR-12, .02 GAL/SK HALAD-344L ACID SQZ #1 The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 10974' - 10984' MD 10954' - 10974' MD A Frac was performed using the following fluids: Fluids Pumped: 20 bbls 50# gel prepad to establish rate. 67 bbls 50# X-link gel pad w/9% ESL 132 bbls 50# X-link gel w 18,000# 20/40 carbolite 135 bbls 50# X-link gel w 50,000# 16/20 CP 241 bbls 20# gel flush 120 bbls diesel to pt lines and freeze protect. RECEIVED AU G 1 1 1993 Alaska Oil & Gas Cons. Oommissio~ Anchorage STATE OF ALASKA ..~ A XA OIL AND GAS CONSERVATION COMMI ,N i G N A L REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1606'SNL, 606'WEL, SEC. 01, T11N, R12E, UPM At top of productive interval 1096' SNL, 1158' WEL, SEC. 36, T12N, R12E, UPM At effective depth 895' SNL, 1073' WEL, SEC. 36, T12N, R12E, UPM At total depth 606' SNL, 1060' WEL, SEC. 36, T12N, R12E, UPM 5. Type of Well: Development X Exploratory StratJgraphic Service RECEIVED S EP 2 5 1992 Alaska 0il & Gas Cons. Cornm'~ss~°~ Anchorage 6. Datum elevation (DF or KB) KBE = 52.28 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number M-16 (41-36-12-12) PBU 9. Permit numbedapproval nur~er 81-86/ 10. APl number 50- 029-20613 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 11750feet BKB 9319feet Plugs (measured) Effective depth: measured true vertical 11585feet BKB 9192feet Junk (measured) junk in hole (20'perf gun) Casing Length Structural -- Conductor 110 Surface 2709 Intermediate 10762 Production -- Liner 1398 Perforation depth: measured Size Cemented Measured depth True vertical depth BKB 134 134 2733 2671 10786 8565 20x30 8 c.y. 13 3/8 3767 c.f. 9 5/8 1694 c.f. 5 208 c.f. Class "G" 10194-11592 10954'-10984', 11000'-11008', 11016'-11080', 11100'-11180', 11341'-11356' 8114-9197 true vertical subsea 8646'-8862' (five intervals) Tubing (size, grade, and measured depth) 5 1/2", 17#,NT13CR-80 NSCC tubing to 10196'MD Packers and SSSV (type and measured depth) 9 5/8" TIW 'HB-BP' big bore Packer@10143'MD,4-1/2" Otis SSSV@1999'MD 13. Stimulation or cement squeeze summary 14. See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Prior to well operation 4451 14520 5655 1480 Subsequent to operation 4210 8060 33 0 Tubing Pressure 382 334 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby .certify that the foregoing is true and correct to the best of my knowledge. Si~lned(~j~.~ ~?, ~~ Title SeniorTechnicalAssistant/ Form 10-404 Rev 06/15/88 SUBMIT IN DOPLI6ATE 8/19/91 WE LLM-11}(41-36-12-12) P BI, I NRWO/ReDerf/HvdraulicFracturinqO_Derations The following interval were reperforated using 3 3/8" gun diameter, 6 SPF random orientation and 60 degree phasing. 10954' 11008' MD 12/14/91 1 2/1 7/91 The following interval were reperforated using 3 3/8" gun diameter, 6 SPF random orientation and 60 degree phasing. 10954' 10994' MD Set Inflatable Bridge Plug. fjh 9/14/92 REEEIVED s EP 2 § 1992 Alaska 0il & Gas Cons. Commission Anchorage REPORT OF SUNDRY WELL OPEHATIONS Gl NA 1.Operations performed: Operation shutdown .. Stimulate Plugging ..... Perforate~ Pull tubing X Alter casing X Repair well X Other 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1606' SNL, 606' WEL, SEC. 01, T11N, R12E, UPM At top of productive interval 1096' SNL, 1158' WEL, SEC. 36, T12N, R12E, UPM At effective depth 758' SNL, 1080' WEL, SEC. 36, T12N, R12E, UPM At total depth 606' SNL, 1060' WEL, SEC. 36, T12N, R12E, UPM 5. Type of Well: Development Exploratory Stratigraphic Service L 6. Datum elevation (DF or KB) KBE =52.28' AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number M-16 (41-36-12-12) 9. Permit number/approval number 81-86/Conservation order 258 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11750 feet BKB 9319 feet 11508 feet BKB 9132 feet Plugs (measured) Junk (measured) 10. APl number 50- 029-20613 ,,, 11. Field/Pool Prudhoe Bay Field/Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length 1398' Size Fill to 11508' (7/23/91 ) Cemented Measured depth True vertical depth 8114'-9197' RECEIVED true vertical .. Tubing (size, grade, and measured depth) 5" 208 cu fl Class"G" 10194'-11592' MAY - 5 1992 Alaska 0il & Gas Cons. C0mmi$ ~,nchorage 5-1/2", 17#, NT13CR-80 NSCC tubing to 10196'MD Packers and SSSV (type and measured depth) 9-5/8" TIW 'HB-BP' big bore Packer @ 10143'MD, 4-1/2" Otis SSSV @ 1999'MD 13. Stimulation or cement squeeze summary Perforation squeeze- see attached Activity Summary 14. Intervals treated (measured) 10954'-10984', 11000'-11008', 11016'-11080', 11100'-11180°, 11341 '-11356' Treatment description including volumes used and final pressure 197 cu ft Class "G", final pressure = 600 psi Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run .... Daily Report of Well Operations x Re0resentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl . Casing Pressure Service 16. Status of well classification as: Oil x Gas .... Suspended D at e~-/',,,~ ~//~"Z SUBMIT IN DLIPI_(CATE J17. ! hereby certify that the foregoing is true a~:orrect to the best of my knowledge. Sign ed /~/~¢~./.4 _.~~ ~/'~1~,,~¢---- Title WorkoverEn~lineerSupervisor Form 10-404 Rev 06/15/88 ~P BP EXPLORATION DAILY WORKOVER REPORT: As of 0600 Hrs. Monday. July 15. 1991 WELL: M-16 (4,1-36~12-12~ (ALASKA), INC. PRUDHOE BAY UNIT Rig: Nabors Rig #3-S Day: .O. Expense AFE Number: Expense AFE Amount = .!45078 Current Field Costs = .Estimated Final Cost = Current Operation: Circulating Well Summary. of Last' 24 Hours MIRU. ACcept rig 0030 7-15-91o Circulate well. Reviewed By: ~, ~ RECEIVED MAY - 5 199~ Alaska 0il & Gas Cons. commissio~ Anchorage /~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. TU. esd~,y. July 16.1991 WELL: M-16 (41-36-12-12) PRUDHOE BAY UNIT Rig' Nabors Rig #3-S Day: 1 ExPense AFE Number: Expense AFE Amount = 145078 Current Field Costs = Estimated Final Cost = Current Oper.,3tion: POH Laying Down Jts Summary_ of Last. 24 Hours Puli B'PVinstall 2-way chech, NU 6" CIW, NU BOPE and test. RU to pull 5-1/2" tbg, puli tbg hanger. POH with 50 jts 5-1/2, tbg, LD SSSV. Continue POH. Reviewed By: ~~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday. July !7. 1991 WELL: M-16 {'41-:56.12-12) Rig: Nabors Rig #3-S Day: 2 Expense AFE Number: Expense AFE Amount = 145078 Current Field Costs = Estimated Final Cost = Current Operation' Circulating Summary of Last 24 Hour8 L/D 5-1/2" tbg & jewelry, test BOP's, PU fishing tool's RIH overshot 3-1/2" DP to 10,205. slick stick. POOH. Released Reviewed By: ~.,~.~ ~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Thursday. July 18. 1991 WELL: M-16 (41-~36-12-12~ PRUDHOE BAY UNIT Rig: Nabors Rig #3-S Day: 3 Expense AFE Number: Expense AFE Amount = 145078 Current Field Costs = Estimated Final Cost = Current Operation: Mill Packer Summary of Last' 24 Hours Circ pOoH recover PBR and "K" anchor. RIH L/D stretched pipe PU new,~[ag 9-5/8 packer @ 10224. Mill on packer. Reviewed By: ¢-. ~ ~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Friday. July 19. 1991 WELL: M-l(; (41-36-12-12~ PRUDHOE BAY UNIT Rig: Nabor8 Rig #3-S Day' 4 Expense AFE Number: Expense AFE Amount = 145078 Current Field Costs = Estimated Final Cost = Current Operation: . RIH Clean Out Liner Summary_ of Last 24 Hours Mill pkr, Circ out gas, POH L/D 9-5/8" pkr, RIH. Reviewed By: (~¢, F' BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Monday, July 22. 1991 WELL: M-16 (41-36-12-12~ PRUDHOE BAY UNIT Rig' Nabors Rig #3-S Day: Z Expense AFE Number: Expense AFE Amount = 145078 Current Field Costs = Estimated Final Cost = Current Operation: Circulating Summary of Last 72 Hours Clean out liner to 11,400,. Pump 25 bbls 15% HCL and overdisplace with 400 bbl seawater. Lay 170 sx balanced plug and squeeze to 2000 pis. Set storm packer. ND BOP and tubing spool. Replace 9-5/8" packoff. NU and test BOP and tubing spool. Recover storm packer. RIH 3-1/2" drill pipe tag cement @ 11095'. C/O cement to 11309 reverse circ hole clean. Reviewed By: BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Tuesday, July. 23, 1991 WELL: M-16 (41-36-12-12~ PRUDHOE BAY UNIT Rig: Nabor$ Rig #3-S Day: Expense AFE Number: Expense AFE Amount = 145078 Current Field Costs = Estimated Final Cost = Current Operation' Run 5" liner Summary_ of Last 24 Hours Clean out7" liner to 11505' junk, POH LD BHA RU and run 5" liner. Reviewed By: BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday. July 24. 1991 WELL: M-16 (41-36-12-12) Rig: Nabors Rig #3-S Day: 9 Expense AFE Number: Expense AFE Amount = 145078 Current Field Costs = Estimated Final Cost = Current Operation: Drilling out cement Summary_ of Last 2.4U.a.u.r.~ RIH with 5" liner, circulate. RU test lines to 4000 psi pump 35 bbls cement, 2 bbls water, dropped plug & displaced w/rig. Pump 88 bbls of brine. Cement in place. RIH tag cement at 10025'. Drilled out cement to top of liner. Reviewed By' ~:2~~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Thursday, July 25, 1991 WELL: M-16 (41-36-12-12~ PRUDHOE BAY UNIT Rig: Nabor~ Rig #3-S Day: Expense AFE Number: Expense AFE Amount = 145078 Current Field Costs = Estimated Final Cost = Current Operation: Circulate Su. mmary of Last.24 Hours Drilled out hard cement to 5" liner. POH LD bit & scraper, RIH to 10194'. Test liner & casing to 3000 pSi. RIH c/o stringers to 11510. Reverse circulate and change over to seawater. Reviewed By' ¢'~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Friday. July 26. 1991 WELL: M-16 (41-36-12-12~ PRUDHOE BAY UNIT Rig: Nabor~ Rig #3-S Day: 1 1 Expense AFE Number: Expense AFE Amount = ,1,45078 Current Field Costs = Estimated Final Cost = .CUrrent Operation: RIH with Packer Summary. of Last 2,4~ Reverse CircUlate & displace to clean seawater. POH LD drill pipe. RU to run 5-1/2" completion. RIH with 9-5/8" packer. Reviewed By: ~,~" BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Monday. July 29. 1991 WELL: M-16, (4!,-36-12-12) PRUDHOE BAY UNIT Rig: Nabor$ Rig #3-S Day: 14 Expense AFE Number: Expense AFE Amount = 145078 Current Field Costs = Estimated Final Cost = Current Operation: ~ Moved rig ~Summary of Last '72 Hours RIH 9-5/8" packer & jewelry on 5-1/2" tubing. ND BOPE, NU flange & test, NU test tree & control line to 5000 psi. RU circ' line & displace 150 bbis diesel. Released rig 1600 on 7-28-91. RD move rig, repair damage from over pull. Reviewed By: ¢'°~'''~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 // DATE: 04/03/92 T# 83365 BP CASED HOLE FINALS Enclosed is your copy of the materials li'sted below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-25 ~X--?gPROO-F 03/06/92 #1 Y-34 ~/..~ TE~ 03/06/92 M-16 GR 12/18/91 R-10~/--~~ LE~ DET 03/07/92 GAS LIFT SURVEY 03/11/92 X-02 ~--~ PROD-F 03./06/92 F-37~--~ LE~ DET 03/12/92 Y-14~-~GAS LIFT SURVEY 03/15/92 U-05~'/~ INJ 03/14/92 X-10~e--~GAS LIFT sURly 03/11/92 91 2850.00- 9900.00 C~CO 5 " 12350.00-12650.00 CAMCO 5 " 9000.00- 9575.00 CAMCO 5 " 10000.00-10996.00 CAMCO 5 " 500.00- 1980.00 CAMCO 5 " 609.00- 9295.00 CAMCO 2/5" 2850.00- 8700.00 CAMCO 2/5" 9550.00- 9927.00 CAMCO 5 " 0.00-10300.00 CAMCO 2 " 0.00- 9600.00 CAMCO 2 " 9050.00- 9400.00 CAMCO 5 " 2/5" 03/04/92 #1 13600.00-13886.00 CAMCO Information Control Well Records Adrian J. Martin RECEIVED APR 1 5 1992 Alaska 0ii & ms Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01/14/92 T# 83182 BP CASED HOLE FINALS Enclosed is your copy of the materials listed questionsj please contact BP Well Records at ~6 ~ CC~,/PE~ 01/06/92 #1 below. If you have any (907) 564-4004. 10800.00-11100.00'~TLAS 5 " l1300.00-11548.00'~ATLAS .~'" Information Control Well Records Adrian J. Martin JAN 2 2 19~Z ~aska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 12/19/91 T# 83129 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. PERF 12/14/91 #1 TUBING CUTTER 12/15/91 #1 CNL 12/13/91 #1 CNL 12/14/91 #1 PRODUCTION LOG 12/11/91 #1 10040.00-11446.00 SCH 9700.00- 9970.00 SCH 8790.00- 9394.00 SCH 10800.00-11246.00 SCH 10590.00-10815.00 SCH 5 " 5 " 5 " 5 " Information Control Well Records Adrian J. Martin RECEIVED DEC 26 1991 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 RECEIVED OCT 1 8 1991 Alaska Oil & Gas Cons. Commission Anchorage BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. . DATE: 10/10/91 T# 82910 PITS 09/20/91%1 10860.00 PITS 09/07/91 #1 10800.00 CCL 09/16/91 ~1 8650.000 CCL 09/16/91 #1 10131.00 CCL 09/25/91 #1 9000.000 GAS LIFT SURVEY 09/15/91 ~1 200.0000 PROD-F 08/13/91 #1 9550.000 GAS LIFT SURVEY 09/16/91 #1 5400.000 INJ 09/24/91 ~1 9150.000 CL 09/07/91 #1 9100.000 INJ 09/11/91 ~1 9800.000 PROD-F 08/24/91 ~1 11000.00 GR 09/11/91%1 14200.00 PROD-F 09/25/91 ~1 12450.00 LEAK DET 09/19/91 #1 2000.000 PROD-F 08/20/91 #1 10350.00 TEMP 09/15/91 #1 10275.00 PROD-F 08/24/91 #1 10350.00 CL 09/04/91 #1 10200.00 LEAK DET 08/23/91 #1 7992.000 LEAK DET 08/23/91 #1 11800.00 GAS LIFT SURVEY 09/04/91 #1 3200.000 PROD-F 09/25/91 #1 9250.000 PROD-F 09/15/91 #1 9800.000 CL 09/15/91 #1 9500.000 TEMP 09/03/91 #1 11800.00 PROD-F 08/26/91 #1 10850.00 GAS LIFT SURVEY 08/26/91 #1 2500.000 INJ 09/06/91 #1 10240.00 JEWELRY LOG 08/22/91 #1 CAMCO 5 JEWELRY LOG 08/21/91 #1 CAMCO 5 CAMCO 5 08/23/91 #1 10900. 12550. 9950.0 11444.00 CAMCO 5 11140 . 00 CAMCO 5 9240 . 000 CAMCO 5 12500.00 CAMCO 5 9755. 000 CAMCO 5 4000. 000 CAMCO 2 98~0.000 CAMCO 5 10986.00 CAMCO 5 9680 . 000 CAMCO 5 10941.00 CAMCO 5 10279.00 CAMCO 5 11480.00 CAMCO 5 15162.00 CAMCO 5 12685.00 CAMCO 5 11270.00 CAMCO 2/5 10720 . 00 CAMCO 5 10953.00 CAMCO 5 10660.00 CAMCO 5 10522.00 CAMCO 5 9062. 000 CAMCO 5 12553.00 CAMCO 5 8639. 000 CAMCO 5 9722. 000 CAMCO 5 10100.00 CAMCO 5 10224.00 CAMCO 5 12175.00 CAMCO 5 11150 . 00 CAMCO 5 9821. 000 CAMCO 2/5 10807 . 00 CAMCO 5 00 11758.00 00 13284.00 00 10120.00 BP EXPLORATION BP ExDiora~mn {AlasKa) Inc. 900 East Benson Boulevarcl PO. Box 196612 Ancnorac_e, Alaska -~95!9-6512 (907) 561-5111 DATE: 10/07/91 T9 82899 BP PRESSURE REPORTS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. H-24~ PRES 07/31/91 REF~ qq-2~ J-09 -- PRES 07/31/91 REF~ Y-30 ~ PRES 05/25/91 REF~ C-35v PRES 08/04/91 REF~ C-02~' PRES 07/31/91 REF~ F-17~ PRES 08/13/91 REF,% F-42~' PRES 09/04/91 REF~ J-03~ PRES 09/04/91 REF~ G-24~ PRES 09/03/91 REF,~ A-i6~' PRES 09/01/91 REF9 F-44 ~'" "'~PRES :'~':'09 /04/gI'""~--REF%~''~ ..... ~ : '~ F-45 -' PRES 09/02/9I REF~ ?-03 PRES 09/10/91 REF~ M-16~ PRES 08/26/91 REF9 F-03 ~- PRES 08/30/91 REF9 R-04~' PRES 08/26/91 REF~ G-11'~ PRES 08/31/91 REF.% W-11~ PRES 08/21/91 REF9 Z-28-- PRES 08/22/91 REF~ F-38~' PRES 09/06/91 REF9 G-26~ PRES 09/04/91 REF~ G_32,.~. PRES 09/04/91 REF~ G-05- PRES 09/03/91 REF~ B_32 ,~ PRES 09/15/91' REF~ F-24.- PRES 09/03/91 REE~ STATIC SURVEY HLS STATIC SURVEY HLS STATIC SURVEY HLS STATIC SURVEY HLS STATIC SURVEY HLS GRADIENT HLS BHP STATIC CAMCO BHP STATIC CAMCO BHP STATIC CAMCO BHP FLOW CAMCO BHP STATIC CAMCO BHP STATIC CAMCO BHP FLOW CAMCO BHP STATIC CAMCO BHP FLOW CAMCO BHP STATIC CAMCO BHP STATIC CAMCO BHP STATIC CAMCO BHP STATIC CAMCO BHP STATIC C~4CO BHP STATIC CAMCO BHP STATIC CAMCO BHP STATIC CAMCO BHP STATIC C~MC0 Information Control Well Records Adrian J. Martin BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date:08/27/91 T~'~2771 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the matedai listed below. Well Records at (907) 564-~.~.45. N-14 COMPLETION 08/21/91 #1 M-16 PERF 08/19/91 #1 U-13 COMPLETION 08/20/91 # 1 M-04 PERF 08/19/91 #1 M-04 GR,CCL 08/19/91 #1 If you have any questions, please contact BP 9438-9688 $CH 5" 10140-11100 SCH 5" 11050-11319 SCH 5" 11250-11550 SCH 5" 9430-11568 SCH 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 08/07/91 T#:82721 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the matedal listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. a-01 ' COLLAR 08/04/91 #1 8690-9002 ATLAS a-01 '- CCL/GR 08/04/91 #1 7650-9188 ATLAS B-14- COLLAR 08/01/91 #1 11510-11934 ATLAS M-04.' TUBING CU'I-I'ER 07/24/91 #1 9312-9464 ' ATLAS M-16- CCL/GR 08/03/91 #1 10020-11462 ATLAS R-18-, PFC/GR 08/01/91 #1 9050-10044 ATLAS R-27~ COLLAR 08/03/91 #1 8970-9738 ATLAS X-03 -- COLLAR 07/29/91 #1 11690-11887 ATLAS 5" 5" 5" 5" 5" 5" 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES BP EXPLORATION RECEIVED BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :05123/90 T#:81169 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the matedal listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. C-12 CNL/GR 05/14/90 #4 11100-11958 SCH 5" M-16 PROD-F 05/15/90 #1 10800-11520 SCH 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS ARCHIVES BP EXPLORATION HOUSTOR ARCO Cl~-~ON EXXON ,, , TEXACO TO: MOBIL · PHILLIPS STATE OFALAS~ GEOSCIENCES RESERVOIR REFERENCE: BP'CASED HOLE FINAL LOGS BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, ~laska 99519-6612 (907) 561-5111 Da*e: 06-20-89 T~: 80129 The following materlal is being subml't-i'ed herewith, Please acknowledge receipt by signing a copy of this leti'er and returning It to thls office: ' C-10 REPERF 06-12-89 #1 10100-11889 Sch 5" G-07 REPERF 06-11-89 #1 11000-11355 Sch 5" M-16 PERF 06-10-89 #1 10100-11549 Sch 5" .L Rece i ved Date _ CEV ~,' Naska u, ~k uas ~ons. C0mmissio~ ; Anchorage Shirley R. McCurry INFORMATI ON CONTROL We I I Records LR2- I BP EXPLORATION ORIGINAL BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 20, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well M-16 (41-36-12-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. Yours very truly, B. J. Policky Supervisor Waterflood & Miscible Flood BJP:JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File JUN £ 1 1.989 Alaska Oil & Gas Cons. ~ncborage 'STATE OF ALASKA .~SKA OIL AND GAS CONSERVATION COMM~,.,,.,~ON REPORT OF SUNDRY WELL OPERATIONS '"1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1606' SNL, 606' WEL, SEC. 01, T11N, R12E, UPM At top of productive interval 1096' SNL, 1158' WEL, SEC. 36, T12N, R12E, UPM At effective depth 895°SNL, 1073' WEL, SEC. 36, T12N, R12E, UPM At total depth 606'SNL, 1060' WEL, SEC. 36, T12N, R12E, UPM 12. Present well condition summary Total depth: measured 11750 feet true vertical BKB 9319feet Repair well 5. Type of Well: Development .~L Exploratm7 .... Stratigraphic Service Plugs (measured) Other__ 6. Datum elevation (DF or KB) KBE = 52.28 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number M-16 (41-36-12-12) PBU 9. Permit number/approval numl~er 81-86 / 9-290 10. APl number 5O- O29-2O613 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 11585feet true vertical BKB 9192feet Junk (measured) junk in hole (20'perf gun) Casing Length Structural -- Conductor 110 Surface 2709 Intermediate 10762 Production -- Liner 1436 Perforation depth: measured Size Cemented Measured depth True vertical depth BKB 134 134 2733 2671 10786 8565 20x30 8 c.y. 13 3/8 3767 c.f. 9 5/8 1694 c.f. 7 456 c.f. 10314-11750 10954'-10984', 11000'-11008', 11016'-11080', 11100'-11180', 11341'-11356' 8203-9319 true vertical subsea 8646'-8862' (five intervals) Tubing (size, grade, and measured depth) 5 1/2" L-80 to 10211'with 4 1/2" tailpipe to 10365' 13. Stimulation or cement squeeze summary ..~ ~. ~ ~.~Cj Intervals treat~:l (measured) Treatment description including volumes used and final pressure j~las~a Oit & Gasj~nc~O~,aO~e,cOns' Com~'tssiOa 14. Reoresentative Daily Averaee Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4920 7268 1703 0 261 Subsequent to operation 4910 6803 2477 15. Attachments 16. Status of well classification as: .Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 0 257 Service T' Title Supervisor Waterflood/Miscible Flood Date SUB ,T,N )UP',O^TE WELL M.16 (41-36-12-12~ PBI! ADD*L. PERFORATION OPERATIONS The following additional interval was perforated June 10, 1989 using Schlumberger 3 3/8" carrier guns at 4 spf: 11341' - 11356' MD BKB (Ref. BHCS, 9/29/81) A lubricator was installed and tested to 3500 psi for all well work. The well was returned to prodction immediately following perforating operations, then tested. jm 5/15/89 RECEIVED JUN 2 t 1989 Alaska 0il & Gas Cons, CommissJo~ Anchorage BP EXPLORATION April 13, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well M-16 (41-36-12-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. Yours very truly, ~ /~ Supervisor Waterflood & Miscible Flood BJP:JAM Enclosures (9) cc: L. Burke (MB12-1) Well File STATE OF ALASKA ~L ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Aller ca~ng Repair well__ 2. Name of Operator 3. Address P. O. Box lg6612, Anchorage, Alaska g951g-6612 4. Location of well at surface 1606' SNL, 606' WEL, SEG. 01, T11N, R12E, UPM At top of productive interval 1096' SNL, 1158' WEL, SEC,. 36, T12N, R12E, UPM At effective depth 895' SNL, 1073' WEL, SEC. 36, T12N, R12E, UPM At total depth 608' SNL, 1080' WEL, SEC. 36, T12N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical BKB Operal~on Shutdown . Plugging ~ Pull tubing __ Variance__ 5. Type of Well: Development x . Exploratory Slmligraphic Servioe 11750 feet Plugs (measured) 9319 feet Re-enter suspended well .. Time extension slimulate" Per,rate x Other 6. Datum elevation (DF or KB) KBE = 52.28 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number M-16 (41-36-12-12) PBU 9. Permit number 81-86 10. APl number 50- 029-20613 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 11585 feet true vertical BKB 9192 feet Junk (measured) junk in hole (20'perf gun) Casing Length Structural -- Conductor 110 Surface 2709 Intermediate 10762 Production -- Liner 1436 Perforation depth: measured Size Cemented Measured depth True vertical depth BKB 134 134 2733 2671 10786 8565 20x30 8 c.y. 133/8 3767c. f. 9 5/8 1694 c.f. 7 456 c.f. 10314-11750 I0954'-10984', 11000'-11008', 11016'-11080', 11100'-11180' 8203-9319 true vertical subsea 8646'-8824' (four intervals) Tubing (size, grade, and measured depth) 5 1/2" L.80 to 10211' with 4 1/2" tailpipe to 10365' ~ ~ ~-. Packers and SSSV (type and measured depth) 9 5/8" BO T packer at 10211"5 1/2" SSSV at 2140' ~-~'~'~'~ .Oil.& 6as Cons. ~chnr~na 13. AE~hments Description summa~ of pm~sal x Detailed operations program ~ BOP sketch --~ 14. Estimated date for commencing operation 15. Status of well classification as: April 1989 16. If proposal was verbally approved Oil X Gas __ Suspended Name'of approver Date approved Service 17. I hereby certify that the foregoing is tru~'~nd correct to the best of my knowledge. ,,,,~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness J Approval No. ~.~ Plug integrity BOP Test Location clearance , , _, r,_onV I /~ ~',/,'-' Mechanical Integrity Test -Subsequent form required 10'-~--/~/--~ppro'/a.~_~"'~ - ORIGINAL SIGNED BY Ret, u,,~,~ .......... ~mmissioner Date ~ Approved by order of the Commission 10NNIE C. SMITH ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL M.16 ¢41-36.12-12~ PBU ADD~L. PERFORATION PROPOSAL We propose to perforate the following additional interval during April 1989: 11341' - 11356' MD BKB (Ref. BHCS, 9/29/81) A lubricator will be installed and tested to 3500 psi for all well work. The well will be returned to prodction immediately following perforating operations, then tested. jm 417189 BOWEN PACKOFF FLOW TUBES & PACKOFF ~-' HAND GREASE SEAL FLOWTUBE PUMP FLOWLINE GREASE LINE~ FLOWLINE VALVE GREASE )///~ -MANIFOLD RISER ,..-GREASE RESERVOIR BOP Pr o'duc I'~ofl Company - 900 Eo'd Bern, off 8oufe,,o,d PO 843, 19661~ A~(ho~oge. AIo~&o 99519-0,01~ (9071 J,64..~11 I TO: HOUSTON ARCO CHEVRON ET~XON TEXACO MOBIL PHILLIPS sTA~E'~SF'~sKA ARCHIVES I NOEXED ,, _ STANDARD ALASKA PRODUCTION Date: 10/10/88 r;: 79398 REFERENCE: SAPC FINAL'DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt signing e copy of thls letter and returning it to this offlce: ¢-13 C-18 D-07 D-15 E-08 F-01 : G-01 G-07 H-28 J-13 K-03 K-09 N-01 N-02 'M-05 M-16 R-lO U-04 U-05 Y-19 Z-14 Z-15 Static 09/24/88 GO Static 09 / 24 / 88 GO Static Gradient 09 / 25 / 88 0tl~ ~c Gradient 09 / 25 / 88 Otis Static Gradient 09/25/88 Camco S~z~.c 09 / 2.6 / 88 GO Sta~c G~adient 09 / 24 / 88 Camco Static Gradient 09 / 24 / 88 Camco ~¢ 09/25/88 GO ~c Gradient 09 / 22 / 88 Camco Sta~c G~adient 09 / 28 / 88 Camco Static Gradient 09 / 22 / 88 Camco Static Gradient 10 / 03 / 88 Camco Static G~_dient 10/02/88 Camco Static Gradient 09/30/88 Camco Flowing Gradient 10 / 03 / 88 Camco Static Gradient 09/28/88 Camco Static Gradient 10 / 02 / 88 Camco StSc Gradient 10/02/88 Camco Static Gradient 09/30/88 Camco Ini~ S~t~c Gradient 09/30/88 Sta~c Gradient 09 / 29 / 88 Camco Received Da te Fot;,~cied o, o,..,,,..,, ~nch0mge Jenni f er Dietz I NFCXRMAT ! ON CONTROL Wel I Records ER2-1 .~londo~d AIo ~sl~ o Pfo, du¢ I;on Company 9'00 [o~,! ~'n~on P.O. Bo. 196612 Anchorage. AIosLo 9~19-6612 1907) .~64-51 I I INDEXED TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL __.~PHILLIPS ARCHIVES STANDARD ALASKA PRODUCTION Date: 06/01/88 TI: 78888 REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this leYfer and Feturnlng It to thls office: A-25 F-24 G-26 M-9 M-16 M-18 M-25 N-16 N-17 R-13 R-19 $-7 U-6 U-7 Flowing Gradient 05/22/88 Camco ,, " " 05/09-11/88 Camco Static Gradient 05/18/88 Static Gradient 05/17/88 Camco " 05/24/88 " " 05/22/88 " " 05/17/88 " " o5/17/88 " " o5/16/88 " " 05/20/88 " " 05/20/88 " Flowing Gradient 05~17/88 " Static Gradient 05/20/88 " " " 05/20/88 " /~A1n,f'~a Oil & G,~s Received Date Victoria Aldridge INFORPtATION CONTROL Well Records LR2-1 900 Eo',t I~'n.,on PO Bo,, 19661? An(ho,.oge. AIo,I,O 99.5 (907~ ~64-~ I ! I INDEXED DALLAS ~co STANDARD CHEVRON AL ASKA PRODUCT ION EXXON Date: 01/12/88 TEXACO TO: T#: 78429 MOBIL PHILLIPS STATE OF ALASKA REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by slgnlng a copy of thls letter and returning It to thls office: ~ M-25 ~-- N-6 -----. N-7 '~' R-ii -"~ R-15 '-"-- S-2 ~ S-5 Static Survey 01/03/88 GO static Gradient 01/05/88 Camco Static Survey 01/03/88 GO Static Survey 01/01/88 GO Static Survey 01/2-3/88 Camco Static Gradient 01/02/88 Camco Static Gradient 01/03/88 Camco Static Gradient 01/01/88 Camco Static Gradient 12/30/87 Camco Race I red Date A un., ot the o,,,9.nol Stondo,d (~t Co,',puny I~ounded ,n Cle-elond. Oh,o. ,n 1870 Victoria Aldridge I NFORMAT I ON CONTROL Wel I Records LR2-1 Standard Alaska ~,,~ ~' Production Compar~ 900 East Benson Bou%~ .,rd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION October 16, 1987 Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well M-16 (41-36-12-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB:JAMJ9~ ragg v~ visor Production Operations Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 M-16 Well File A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator STANDARD ALASKA PRODUCTION COMPANY 3. Address P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 1606' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM At top of productive interval 1096' SNL, 1158' WEL, Sec. 36, T12N, R12E, UPM At effective depth 632' SNL, 1063' WEL, Sec. 36, T12N, R12E, UPM At total depth 606' SNL, 1060' WEL, Sec. 36, T12N, R12E, UPM 5. Datum elevation (DF or KB) KBE = 52.28 6. Unit or Property name Prudhoe Bay Unit 7. Well number M-16 (41-36-12-12) PBU 8. Approval number 7-575 9. APl number 50--029-20613 10. Pool Prudhoe Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical 11750 feet Plugs (measured) 9319 feet BKB Effective depth: measured 11710 feet Junk (measured) true vertical 9288 feet BKB Casing Length Size Cemented Structural __ Conductor 83' 20"x30" 8 cu. yds. Surface 2705' 13 3/8" 3767 c.f. Intermediate 10758' 9 5/8" 1694 c.f. Production -- Liner 1436' 7" 456 c.f. Perforation depth: measured 10954, - 11180' (four interVals) true vertical (ss) 8646' - 8824' Tubing (size, grade and measured depth) 5 1/2" L-80 to 10211' with 4 1/2''~ tailpipe to 10365' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 10211'; 5 1/2" SSSV at 2140' Measured depth 110 ' 2733' 10786 ' 10314'-11750' True Vertical depth BKB 110 ' 2671' 8565' 8203'-9319' 12. Stimulation or cement squeeze summary See attaChment Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 4090 3336 1237 Casing Pressure 0 0 3640 2406 1422 Tubing Pressure 227 232 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge I Signed ~ Title Supervisor Production Operations Submit in Dupl c'at~/ Well M-16 (41-36-12-12) PBU STIMULATION OPERATIONS A combination EDTA/scale inhibitor treatment was performed September 19, 1987 on the following perforated intervals in Well M-16. 10954' - 10984' MD BKB 11000' - 11008' MD BKB 11016' - 11080' MD BKB The intervals that were treated were isolated from the lowermost interval by setting an inflatable bridge plug at 11088' MD BKB. The bridge plug was removed following the completion of the treatment. The treatment fluids consisted of the following: 20 bbls. diesel preflush w/mutual solvent 20 bbls. EDTA 24 bbls. EDTA w/diverter 97 bbls. EDTA 127 bbls. scale inhibitor solution 5'12 bbls. effluent water overflush The treatment fluids were displaced to the perforations with 256 bbls. dead crude.· The well was left shut in for 24 hours, then returned to production and tested. jm 10/13/·87 Standard Alaska _,,~ Production Compa~ 900 East Benson Boc~. ,rd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907i 561-5111 August 27, 1987 STANDARD ALASKA PRODUCTION'" Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well M-16 (41-36-12-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, jAB:jAM'~~ Enclosures (9) cc: J. L. Haas (MB12-1) M-16 Well File . A Bragg/~~ ~~r Production Operations RECEIVEO Alaska Oil & Gas Cons. Commissior~ Anchorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. ALA~:iIr: STATE OF ALASKA CO~i.,ISsl .A OIL AND GAS CONSERVATION ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 52.28 feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 1606' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM 7. Well number M-16 (41-36-12-12) PBU At top of productive interval 1096' SNL, 1158' WBL, Sec. At effective depth 632' SNL, 1063' WEL, Sec. At total depth 606' SNL, 1060' WEL, Sec. 36, T12N, R12E, UPM 36, T12N, R12E, UPM 36, T12N, R12E, UPM 8. Permit number 81-86 9. APl number 50--029-20613 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11750 feet 9319 feetBKB 11710 feet 9288 feetBKB Plugs (measured) Junk (measured) Casing Length Size Structural -- Conductor 83 ' 20 "×30" Surface 2705 ' 13 3/8" Intermediate 10758' 9 5/8" Production -- Liner 1436 ' 7" Perforation depth: measured 110954' - 11180' true vertical (ss) 8646' - 8824' Cemented 8 cu. yds. 3767 c.f. 1694 c.f. 456 c.f. (four intervals) Tubing (size, grade and measured depth) 5 1/2" L-80 to 10211' with 4 1/2" tailpipe to 10365' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 10211'; 5 1/2" SSSV at 2140' Measured depth 110' 2733' 10786' 10314 ' -11750 ' True Vertical depth B~ 110 ' 2671' 8565 ' 8203'-9319' RE'CEIYED 0il & 6as O0~s. C0mm;ss Anchorage 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation August 1987 14. If proposal was verbally approved Name of approver Date approved 15.,I hereby certify that t,he fOregoing is true and correct to the best of my knowledge . A. Bragg ~ Commission Use Only Conditions of approval Notify commission so representative may witness ~ Approval No. ~ ~ Q Plug integrity Q BOP Test Q Location clearancel Approved by Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Well M-16 (41-36-12-12) PBU STIMULATION PROPOSAL A combination EDTA/scale inhibition squeeze is proposed for the following perforated intervals in Well M-16. 10954' - 10984' MD BKB 11000' - 11008' MD BKB 11016' - 11080' MD BKB The intervals to be treated will be isolated from the lowermost interval by setting an inflatable bridge plug +11090' MD BKB. The bridge plug will be removed following the completion of the treatment. The treatment fluids consist of the following: 20 bbls. diesel preflush w/mutual solvent 20 bbls. EDTA 20 bbls. EDTA w/diverter 105 bbls. EDTA +150 bbls. scale inhibitor solution 510 bbls. filtered seawater overflush The treatment fluids will be displaced to the perforations with diesel. The well will be left shut in for 24 hours, then returned to production and tested. 'Alask~ Oil & Gas Co~s, Commiss~ Ar~chorage jm 8/17/87 Coiled Tubing Blow-Out-Preventers ~iled Tubing Pack-Off* Blind Rams Cutter Rams Chicksan (Kill Line) Pipe Rams Pump-In Sub (Circulate/Re turns) W ell Head Swab Valve Standard Alaska /,!~ Produ¢lion Company,' 900 Eas.t Bens, on Bouie~, d P.O. Box 196612' Anchorage. Alaska 99519-6612 1907) 564-5111 TO: DALLAS ARCO CHEVRON EXXON TEXACO HOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES * RESERVOIR * DRILLING REFEREI~E: SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PRODUCTION Date: 07/14/87 TI: 78041 The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this lette~ and returning It~othls office: B-12 Production Log 07/09/87 B-13 DFT/Borehole Audio Tracer SurVey E-II CCL/Perf. 06/04/87 F-24 Temp. 06/02/87 F-29 CCL/Perf. 06/03/87 F-31 CCL/Perf. 06/03/87 M-16 Hydro 06/10/87 M-16 CFS 06/10/87 M-16 GR 06/10/87 U-4 CCL/Perf. 06/06/87 U-5 GR 06/02/87 #1 8850-9427 Sch 5" 06/10/87 #1 1800-10730 #1 9450-10753 GO 5" #1 11800-12315 GO 5" #1 9950-10215 GO 5" #1 9200-9500 GO 5" #1 10900-11460 GO 5" #1 10850-11580 GO 5" #1 10900-11575 GO 5" #1 10800-11700 GO 5" #1 8580-9400 GO 5" 5II * ONLY this log is being sent to Reservoir & Drilling. "' t I~§/L/ Victoria Aldridge Dote ~/" / - _ ...... o~.. P. nmmi.~[OI1 Nell Records LR2-1 Founded in Cleveland. Oh~.~O. Standard Alaska Produ¢lion Company 900 Eost Ben,,on I~)ul/ P,O. I~x 196612~ Ancho~oge. Alosko ~519-~12 TO: DALLAS CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALAS~ INDEXED STANDARD ALASKA PRODUCTFON Date: 06~08~87 TI: 77955 .- REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The followingmaterlal is being submitted herewith. Please acknowledge.receipt by signing a copy of this letter and returning it to this office: "~:~;::::: Static Gradient 05/29/87 Camco M-21 Static Gradient 05/26/87 Camco N-19 Static Gradient 05/27/87 Camco R-16 Static Gradient 05/26/87 Camco Rece l ved ria Aldridge ~ /,~- ' _' ~k._~__ 'NFORHATION CONTROL Date ~:- Oil& Gas Con. Commission . Well Records LR2-1 Anctlorage Founded in C~veln.d. ~,o. ,n TO: DALLAS A~CO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES (Transmittal Only) INDEXED STANDARD ALASKA PRODUCTION Date: O1/08/87 T~: 77647 Page 1 of 2:! REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please ackncr~ledge receipt by signing a copy of this letter and returnlng it to this office: ~A-1 Static Gradient 12/28/86 Camco ~A-5 " " 12/28/86 Camco ~'A-22 " " 12/25/86 " ~A-26 Static 12/22/86 GO -'-A-29 Static " 12/26/86 Camco ~-A-30 Static 12/23/86 GO ~A-32 " " 12/23/86 Camco '""A-35 " " 12/25/86 " ~'~-B-1 " " 12/27/86 " -~"-C-15 Static 01/02/87 GO --"'-C-32 " 01/02/87 GO -~'~-D-9 " 12/30/86 " ~D-10 " 12/30/86 GO ~'~G=30 " 11/24/86 Camco ~M-4 " " 12/11/86 Camco ~M-IO Static Survey 12/11/86 GO ''"'M-16 Static Survey ' 12/11/86 GO ~M-19 Static Gradient'-' 12/12/86 Camco ~M-21 Static Gradient 12/11/86 Camco ~N-7 " " 01/02/87 Camco ~N-9 " " ~ 12/13/86 Camco 'N-15 " " 12/12/86 Camco '~- N-18 Static Survey 12/12/86 GO ~'~--N-19 Static S/u.~y /z'-') 12/12/86 GO ' ~ / '.~C~C;: ~ bas vvn~. Wel I Records LR2-1 Founded ,,, (le,elo,,d fq,)~,*m...,* IM70 t NOEXED DALLAS ARCO SI'ANDARD CHEVRON ALASKA PRODUCTION EXXON Date: 01/08/87 TEXACO TO: TI: 77647 MOBIL PHILLIPS :. Page 2 of 2!! STATE OF ALASKA REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following materiel is being submitted herewith. Please acknowledge receipt by slgnlng a copy of thls le~-fer end returnlng It to thls office: ~R-1 Static Gradient 12/14/86 Camco -'-~R-16 " " 12/14/86 " ~ R-19 " " 12/13/86 " --- R-23 " Survey 12/15/86 GO -~" S-1 Static Gradient 12/17/86 Camco ~S-2 " " 12/17/86 Camco ~-S-10 " Survey 12/19/86 GO ~S-10. " Gradient 12/16/86 Camco ~ S-13i Static Survey 12/14/86 GO ~'"~-19 " Gradient 12/05/86 Camco ~-S-20 " " 12/07/86 Camco "'-X-2 " " 12/26/86 Camco ~X-5 " " 12/20/86 Camco ~ Y-2 " " 12/20/86 Camco ~ Y-8 Static 12/07/86 GO PLS-P=es. Survey 11/04/86 Dres ~'3 ~-~ , Received ~ Date ...... r~l ~ GaS COt'r3, C0mm~s~(~l Victoria Aldridge INFORHAT I ON CONTROL Wel I Records LR2-1 Standard Alaska ~~ Production Cam ~1~ 900 East ~enson ~. .ard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 30, 1986 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well M-16 (41-36-12-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB: JAM ~ Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 M-16 Well File rvisor Production Operations RECEIVED Nov 0 B86 ~,~1. 0il & k~~oe~~ A unit of the or,ginal Standard Oil Company Founded in Cleveland Ohio in 1870. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ~ Perforate ~ Pull tubing Alter Casing ,___ Other~ .~ 2. Name of Operator STANDARD ALASKA PRODUCTION COMPANY 3. Address P. O. BOX 196612, ANCHORAGE, ALASKA 4. Location of well at surface 99519-6612 5. Datum elevation (DF or KB) KBE = 52.28 Feet 1606' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM At top of productive interval ,,, 11. Present well condition summary Total depth: measured true vertical 6. Unit or Property name Prudhoe Bay Unit 7. Wellnumber M-16 (41-36-12-12) PBU 8. Approval number 271 9. APl number 50--029-20613 1096' SNL, 1158' WEL, Sec. Ateffective depth 632' SNL, 1063' WEL, Sec. Attotaldepth 606' SNL, 1060' WEL, Sec. 36, T12N, R12E, UPM 36, T12N, R12E, UPM 36f T12Nf R12E~ UPM 10. Pool Prudhoe Oil Pool 11750 feet Plugs (measured) 9319 feet BKB Effective depth: measured true vertical 11710 feet Junk (measured) 9288 feet BKB 12. Casing Length Structural -- Conductor 83 ' Surface 2705 ' I ntermed iate 10758' Production __ Liner 1436 ' Perforation depth: measured 10954' - 11180' Size Cemented Measured depth True Vertical depth BKB 20"x30" 8 cu.yds. 110' 110' 13 3/8" 3767 c.f.. 2733' 2671' 9 5/8" 1694 c.f. 10786' 8565' 7" 456 c.f. (four intervals ) true vertical (subsea) 8646' - 8824' TUbing (size, grade and measured depth) 5 1/2" L-80 to 10211' with 4 1/2" tailpipe to 10365' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 10211'; 5 1/2" Otis SSSV at 2140' Stimulation or cement squeeze summary See attachment Intervals treated (measured) Treatment description including volumes used and final pressure 10314'-11750' 8203'-9319' RECEIVED Alalka 0il & ~ ~:;~,',~..~. ~,~,¥,missi0n 13. Prior to well operation Subsequent to Operation Representative )aily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2150 1563 2110 1717 1920 1394 2000 1714 Tubing Pressure 233 208 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-40~Rev. 12-1-85 Title Supervisor Production Operations Date/0 °30.~ Submit in Duplicate Well M-16 (41-36-12-12) PBU STIMULATION OPERATION A combination 278-bbl. EDTA/174-bbl. scale inhibitor squeeze via coiled tubing was performed October 14, 1986 on the following perforated intervals in Well M-16. 10954' - 10984' MD BKB 11000' - 11008' MD BKB 11016' - 11080' MD BKB 11100' - 11180' MD BKB The well was left shut in for 24 hours following the treatment, then put back on production and tested. jm 10/24/86 RECEIVED NOV 0 1986 Oil & 8aS Cons. Commission Anchorage Standard Alaska f~ Production Company ~i 900 East Benson Boulev~, P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 July 21, 1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Well M-16 (41-36-12-12) PBU Gentlemen: Enclosed, in triplicate, is Approvals, for the above-named stimulate the well. Form 10-403, Application for Sundry well. This contains our proposal to Yours very truly, JAB: JAM ~ Enclosures (g) cc: J. L. Haas (MB12-1) M-16 Well File A. Bragg pervisor Production Operations A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. AL/'A~" STATE OF ALASKA f OIL AND GAS CONSERVATION CO~ ,SION APPLICA! ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon F' Suspend - Operation Shutdown - Re-enter suspended well _~ Alter casing -- Time extension- Change approved program _-- Plugging ~. Stimulate :~ Pull tubing- Amend order ~ Perforate- Other 2. Name of Operator 5. STANDARD ALASKA PRODUCTION COMPANY 3. Address 6. P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 7. 1606' SNL, 606' WEL, Sec. '01, TllN, R12E, UPM At top of productive interval (top Ivishak/Sadlerochit) 1096' SNL, 1158' WEL, Sec. 36, T12N, R12E, UPM At effective depth 632' SNL, 1063' WEL, Sec. 36, T12N, R12E, UPM At total depth 606' SNL, 1060' WEL, Sec. 36, T12N, R12E, UPM Datum elevation (DF or KB) BE = 52.28 feet Unit or Property name Prudhoe Bay Unit Well number M-16 (41-36-12-12) PBU 8. Permit number 81-86 9. APl number 50-- 029-20613 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 11750 feet Plugs (measured) 931'9 feet BKB Effective depth: measured true vertical 11710. feet Junk (measured) 9288 feet BKB CaSing Length Structural ,- Conductor. 83 Surface 2705' Intermediate 10758 Production __ Liner 143.6 Perforation depth: measured 10954' - 11180' Size Cemented Measured depth True Vertical depth 20"x30" 8 cu.yds. 110' 110' 13 3/8" 3767 c.f. 2733' 2671' 9 5/8" 1694 c.f. 10786' 8565' 7" 456 c.f. (.four intervals) true vertical (subsea) 8646' - 8824' Tubing (size, grade and measured depth) 5 1/2" L-80 to 10211' with 4 1/2" tailpipe to 10365' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 10211': 5 1/2" 12.Attachments 10314'-11750' 8203'-9319' Description summary of proposal [~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation July/August 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge SiCd~~~. ~agg~~ CommissionTitle SuperviSOruse OnlyPr°ducti°n Operations Date 7. z/- Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Form 10-403 Rev 12-1-85 ~ ~' IApproval c~ ~,/ No. by order of the commission Date Submit in triplicate Well M-16 (41-36-12-12) PBU STIMULATION PROPOSAL A combination 260-bbl. EDTA/173 bbl. scale inhibitor squeeze via coiled tubing is proposed for the following perforated intervals in Well M-16. 10954' - 10984' MD 11000' - 11008' MD 11016' - 11080' MD 11100' - 11180' MD The well will be left shut in for 24 hours following the treatment, then put back On prodUction and tested SOHIO ALASKA PETROLEUM COMPANY /- PAGE ~ OF~ PETROLEUM SUBJECT: ENGINEERING OPERATIONS MANUAL REVISION NO. DATE '~- ,~ 2'-~c~- PREPARED BY: /'~' ~ '~-'"/~ 7'-/,,<.,/ APPROVED BY: INDEXED TO: DALLAS A~CO STANDARD C~EV~0N ALASKA PRODUC'[ ION EXXON D~te: 06/25/86 TEXACO TI: 77147 MOBIL PHILLIPS STATE OF ALASKA Page I of 2!! GEOSCIENCES REFERENCE: SA]PC FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by slgnlng a copy of this lel-ter and returning It to this office: A-26 '~ BHP Survey A-29 ~" " A-31 "-~D A-31 ~BH Pres. Survey A-33 '-BHPD &"PBU A-33 ~Static Gradient A-34A ~PBU A-34A ~BHPD F-17 ~static Gradient F-24 tatic Gradient J-3 ~'~tatic Gradient K- 8 ."-BHPD '~-~P BU M-10 X~Stat ic Gradient M-16 ~" " M-19 '~" " M-21 ~" " M-24 ~'~' '" N-7 "~,survey N-15 %~" Gradient N-18 N-19 ~--" " R-13 ""*" " R-16 ~., R-19 " R-23 '~"BHPD &~PBL' 05/28/86 Otis 05/29/86 Otis 05/11/86 Dres 05/09-11/86 Dres 06/03/86 GO 06/11/86 Camco 05/19-20/86 Camco 05/20/86 Camco 06/04/86 Camco 06/06/86 Camco 06/13/86 Camco 04/26/86 Otis 04/19/86 Otis 06/06/86 Camco 06/02/86 Camco 06/03/86 Camco 06/08/86 ~o 06/08/86 Camco 05/24/86 GO 05/31/86 Camco 06/05/86 Camco 06/05/86 Camco 06/10/86 Camco 06/11/86 Camco 06/07/86 Camco 05/21/86 GO Static Gradient II INFORMATION CONTROL Wel I Records LR2-1 Date: 06/25/86 T#: 77147 Page 2 of 2!! R~BHPD & Flowing Gradient S-16 _~'Static Gradient 05/27/86 U-2 ~ " " 06/01/86 U-10%BH~D ~Flowing Gradient U-12 ~'Static Gradient 05/27-28/86 -~22-11-12 Static Gradient 03/16/86 05/13/86 Camco Camco 06/01/86 Camco Camco Camco Camco Oil & Gas Cons. ¢ommissi,~: Anchorage Victoria Aldridge LR2-1 Well Records LR2-1 INDEXED SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON To:SFO/UNIT/STATE: TEXACO (-Marathon) MOBIL PHILLIPS . STATE BPAE (Transmittal Only) 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE {907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 1-08-86 T#: 76682 REFERENCE: SOHIO FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- '~--Tg~ i2-21-85 Static Gradient Camco /'?.'A~i'4 12-23-85 Static Gradient Camco / C-20 12-21-85 Static Gradient Camco ~'B-24 12-22-85 Static Gradient Camco /H-6 12-25-85 Static Gradient Camco /M-5 12-18-85 Static Gradient Camco /M-16 12-19-85 Static Gradient Camco ?M-21 12-20-85 - Static Gradient Camco zR-10 12-15-85 Static Gradient Camco ..R-10 12-15-85 Static Gradient Camco ~-13 12-18-85 Static Gradient Camco ~R-19 12-17-85 Static Gradient Camco /X-2 12-20-85 Static Gradient Camco ,zY-12 12-25-85 Static Gradient Camco ,/Y-13 12-24-85 Static Gradient Camco RECEIVED DATE 19 Cathy Perkins LR 2-1 Technical Documentation Records Management INDEXED -- SOHIO ALASKA PETRt~LEUM COMPANY SY0 ARCO CHEVRON EXXON TO:SFO/UNIT/STATE: TEXACO (-Marathon) MOBIL PHILLIPS STATE BPAE (Transmittal Only) 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 08/26/85 T#: 7 6403 REFERENCE: SOHIO FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- M-5 Static 08/11/85 'Camco M-10 Static 08/16/85 Camco M-16 Static 08/11/85 Camco M-19 Static '08/19/85 Camco M-21 Static 08/15/85 Camco N-9 Static 08/13/85 Camco N-18 Static 08/17/85 Camco R-8 Static 08/16/85 Camco R-9 Static 08/08/85 Camco R-12 Static 08/06/85 Camco R-13 Static 08/17/85 Camco R-16 Static 08/07/85 Camco S-2 Static 08/07/85 Camco S-3 PBU & BHPD 08/05/85 GO S-8 PBU & BHPD 08/09/85 GO S-8 Static 08/09/85 GO U-2 Static 08/07/85 GO Y-3 Flowing Gradient 08/10/85 Camco Y-18 Flowing Gradient 08/12/85 Camco '-~', 10-~u~ Victoria Aldridge LR2-1 ................................ S'f.i 0 Technical Documentation DATE ............................... ~$k~ 0ii"& GaS [~0[~§. -%301'nm%$$iC:' Records Management SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 AN CHORAG E, ALASKA 99502-0612 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATTN' Mr. C,V' Chatterton August 6, 1985 Well M-16 (41-36-12-12) PBU Gentlemen- Enclosed in duplicate, is Form 10-403, Sundry Notice and Reports on Wells, for the above named well' This gives notice of completion of work performed as outlined in our Sundry Notice dated January 15, 1985. Yours very truly, SOHIO Alaska Petroleum Company R.S. Allan SAPC Drilling Engineer RSA/MSS/sh 8685: 0505N Enclosures cc' Well File #17 RECEIVED AUG 1 ) 1, 5 Alaska 0il & Gas Cons. Commission Ancher;zge O~1 STATE Of ALASKA ALASKA AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 81-86 3. Address 8. APl Number PO Box 6612, Anchorage, AK 99502 50-029-20613 4. Location of Well At Surface: 1606'SNL, 606'WEL, Sec. 01, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 52.28' AMSL 6. Lease Designation and Serial No. ADL 28257 9. Unit or .Lease Name PrU~hoe Bay Unit 10. Well Number M-16 (41-36-12-12) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ::~], Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs .Made ~ Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following summarizes the work performed on Well M-16: 1. RIH and set plug in tailpipe "XN" nipple. 2. Perforated 5-.1/2" tubing at 10,066'. 3. Changed 5-1/2" x 9-5/8" annulus and 5-1/2" tubing over to kill weight NaCl. Installed BPV. 4. Moved in rig. Removed tree. Installed and tested BOPE to 5000 psig. 5. Sheared off SBR. Pulled 5-1/2" tubing. 6. Ran new 5-1/2" - 17# IPC tubing with 6 gas lift mandrels. 7. Stabbed back onto SBR. Spaced out and landed tubing. Pressure tested tubing to ens. ur. seal integrity. 8. Shifted. Open sliding sleeve. Changed 5-1/2" x 9-5/8" annulus over to 9.6 ppg NaC1 and · tubing over to diesel. Closed sliding sleeve. Pressure tested tubing. Installed BPV. 9. Removed BOPE. Installed and tested tree to 5000 psig. Moved rig off. 10. Installed and tested SSSV. The above work was completed on 7/28/85. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED AUG 1 19t 5 Alaska 0il & Gas Cons. C°mmissio A[luhura. g~ The space below for Commission use Title SAPC Drilling Engineer Date Conditions of APproval, if any: Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON To SFO/UNIT/STATE- TExAco (-.Hara [hon) MOBIL PHILLIPS STATE OF AK BPAE 3111 "C" .~IllE[T ANCtIOtlA6[. ALASKA IELEPi,~ONE (9071 265-0000 MAIL POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: T#: 6-5-85 76225 REFERENCE: SOHIO CASED HOLE FINAL LOGS The tollowin,g material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SF O/UN IT/STATE: A-2 .- 3-27-85 Casing Puncher 1 ~-,n_1860 F-19 2-11-85 Completion Record 11605-12839 M-6 ~ 5-02-85 CFS 10950-11600 · M-10" 5-04-85 CFS 9150-9750 M-16 ~ 5-05-85 CFS 107 00-11400 Sch #1 5" Sch # 1 5" Sch ~1 5" Sch #1 5" Sch # 1 5" Iii': Ii Alaska Oil & Gas Cons. Commission Anchorage Cathy Perkins LR 2-1 l)cve]opmcnt Ceology Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 February 26, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gent lemen: Well M-16 (41-36-12-12) PBU Enclosed, in dupliCate, are the following foms for the above-named well.~ 1. Form 10-407, Completion Report 2. Form 10-403, Sundry Notice and Reports on Wells; 3. Form 10-404, Monthly Report of Drilling and Workovers. JAB/J~H/jmw Enclosures cc: A. E. Leske Well Records (LR2~-I) Drilling Well File #17 s very truly, ~is tA~ lcB[a~e~ne~~~Ac ~ g," ,, ( ting) RECEIVED ~,~-~ 0 1 1985 Alaska Oil & Gas Cons. Commission ~, Anchorage 1. Status of Well Classification of Service Well OIL C~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] _ 2. Name of Operator 7. Permit Number Soh±o Alaska ~Petroleum Company 81-86 3. Address 8. APl Number P. O. Box 6612, Anchorage, Alaska 99502 50-029-20613 4. Location of we~l at surface 9. Unit or Lease Name 1606' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM (corrected) Prudhoe Bay Unit - At Top Producing Interval top of Sag R. SST. 10. Well Number 1162' SNL, 1174' WEL, Sec. 36, T12N, R12g, U?M M-16 (41-36-12-12) At Total Depth 11. Field and Pool 606' SNL, 1060' WKL, Sec. 36, T12N, R12E, U?M ?rudhoe :Bay 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ?rudhoe Oil 7ool KBE = 52.28' AMSL ADL 28257 12. Date Spudded9/10/81 13. Date T.D. Reached9/29/81 14. Date Comp., Susp. or Aband.10/5/81 I15' Water Depth' if °ffsh°refeet MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. De.th~hereSSSVset I 21. Thickness of ~ermafrost [1750'MD 9319'TVD ll710'MD 9288'TVD YES[] NO[] 2035 feetMD 1877' 22. Type Electric or Other Logs Run DTL/S?/CR/:BHCS, ~DC/CNL/CR/Cal, HDT, CB~./W~/CA/CC~. 2'3. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" x 30" Insulate.[Conduct'et' Surface 110' 36" 8 cu.yds concrete 13 3/8" 72# L-80 Surface 2733' 17 ½" 3767 cu. ft. Permafrost II ...9 5/8" 47# L-80 Surface 10786' 12 ¼" 1564'cu.ft. Class G; 130 cu. ft. Permafrost C 7" 26# L-80 10313' 11750' 8 ½" 456 cu.ft. Class G wf18% salt .. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) MD TVI)ss SIZE DEPTH SET (MD) PACKER SET (MD) ?rudhoe Oil Pool Top: 10954' 8646' 5 ~" 10367' 10206' , Bottom: 11180 8824' 10954'-10984' BKB (8646'-8670' TVDss) 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11000'-11008' BKB (8683',-8689' TVDss) DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 11016"-11080' BKB (8696'-8746" TVDss) ' 11100'-11180' BKB (8762'-8824' TVDss) .,, · 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) ' August 6, 1982 Flowing ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST pERIoD I~ oIL~B'BL GAs-Mc'F WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casirtg Pressure CALCULATED Press. 24-HOUR 'RATE 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ch~ps. '~. STATE OF ALASKA ALASK .LAND GAS CONSERVATION C .MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED' · MAFR 0 1 1985 ^laska 0~l & Gas Cons. Commissi(l!! ,, Anchorage ~----" Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Sag River SST. Shublik Ivishak GEOLOGIC MARKERS MEAS. DEPTH BKB 10840' 10884' 10953' 30. FORMATION TESTS TRUE VERT. DEPTH Subsea 8556' 8591' 8646' Include interval tested, pressure data. all fluids recovered and O.a.~.',, GOR, and time of each phase. IST OF ATTACHMENTS · I hereby certif¢ that the foregoing is true and correct to the best of my knowledge Signed___ Acting District Title Petroleum EngineeDate 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, ancl 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Sohio Alaska Petrole,;m Company 3. Address P. O. :Box 6612~ Anchorage, Alaska 4. Location of Well 99502 At Surface: 1606' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 52.28' AMSL 12. I 6 . Lease Designation and Serial No. ADL 28257 7. Permit No. 81-86 8. APl Number 50- 029-20613 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number M-16 (41-36-12-12) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following additional interval was perforated February 13, Schlumberger 3 3/8" Scallop guns at 6 s.p.f. 11036'-11076' BKB (Ref. BHCS/GR, 9-29-81) · 1985 using Due to problems incurred by the use.~of the larger gun, the following additional intervals were perforated February 14-16, 1985 using Schlumberger 2 7/8" Hyper- domes at 4 s.p.f. RECEIVED 10954 11000 11016 11076 A lubricator '-10984' BKB (Ref. BHCS/OR, 9-29-81) '-11008' :BKB ( " ) MAR 0 1 1985 '-11036' BKB ( " ) '-11080' BKB ( " ) Ai~,,~ u,i ~ Gas 00118. C0~llill was installed and tested to 3500 psi on all well work. Anchorage An SSSV was set and tested in the ball valve nipple at 2035~, I(ereby c~'ti~y/that the foregoing is true and correct to the best of my knowledge. J~ed Title Petroleum Engineer , ,he space~;l/~for CommissiOn u;e' ~ ~ I Conditi~Appr°val,ifany: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate '. STATE OF ALASKA ALASKA AND GAS CONSERVATION C . ;fiSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~1 Drilling well ~] Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 81-86 3. Address 8. APl Number P. O. Box 6612, Anchorage, Alaska 99502 50- 029-20613 4. Location of Well at surface 1606' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 52.28' AMSL 6. Lease Designation and Serial No. ADL 28257 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. M-16 (41-36-12-12) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of. February 85 ,19__ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressur9 tests ~'14. Coring resume and brief description 15. Logs run and depth where run RECEIVED i 6. DST data, perforating data, shows of H2S, miscellaneous data see Attached. Uss Cons. Anchorage -17. I hereby certify that the foregoing is true and correct to the best of my knowledge. :.i~GN /~ ~/~ ~..,,,") Acting District 2~? ED__~..~(J//~ /(~~,,,, TITLE Petroleum Engineer DATE · NO TE--R~/rton this form is required for ~calendar month, regardless of,the status of operations, and must be ~led in duplicate with the Alaska Oil and ~a~Co~ervation CommiSsion by the 15th of the succeeding month, unless otherwise directed. Form 10~04 Submit in duplicate Rev. 7-1-80 g PERFORATING DATA - WELL M-16 (41-36-12-12) PBU February 13, 1985: Rigged up Schlumberger and perforated the follOwing additional interval using 3 3/8" Scallop guns at 6 spf: 11036'-11076' BKB (Ref. BHCS/GR, 9/29/81) February 14-16, 1985: Rigged up Schlumberger and perforated the following additional intervals using 2 7/8" Hyperdome guns at 4 spf: 10954'-10984~ BKB (Ref. BHCS/GR, 9/29/81) 11000'-11008' BKB ( " ) 11016'-11036~ BKB ( " ) 11076'-11080~ BKB ( " ) Put well on production. February 22~ Set and tested SSSV in ball valve nipple at 2035'. Well on production. RECEIVED Ataska Oi~ & Gas Cons. Comm[ssio~ Anchorage SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 January 15, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Wells M-4r M-6r M-10~ M-15~ M-16 Enclosed, in triplicate,~ is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our proposals to perforate additional intervals in these wells. JAB/~'pjw Enclosures A. Br agg ~ ~' (Act ing) ~ ~istrict Petroleum Engineer cc: A. E. Leske Geology Well File 917 RECEIVED .lAN 2 4 ]g85 Alaska 0il & Gas Cons. Commission Anchorage ALASK IL AND GAS CONSERVATION ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 81-86 3. Address 8. APl Number P.O. Box 6612, Anchorage, Alaska 99502 50-029-20613 4. Location of Well At Surface: 1606' S2qL, 606' WIgL, SeC. 01, Tlllq, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) ERE = 52.28' AMSL I 6. Lease Designation and Serial No. ADL 28257 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number M-16 (41-36-12-12) PBU I 1. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following .additional intervals will be perforated ~n Feb~3_a_~z, Schlumberger 3 3/8" Scallops at 6 spf. 1985 using A lubricator will be instal-led and tested to 3500 psi for all well work. 10954'-10984' BKB (P~f. BHCS/GR, 9-29-81) 11000'-11008' BKB ( " ) 11016 '-11080 ' BKB ( " ) An SSSV will be set and tested in the ball valve nipple at 2035'. oa F~ No. ~ 14.~1 here, by certify that the foregoing is true and correct to the best of my knowledge. The spa/o~Jbelow for Commission use u / CondiCor~s of Approval, if any: Date APproved by I~RiGi~IAt SIGllED BI' LONHiE C. SMITH Approved CoPy Returned zo¢ By order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, (A 99502-0612 November 14, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: WET.n M-16 (41-36-12-12) PBU Enclosed, in triplicate, is Form 10-403, Sundry Notices and Wells, for the above-named well. This gives notice of intention to change tubing and install gas lift mandrels. Very truly yours, R. H. Reiley District Drilling Engineer RHR:IBG:ckg 111384 Enclosure cc: Well File %17 ALAS~-' .£ STATE OF ALASKA ( ¢ (J,L AND GAS CONSERVATION~JOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I-] COMPLETED WELL [] OTHER [] 2. Name of Operator 5. Elevation in feet (indicate KB, DF, etc.) KBE = 52.28" AMSL Perforate Stimulate Repair Well Pull Tubing 12. 6. Lease Designation and Serial No. ADL 28257 Check Appropriate Box To Indicate Nature of Notice, Report, or 7. Permit No. 81~86 8. APl Number 50- 029~206!3 9. Unit or Lease Name prudnoe 'Bay U~t' 10. Well Number M-16 [41--36-12.-12) PBU 11. Field and Pool Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) [] Alter Casing [] . [] Abandon [] [] Change Plans [] ~ Other [] Perforations Stimulation Repairs Made Pulling Tubing SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any' proposed work, for Abandonment see 20 AAC 25.105-170). Well M-16 is tentatively scheduled to be. %x~rked over during December 1984 to install gas lift mandrels,i 1. Rig up slickline. RIH and set plug in tailpipe "~" nipple. 2. Shift open sliding sleeve... 3. Change 5 1/2" x 9 5/8" annulus and 5 1/2" tubing over to kill weight NaCl. Install BP . 4. Move in rig. Remove tree. install and test BOPE to 5000 psig. 5. Rig up to pull and lay down 5 1/2', tubing.~ Shear off SBR. Pull 5 1/2" tubing. 6. Run new 5. 1/2" - 17~ IPC tubing with 6 gas lift mandrels. 7. Stab back onto SBR. 'Space out and land tubing. Pressure test tubing to ensure, seal integrity. 8. Rig up slickline. Shift open sliding sleeve. Change 5 1/2" x 9 5/8" annulus over to 9..6 ppg NaC1 and tubing over to diesel. Close sliding sleeve. Pressure test tubing. Install BPV. 9. Remove BOPE. Install and test tree to 5000 psig. Move rig off. 10. Rig up slickline and pull plug frcm packer tailpipe. Install and test SSSV. Put' well on production. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ The space belo Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1 ~80 Title Distric-e Dr~ 1 l~;.ng Engineer Date By Order of COMMISSIONER the Commission and Subsequent Re,otis' m Duphcate ' SOHIO ALASKA PETROLEUM COMPANY SFO ARCO EXXON TO: PHILLIPS CENTRAL FILES (¢C#' s-Transmittal Only INDEXED 3111 "Ct' STREE'~ ANCHORAGE. ALASKiA TELEPHONE 1907! 265-O000 MAIL: POUCH 6-61:2 ANCHORAGE. ALASKA 99502 Date: 9:'5-84 CC#: 75699 REFERENCE: SOHIO MAGNETIC LIS TAPES & LISTINGS The following material is being submitted herewith..Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: *J-11 TDT-LIS w/ Listing 7-12-84 #1 C.H. Sch~69430 *J-13 TDT-EDI'T w/ Listing 7-13-84 #2 C.H. Sch#69410 *M-16 TDT-EDIT w/ Listing 7-7-84 #2 C.H. Sch#69406 -...,.7'-'/3 -'~,~o~ / 8~/-5 -c<.~ e~ -- 1~o°~-//7/~ TAPE POS. 03155 03163 03158 (4/82) *SFO & EXXON: An Asteri,sk(*) next to a listing aboue means you should have' received the'Tape(s) and Listing(s.). ~$rd%ctly from the respective service company, Please confirm this. Q ~,~,_~ _~.~/~ RECEIVED ~ Carolyn Bishop Development Geology. DATE ln9n -- Well Records ALaska 0B & Gas Cons. comm%ss%v" Anchorage SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907! 265-0000 MAIL: POUCH 6-61 2 ANCHORAGE. ALASKA 99502 TO: SFO/UNIT/STATE: GETTY (-Marathon) MOBIL PHILLIPS ~' ~'~'*~ (~ransmit t al Only) .. C~T~ FILES (CC~' s-Transmittal 0nly) Date: 8-30-84 CC~: 75680 REFERENCE: · OOS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- C- 12/~,,,,..C~T~ S-15 ~ CNL J-Il J-12 J-13 R-12 R-22/" S-15 R-13 CNL TDT-M TDT-M TDT-M TDT-M TDT-M Compl. Rec. Compl. Rec. Comp1. Rec. GCT Gyro Well GCT Gyro Well Perf. Record 7-18-84 #2 7-4-84 #1 6-26'84 #1 7-12-84 #1 7-14-84 #1 7-13-84 #2 7-7-84 #2 7-9-84 #0 7-18-84 #I 7-19-84 ~.1 7-5-84 #1 7-4-84 #1 6-26-84 #1 7-22-84 #1 11000-11896 Sch 5" 1'1250-11872 Sch 5" 8850-9265 .............. Sch-.~~ .... ~: 10100-10970 Sch 5" 9150-10172 ,. Sch 5" 10800-11717 $ch 5" 10750-11630 Sch 5" 9590 Sch 5" 10822-10851 SCh 5" 11022-. !!O_~_Q ....... .S.~h ........ 5". 9950-10879 Sch 5" - - -11846. Sch - : - - -9294 Sch - 8700-10108 $ch 5." (4/82) RECEIVED DATE ~ - ~',-~ ~.,,o. ,~.i..a~10a Carolyn Bishop Anchoraoe Development Geology ~9 Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 August 15, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AlaSka 99501 Attention: Mr. C. V. Chatterton Well M-16 (41-36-12-12)_PBU Gentlemen: Enclosed, in duplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This ¢omtains our subsequent to performing an EDTA matrix stimulation treatment om this well. Yours very truly, JAB/J~H/pjw Enclosures cc: J. D. Hartz Geology Well File #17 J. A. Bragg District Petroleum Engineer (Acting) RECEIVED AUG ! 6 1984 Alaska Oil & Gas Cons. Commission Anchorage t.~ STATE OF ALASKA ALASir [ _ANDGAS CONSERVATIO~ .,~ .MISSION SUNDR NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:~ 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 81-86 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20613 4. Location of Well OTHER At Surface: 1606' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 52.28' AMSL 6. Lease Designation and Serial No. ADL 28257 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number M-16 (41-36-12-12) ?BU 11. Field and Pool Prudhoe-~Bay Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~[] Abandonment [] Repair Well [] Change Plans [] RePairs Made [] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see :20 AAC 25.105-170). The following interval in this well was treated 'with 100 barrels of EDTA matrix solution on July 21, 1984. The treatment wasconducted through coiled tubing as a single stage job and the well was shut-in for 24 hours after the treatment. 11100'-11180' BKB (Ref. BHCS/GR,. 9-29-81) An SSSV was set an~ tested in the ball valve nipple at 2035'. RECEIV£D AUG 1 6 Alaska 0il & Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct t~3 the. best of my knowledge. ~gne~_ ~_~~~ T itleDistrict Petroleum Engineer Date The space below for Commission use '~' Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 July 6, 1984 Alaska Oil & Gas Conservation Con~aission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Wells M-6 and M-16 Gent 1 emen: Enclosed, in triplicate, are Forms 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our prOposals to perform EDTA matrix stimulation treatments on these wells. GJP/~/pjw Enclosures cc: J. D. Hartz Geology Well File ~17 Yours very truly, ~~is~ iPcltipegt roleum Engineer RECEIVED JUL 0 9 .~,lasKa 0ii & Gas Cons. ComaissJon Anchorage STATE OF ALASKA/~, ALASKA ~...AND GAS CONSERVATION CCi MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL~[ OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, AK 99502 4, Location of Well At Sur face: 1606 ' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 52.28' ~ ........ I6. Lease Designation and Serial No. ,,. ADL 2g~57 7. Permit No. 81-86 8. APl Number so- 029-2fl6] 3 9. Unit or Lease Name ............. Prudhoe _naS, Unit 10. Well Number M-1 ¢; (.&l-Ct~-I 9_1 ') ~ Dr~ri 1 {F F~eFd a~c~ ~o~ Pr udhoe BaT Prudhoe Oil ?ool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following interval in this weli will be treated with 100 Bbls of EDTA matrix solution in August/September, 1984. The treatment will be conducted through coiled tubing as a single stage job and the well will be shut-in for 24 hours after the treatment. The SSSV will be removed prior to stimulation and reset after the job at 2035'. 11100'-11180' BKB (Ref. BHCS/GR, 9-29-81) Subsequent Work B .eportexl 14M hereby certify that the foregoing is true and correct to the best of my knowledge. ........ ~ ,~ TitleDiS~ict Pe~ole~ ~g~ Date c~dit~o.~ o~ro~, ~' ~n~: Approv~ Copy ReturnS. By Order of Approvedby ~I LS~tE C.S~)T~ COMMISSIONER the Commission Date JUL 0 91984 Alaska Oil & Gas Cons. Commission Anchorage Form 10-403 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99.502 ~o: SFO/UNIT/STATE: (-Marathon) EXXON GETTY MOBIL PHILLIPS STATE OF AK BPAE (Transmittal Only) . CENTRAL FILES (CC#' s-Transmittal Only) Date: 10/12/82 Trans.#: 2729 CC#: 55729 REFERENCE: SOHIO~D HOLE_ FINAL LOGS L~Copy of this letter and returning it to this office:-- SFL/UNIT/STATE ONLY: M_16'~TDT-M 8/31/82 #1 11740~11685 Sch 5" A-19~ TDT-M 8/28/82 #1 8850-9767 Sch 5" Y-6'" Spinner 8/11/82 #1 10900-10441 GO 5" E-11~ Spinner 8/31/82 #1 10300-10661 Otis 5" R-8--- Spinner 9/13/82 #1 10900-11250 Otis 5" E-1L~ Spinner 9/10/82 #1 10250-10672 Otis 5" A-19~ EPL 8/29/82 #1 8950-9300 Sch 5" G-7j PAL 8/26/82~ #1 0-9730 Sch 5" C-14j PAL 9/5/82 #1 0-10300 Sch 5" G-7¢" ETT 8/26/82 #1 2590-9730 Sch 5" G-7-~' Tubing Cutter 8/23/82 .#1 --- Sch E-10J Completion Report 9/2/82 #1 10100-11688 Sch 5" eCL (4/82) REC[IVED ..................... ~JL-~ I 4-'~82 VictOria Aldridge Development Geology ............................ ,uuS ~:~, ..... Records TP1-5 SOHIO ALASKA PE'TROLEUM COMPANY SF0 ARCO CHEVRON 31 1 1 "'C" SIREEI' ANCHORAGE. ALASKA 1ELEPHONE (907) 265-0000 MAIL: Pouch 6-612 ANCHORAGE, ALASKA 99502 EXXON To._ SFO/UNIT/STATE: (-Marathon) GETTY MOBIL PHILLIPS Date: 10/5/82 Trans. #: 2702 CC#: 55702 BPAE (Transmittal Only) CENTRAL FILES (CC#' s-Transmi t tal Only) REFERENCE: SJDHIO CASED HOLE FINAL LOGS / '~he material is being submitted herewith. Please acknowledge receipt by signing a following copy of this letter and returning it to this office:-- SFO/L~IT/STATE: B-6 TDT-m 9/2/82 . #4 8500-9302 5" Sch B-6 EPL 9/3/82 #1 8860-9203 5" Sch C-10 Spinner 9/13-14/82 5" Camco M-16 Spinner 9/10/82 5" Camoo Q-5 EST 8/16/82 #1 2685-10366 2" Sch Q-5 PAL 8/16/82 #1 - -10360 5" Sch (4/82) RECEIVED DATE 19 Victoria ALdridge Development Geology Well Records TP1-5 SOHIO ALASI,A PETROLEUM CO.::P,,NY SFO ARCO 311 1 "C" STREET ANCHORAGE, ALASKA TELEPHONE 1907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502. EXXON Date: 9~79~82 Trans.#: 2676 PHILLIPS __ _../ I CC#: 55676 ) CENTRAL FILES(CC#'s-Transmittal Only PAGE..1..of..2 REFERENCE: SOHIO MAGNETIC LIS TAPES & LISTINGS The following material is being submitted herewith..Please acknowledge receipt, by signing a copy of this letter and returning it to this office:.-- Tape Pos. Sch OH/DIL/BHC/FDC/CNL/LDT/NGT #1,2 8/15/82 ACC 65510 ** THIS TAPE SHOULD BE DESTROYED. A REPLACEMENT TAPE HAS BEEN IS'SUED AND IS INCLUDED IN THIS BATCH OF TAPES. Sch *'x G-18 --" Sch ~"E-17-' Sch * ~B-6 -~ Sch *"' E-11~"~ Sch *"--,B-6 -'" Sch *~'M-15~'' Sch *~ R- 7 -"' Sch * ~G-9-- Sch *-'"N-13--' Sch * ~-- R-3'--- Sch * --R-8 -- Sch * -AM-16 "- Sch *--"S- 9 -' Sch *'~A-11 / Sch *~ A-16 '-'"' Sch * -~- A-19--' Sch *'-~A-25" Sch * -'-N-15~- Sch OH/Replacement Tape #1,2 8/15/82 ACC 65510 01948 CH/TDT #1 9/11/82 ACC 65610 01942 CH/TDT #1 9/10/82 ACC 65611 01943 CH/TDT ~ #1 11/9/78 ACC 05576 01944 CH/TDT ' #1 8/6/82 ACC 65450 01945 CH/TDT #4 9/2/82 ACC 65561 01946 CH/TDT #1 8/15/82 ACC 65463 01947 CH/TDT #1 8'/12/82 ACC 65453 019.49. CH/TDT : #1 7/9/82 ACC 65333 01950 RECEIVED ~1 7/27/82 ACC 65370 01951 CH/TDT #2 8/6/82 ACC 65451 01952 CH/TDT #1 8/13/82 CH/TDT OCT 1 1982 ACC 65452 O1953 #1 8/31/82 ACC 65543 01954 CH/TDT CH/r. DT Al~skaOii& GasC°ns'Ccmmi£~{"#~2 7/18/82 ACC 65424 01955 Anch0ra~ ' ~1 7/31/82 ACC 65405 019.56 CH/TDT #1 7/26/82 ACC 65420 01957 CH/TDT #1 8/28/82 ACC 65545 01958 OH/DIL/BHC/FDC/CNL #1 8/18/82 ACC 65546 01959_ CH/TDT #1 9/1~/82 ACC 65504 01960 /8 23 *SFO & EXXON: An Asterisk:(*) next to a listing abc~...e means you should have received the Tape(s) and Listing(s) directly from the respective service company. Please,~////,~~.~,~.~.//..~_ ~...~,~_~ , _ Development Geology [ ~.~~k '9 Well Records DATE SOHIO ALASKA PEIFIOLEUM COMPANY SF0 ARCO - CHEVRON 311 1 "C" S1REET ANCHORAGE. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 EXXON GETTY SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) CENTRAL FILES (CC#'s - Transmittal Only) Date: 9-24-82 Trans.#: 2670 CC#: 55670 REFERENCE: ~'FINAL DATA - PRESSURE SURVEY DATA. The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-15'~ GO Pressure Survey and BHPD 8/27/82 N-15-~ Otis Pressure Survey and BHPD 8/28/82 A-19 '" Sch. Pressure Survey and BHPD 8/29/82 A-18~ GO Pressure Survey and BHPD 8/29/82 G-19-*' Camco Pressure Survey 8/27/82 E-15~ 'GO Pressure Survey and BHPD 9/3/82 E-10 .... GO Pressure Survey 9/14/82 E-1 GO Pressure Survey 9/14/82 E-20-' ,GO Pressure Survey 9/7/82 N-14 ~' GO - Pressure Survey and BHPD 8/16/82 R-7 "~ Otis Pressure Survey and BHPD 8/19/82 N-12:~ GO Pressure Survey and BHPD 8/18/82 X-7 ~ Otis Pressure Survey and BHPD 8/9/82 M-16~ Camco Pressure Survey and BHPD 9/10-12/82 R-8~' Otis Pressure Survey and BHPD 9/13/82 E~ll.'~' Otis Pressure Survey 9/1/82 ,E-11j Otis Pressure Survey and BHPD 9/11/~82 82) RECEIVED DATE Ab~k~ 0it & G~s Cons. Commission A.qchera§e Karen Mestas Development Geology Well Records A-11 A-17 A-9 A-lO N-15 M-17 M-16 E~ll SOHIO ALASKA .PETROLEUM COMPANY SFO ARCO CHEVRON EXXON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907! 265-0000 MAIL: Pouch 6-612 ANCHORAGE. ALASKA 99502 GETTY TO'. SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) CENTRAL FILES(CC#' s-Transmittal Only) Date: 9-15-82 Trans. #: 2630 CCI!: 55630 R,,~RENCE: SOHIO CASED HOLE FINAL LOGS · · . The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- Sch TDT-M #1 7/31/82 9700-10644 Sch TDT-M #1 8/2/82 9900-10827 Sch. TDT-M #1 8/1/82 9150-9992 Sch TDT-M #1 8/3/82 9650-10550 Otis Spinner #1 8/27/82 9800-10067 Sch Completion #1 8/9/82 102.34-11835 Record Sch Completion #2 8/4/82 10100-11660 Record Sch TDT-M #1 8/6/82 10100-10760 11 5" 5't 5" 5tt 5I! 5!! 32) RECEIVED DATE ~as Cu~s-. Anchorage Karen Mestas Development Geology' Well Reco'rds SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON GETTY ~o- SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) 3111 "C" S1REET ANCHORAGE. ALASKA TELEPHONE (907i 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 CENTRAL FILES (CC#'s - Transmittal Only) REFERENCE: !FINAL DATA - PRESSURE SURVEY DATA The follOwing material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office':-- A-12/ Pressure Survey & BHPD A_10/ ,, ,, A-ii/ " " A-16 ~< " " A-17 / " " B-16 / " " H-8 ," " " J_10~[.' " ,, Y-6 '~ " " N-15 '~ Pressure Survey R-3 / " E-7J' Pressure Survey & BHPD M-15~' Pressure Survey & BHPD A-18 f " " ~' M'16 ~ " " R_7/ ,, ,, R-8 / " " Y-11 / " " 7/25/82 Dres. 7/31/82 GO 7/24/82 GO 7124/82 GO 7/28/82 GO 7/27/82 GO 8/4/82 GO 8/13/82 GO 8/11/82 GO 811o182 co 8/6/82 Sch 7/23/82 Sch 8/13/82 Camco 8/14/82 Camco 8/15/82 Camco 8/7/82 Camco 8/11/82 Camco 7/27/82 Camco z) RECEIVED DATE 0il & (~.-~ ['~'~c ,::,::..... [ ~ Karen Mestas _ ,~ . And:0ra0e..... :' :~O~10] Development Geology ~s Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 August 17, 1982 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Wells A-18, A-19, M-15,and~I~ii6~PBU Enclosed, in duplicate, are the following forms for the above- na~ed wells. 1. Form 10-407, Completion Report; 2. Form 10-403, Sundry Notice and Reports on Wells; 3. Form 10-404, Monthly Report of Drilling and Workovers. Y~,~ very truly, '~DG '~~i~ ld E~eer GJP/JLH/pj s Encldsures cc: J. D. Hartz Geology Well File #17 ALASKA 6._ AND GAS CONSERVATION CO, ,,ISS,ON LO(~/~~. ~~ WELL COMPLETION OR RECOMPLETION REPORT AND _.. -1-..Status of Well - Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] -2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Company 81-,86 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20613 4. Location of well at surface 9. Unit or Lease Name 1606' SNL, ~06' WEL, Sec. 01, TllN, R12E, UPM (corrected) Prudhoe Bay Unit At Top Producing Interval top of Sag R. SST. 10. Well Number M-16 (41-36-12-12) 1162' SNL, 1174' WEL, Sec. 36, T12N, R12E, UPM At Total Depth 11. Field and Pool 606' ,q~T.~ 1060' WEL, Sec. 36. T12N. R12E. UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) r 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 52.28' AMSL~ ADL 28257 12. Date Spudded 13. Da~e T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 9/10/81 9/2 9/81 10/5/81] feet'MS L one 17. Total Depth (MS+TVS) 18. Plug Back Septh (MD+TVD) 19. Directio'nalSurvey [ 20. Depth where SSSV set I 21. Thickness of Permafrost L1750'MD 9319'TVD ll710'MD 9288'TVD YES~ NO[] 2035 feetMD 1877' 22. Type Electric or Other Logs Run DIL/SP/GR/BHCS, FDC/CNL/GR/Cal, HDT, CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20"x30" Insulate~.Conductoz SUrfaCe 110. . 36. 8 cu.vds, concrete · ' -- 13 3/8" 72~ L-80 surface~ 2.733,!~,. 17 1/2" 3767 cu.ft. Permafrc.,st II · 9 5/8" 47# L-80 Surface· 10786' 12 ~1/4, 156'4 cu.ft. Class G.- ' 130 cu. ft. permafro., t C 7" 26#. L-80 10313' 11750' 8 1/2" 456 cu.ft. Class G %r/18% slat 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD · . irtterval, size and number) MD . TVDss SiZE DEPTH SET (MD) PACKER SET (MD) Prudhoe Oil Pool top: 11100' 8762 ' 5 1/2" 10367 ' ]..f12q6' Bottom: 11180' 8824'.. ~ .. ' '26. ' :'? ~ ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11100' 11180' BKB (8?62' - 8824.' .. TVDss) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED · . , , . , · , , 27. PRODUCTION TEST "' Date :First Production . Method of Operation (Flowing, gas lift, .etc.) · :., . Flowing " .' · ': . ' - .. ,-.. August 6, 1982 ',,.~< I ~ .... ,, ..' ,. , . .... Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBI' CHOKE SIZE IGAS-OILRATIO ., TEST PERIOD .I~I. FlowTubin. g .Casing Pressure CALCULATED I~ Press.. : 24-HOUR RATE --v 0..IL-BBL GAS-MCF WA-I:'ER-BBL.. OIL GRAVITY-APl (corr) ' 28. CORE DATA '~' ' ' .... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit cOre chips. Flowing ": ' ' " RE~'~IVE~ ' '.,. .:? ,.' ' AUG2°1982 " '.'-' '.~-.'.'. ' '- : ' :,::' ,, ,,~'. :' A!aska0il & Gas Cons. Commission .;' . , ' Anchorag~ · ,. · __ 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. BKB Subsea Sag River SST. 10840' 8556' Shublik ~884 ' 8591 ' Ivishak 10953 ' 8646 ' 31. LIST OF ATTACHMENTS 32. I hereby cerl~fy, tthat~ true and correct to the best of my knowledge District Field / Signed ~.k. ~ Title 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- lng 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". I:nrm 1 ~-/I 1'~7 STATE OF ALASKA ALASKA L AND GAS CONSERVATION C ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 81-86 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20613 4. Location of Well At Surface: 1606' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc,) KBE = 52.28' AMSL 6. Lease Designation and Serial No. ADL 28257 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number M-16 (41-36-12-12) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals were perforated August 6, 1982 using Schlumberger 2 7/8" Hyperdome guns at 4 spf. A lubricator was installed and tested to 3500 psi on all well work. 11100' - 11180' BKB (Ref. BHCS/GR, 9/~@½81 An SSSV was set and tested in the BVN at 2035'. AUG 2 0 1982 14. I he lng is true and correct to the best of my knowledge. Anchorage - - Signed ~~ T ~ ~ Title District Field Engineer Da,e Conditions of Appr~al, if any: By Order of Approved. by. COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ~ , - -~- ALASKA~ ~AND GAS CONSERVATION Cli...MISSION MONTHLY REPORT'UF DRILLING AND WORKOVER OPERATIONS · Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 81-86 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20613 4. Location of Well at surface 1606' SNL, WEL, Sec. 01, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 52.28' AMSL ADL 28257 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. M-16 (41-36-12-12) 1 1. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of. August ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks '13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data See Attachment AUG % O~t & Gas Cons. Commission 17. , hereby ~tify~ ~that the foregoing is true.nd correct to the best of my knowledge. ~//,~/~.~ ' SIGNED .,d~.k,..~ ~_, ,J.Z~ TITLE District Field Engineer ~ ~ . ~_ - --, .......DATE NOTE--~'ort o~s form is req~r~d for each calendar month, regardless of the status of operat'ions, and must be filed [n du~ic~te with the Alaska Oil and Gas Conservation Commissi~ by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 PERFORATING DATA - Well M-16 (41-36-12-12) August 3, 1982: August 6, 1982: August 13, 1982: August 15, 1982: August 17, 1982: Pressure tested tubing and inner annulus. Rigged up Schlumberger and perforated the following intervals using 2 7/8" Hyperdome guns at 4 spf: 11100' - 11180' BKB (Ref. BHCS/GR, 9/29/81) Put well on production. Shut well in to prepare for static pressure survey. Ran static pressure/temperature survey at 8800' TVDss. Set and tested SSSV in ball~ valve nipple.at 2035'. Well on production. SOHIO ALASKA PETROLEUM COMPANY TELEPHONE (907) 276-51 July 1~, 1982 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention.: Mr. C. V..Chatterton WELLS R-8, Y-lO, Y-13, A-15, A-18, A-19, E-10, E-15, E-17, E-18, E-20, E-21, G-18, M-15,~R~!61'~'M-17 Gentlemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wells. This contains our proposal to perforate the wells~ f/ · ~ ~is~;i'ct~~ld Engineer GJP:JLH:ybr Enclosures cc: J.D. Hart.z Geology Well File #17 ' ' STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION C ..MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL i~:~X COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 81-86 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20613 4. Location of Well 9. Unit or Lease Name At surface: Prudhoe Bay Unit 1606' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM 10. Well Number M-16 (41-36-12-12) 11. Field and Pool Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 52 28' AMSL ADL 28257 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data ' NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~-I Alter Casing [] '-. Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment r-~ Repair Well [] Change Plans [] Repairs Made [] Other I--I. Pull Tubing [] Other E] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting anyTM proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals will be perforated during July/August 1982 using Schlumberger 2 7/8" Hyperdome guns at 4 spf. A lubricator will be installed and tested to 3500 psi on all well work. 11100' -11180' BKB (Ref. BHCS/GR, 9/29/81) · An SSSV will be set and tested in the ball valve nipple ca. 2000'. Subsequent VFo~-I( xqepoxted ~'~; ..... No. Dated ll.nlhere istr e and correct to the best of my knowledge. S'g ed ~ ~ L/L.~~ Title ;District Field Engineer Date The spac&e,o~ for ~9.~,ssion use -~J. Plisga ~ · Conditions of Approval. if any: A~proved Copy Roturned I Approved by COMMISSIONER the Commission. Date . Form 10~403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SFO/AEP/ST: *E-15 *F-18 ECTED--*M-16 *R-20 SOHIO ALASKA PETROLEUM COMPANY SOH]0 RESTRICTED 3111 "C" STREET ANCHORAGE, At,:, ~'.. .. TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 ARCO ~o: EXXON PHILLIPS Date: 11/16/81 # 1187 SFO REFERENCE: SOHIO MAGNETIC LIS TAPES & LISTINGS. The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- Magnetic LIS Tape & Listing 10/28/81 " " " " ii/i/Si " " " " 9/29/81 " " " :~" 10/22/81 OH-DIL/BHC/FDC/CNL-# l& 2 OH-DIL/BHC/FDC/CNL-¢/i& 2 OH-DIL/BHC/FDC/CNL-,~! l& 2 OH-DIL/BHC/FDC/CNL- ~/l& 2 #62264 #62271 #62217 #62255 (Sch) Ca~l Xr.~ter De~ ~,, ~h~_ Geo logy We~cords HQ 4-5 SOHIO ALASKA PETROLEUM COMPANY November 3, 1981 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Conm~iSsion 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well M-16 (41-36-12-12) Enclosed, in duplicate, is Form 10-407, Completion Report, for the above-named well together with the Well History, Well Logs, and Directional Surveys. This well has been suspended pending perforating operations. Yours very truly, RHR: ja Enclosures cc: Well File #17 R. H. Reiley District Drilling Engineer RECEIVED NOV 0 1981 Alaska Oil & Gas Cons. Commission Anchorage ALASK AND GAS CONSERVATION C ,VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~' GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , ,. 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Company 81-86 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20613 4. Location of well at surface 9. Unit or Lease Name Prudhoe Bay Unit . .. 1606' SNL,' 606' WEL, Sec. 01, TllN, R12E, UPM (co'~ At Top Producing Interval top of Sag R. SST. VEP, IFIED 10. Well Number 1162' S[~, :1174' ~_~, Sec. 36, ~, R12E, UI~ N-16 (41-36-12-12) At Total Depth Surf. ~ 11. Field and Pool 606' SNL, 1060' WEL, Sec. 36, TJX, R12E, UPM .~.H..j..E ~ Prudhoe Bay , 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prud~oe Oil Pool KBE = 52.28 ' AMSLI ADL 28257 12. Date Spudded 13. Date I.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 9/10/81 9/29/81 10/5/81 feet MSLI one 17. Total Depth (MS+TVS) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey [ 20. Depth where SS'SV set I 21. Thickness of Permafrost l1750'MD 9319'TVD llT10'MD 9288'TVD YES~ NO[] 2035 feetMD 1877' 22. Type Electric or Other Logs Run DIL/SP/GR/BHCS, FDC/CNL/GR/Cal, HDT, CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20"x30"" £nsulated Conducto]' Surface 110' ~36" 8 cu.yds. 'concrete 13 3/8" 72# L-80 Surface 2733' 17 1/2" 3767 cu.ft. Permafr¢st II _ 9.5/8" 47# L-80 SUrface . !0786, 12,1/4" 1564 cu.ft. Class G; 130 cu.ft. Permafrcst C 7" 26# L-80 10313' 11750' 8 1/2" 456 cu.ft. Cla~s G ~/18% salt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD 'interval, si. ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) ,. 5 1/2" 10367' 10206' None , , 26. ACID, FRACTURE, CEMENT SQUEEZE, Eib. ... ' .... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED · · , . 27. PRODUCTION TEST Date F rst Product on . 'l M.e:th0d.°f Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I ; . TEST PERIOD ~ ;. ~ · · .... FIo,vv Tubing : Casing Pressure CALCULATED "._~. OIL-BBL GAS-MCI:. WATER-BBL OIL GRAVITY-APl (corr) . Pr~s. 24-Ho'uR RATE 28.~ ~':". ' CORE DATA · , · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,':. , -. ., .... .RE£EIVF. D None '. ". ' ' 'NOV..__ 0 !98] ,' · Alas~ Oil & Gas Cons. Conlmlssion ' ' ' ' ' : : · ' ' ' ' ' ~ r :'Anchorage · . . , , , . . Form 10-407 Submit i n duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. '" ' , .30. · GEOLOGIC MARKERS NAME Include interval tested, pr, MEAS. DEPTH TRUE VERT. DEPTH' GOR, and time of each ph BKB Subsea Sag R. SST. 10840' 8556' Shublik 18884' 8591 ' Ivishak 10953' 8646' FORMATION TESTS )ressure data, all fluids recovered and gravity, )hase. 31. LIST OF ATTACHMENTS Well History, Well Logs, Directional Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title District DrillingDate {~' ~O' ~% BH 'R. H. Rei ey ~ Enqlneer 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 2.4: 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- lng 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" Fnrm 1 WELL M-16 (41-36-12-12) I~LHISTORY Spudded well at 0345 hours, September 10, 1981. Drilled 17 1/2" hole to 2740'.. Ran 71 jts. 13 3/8" 72# L-80 Buttress casing to 2733'. Cemented with 3720 cu.ft. Permafrost cement followed by 47 cu.ft, top job. Installed and tested BOPE. Cleaned out to 2695'; tested casing to 3000 psi, okay. Drilled out to 2760', ran leak-off test to 0.71 psi/ft, gradient. Directionally drilled 12 1/4" hole to 10795'. Ran 283 jts. 9 5/8" 47# L-80 Buttress casing to 10786'. Cemented in two stages: First stage with 1564 cu.ft. Class G cement; second stage through D.V. packer at 2613' with 130 cu.ft. Permafrost C cement pre- ceded by Arctic Pack. Cleaned out DoVo; tested casing to 3000 psi, okay. Cleaned out float equipment and directionally drilled 8 1/2" hole to 11750'. Ran open hole logs. Ran 37 jtso 7" 26# L-80 IJ4S liner to 11750'. Cemented with 456 cu.ft. Class G cement with 18% salt. Cleaned out to ~ested casing'to 3000 psi, okay. Changed well over to NaC1; ran CBL. Ran 249 jts. 5 1/2" 17# L-80 A/B mod. Buttress IPC tubing, to 10367'. Landed tubing with ball valve at 2035'° Installed and tested tree. Displaced tubing to diesel; set packer at 10206'. Tested tubing to 3500 psi, okay. Released rig at 0700 hours, October 5, 1981. NOV 0 4 1981 A~aska Oil & Gas Cons. Commission Anchorage Contr°lled Drilling ConSultants Mr. Brian Rose- Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, AK 99502 Dear Mr. Rose:' P.O. BOX 1189 PALMER, ALASKA' 99645 PHONE 376-,~,423 .. 'October. 6;- 1981 ; , ~., '7, , RE: Magnetic' Single Shot .surVey. Job No. -0981-030_.-- · · · . · Well 'M. 16 (41~36-.12-12).~'~ Prudhoe- Bay Field ..':/~'i',.'i,,~:. North Slope, .Alaska.~'' .... ~" ,. Date of Survey: 9/9/81 t ., ,. , , '~ ,..~, Pl~'ase find enclosed the "Original', and six (6). Magnetic Single Shot' Survey'on the above well'~."~ Radi~S'::ofilCurVature was the method in calculating'-this survey..'.':~The:'depth?i.{nterval · . .~ ' ,,, ~ . the survey was 1600 to 11,700 .., Thank you for givi~§ us this opportunity to.,be of service;~. · ! . ~ours very truly, Control'led Drilling:. Consultants Steve R~.tcli~f' .':" Directional Supervisor " ., ,, -. ' i- · ] " ,- , CC'~:PLF T I0% 'PCRT SCHIO ALASKA ":.5"iTIC SI~:5LE SHOT SURVEY ~?A~IUS 0; CURVATURE ~?ETHOD OF CO>~pUTATION CC'~PUTE~ FO~ WEL,,'.:-18{41-36-1/-12} K B tLEV 52,28 RECORD-OF SURVEY STATE OF ALASKA COPY .............................. TRUE ............... ~ .......... MEAS. DqIFT VERTICAL SUB DRIFT TOTAL COORDINATES DEPTH ANGLE DEPTH SEA DIREC D ,v: DEG. CLOSURES DISTANCE ANGLE . DOG LEG SEVERITY DEG/10OFT 0 O O O.O0 -52,28 N O,OOW O,O0 S 0,00 W O.00 S 0 0 O v; U · O OO ASSUN~ED VERTICAL TO 1600. FT, 1631 1 0 1630,99 1578,71 N41,50W 0,24 N .... !..9!6 '4 30 1815~7.~ .... 176.3,97 ........ N.%.~.,~QOW .. 7.99 N 19&O 8 0 1939,00 1886,72 N14,00W 21,06 N 2053 11 ~5 2060.15 2007.87 N20.OOW 41.22 N 2157 15 15 2151.54 2099.26 N26.00W 61.gO N 22~9 18 0 2239.69 2187.41 N21.50W 85.49 N 2343 21 0 2328.28 2276.00 N21.50W 114.68 N 2466 25 30 2441.27 2388.99 N21.OOW 159.92 N 2559' 29 "0 .... 25'23,9-3 ...... 2471"~5 ...... ~2-0%50~ 199.73 N 2689 ~3 ~0 .263~,19 2581.91 N22.00W 282.09 N 2772 36 30 2702.99 2650.71 N25.50W 306.18 N 2866 43 0 2776.80 2724.52 N20.OOW 359.81 N 295~ 40 0 2847.27 2794.99 N17.50W 415.81 N 3_051 40 0 2918,51...2866,23 .... ~.k~QW ~: .473.53 Fi 31~3 ~1 0 2988.47' 2936.19 N 8.50W 532.27 N 3235 ~2 0 3057.37 3005.09 N 6.50W 592.70 N 3q51 ~5 0 3431,62 3379.34 N 6.50W 945.57 N ..... ~250 ~5 0 378~,¢7 '3732,19 ........ ~ .... 6'50W 1296.15 N ~746 ~6 0 4132,12 ~079,84 N 6,50W 16~7.64 N 5057 ~ 30 43~9,13 4296,85 N 6,50W 1868.98 N 0.00 W ...... 0.00 S 0 0 0 w 0.09 W 4.25 W 7.6~ W 13.79 W 22.36 W 32.96 W 44.46 W 62-05 W 77.14 W 101 · 38 W $20.78 W 143.28 W 162.28 W 177.75 W 188.64 W 196.59 W 236.80 W 276.7/+ W 316.79 W 342 . 01 W 0.26 N gO 44 59 ,~ 9.05 N 28 1 53 w 22.40 i~ 19 55 41 W 43,47 N 18 30 31 W 65.35 N 20 0 51 w 91,62 N 21 b 1£ ~ 123.00 N 21 11 30 W 171,54 N 21 12 29 ~ kSl.O~ N 21 ~ ~ W 329,14 N 21 31 4~ w 387,29 N Zl ~Z 45 W 446,36 N 21 19 13 W 505.80 N 20 3~ 30 ~N 564.71 N 19 30 53 W 974.77 N 1~. 3. 3~ W 1325,36 N 12 3 ~ W 1877,8Z N 10 53 0 W 1900.02 N 10 f2 12 W 0,000 3,Z20 1,Bg~ 2.B23 3.d5~ 3,750 3.025 3,191 3.65v 3,786 3,~06 3.861+ 4.4'39 1.747 3.~55 2.161+ 1.~59 0.5~1 O.uO0 0.202 0.161 O i ~I'AN( 0.00 0,2b 8,1~ gl.39 ~1,~2 162.67 Zu3~ bll.5~ o01.33 &0H.~,O. ~.,/ELL. ,/'""~.6 ..............' ................. L..'~ ......... :]'. ......... SI, NGI=E--$HOT. ~$URVEY~-''' ................................. 2--OCT · 8 ], ............... RECORD OF SURVEY DEPTH ANGLE. DEPTH. SEA DI.REC DISTANCE ANGLE DEGtlOQFT D ~ DEG, D M , 5552 A5 15 A696~85 ~6~4,57 N 7,50W 2218,65 N . ~8~,9~ W 2251'80 N' 9 50 ~5 W 6046 ~5 ~5. 50~.63 4992,~5 N 6,50W 2566,86 N ~27,70 W 2602,25 N 9 27 ~5 W Oel~ 25~eZO _6%1_1 ~ ...... O .... ~.~TZ_._Z.Z ....... ~.0~_~ .... N.__~.5.0~ .... ~_9~,.Z?...N ...... ~6~.00.~ Z~l.SS_? ....... ~ .... ~._~_W ......... 0.05~ .....~91~.00 .... 7007 ~ 30 5724,97 5672,69 N 8,0OW 3240,65 N 509,06 W 3280,40 N 8 55 ~9 W 7502 43 0 6082.53 6030.25 NiO.OOW. 3578,71N 562,61W ~622,67 N 8 56' 3 W 8268 37 0 6677.53 6625,25 N 1,OOW ~05'9,51N 583.17 W 4101,~S N 8 lO Zg.W · 8587 3~ 0 6933,95 . 6881,67 N O,50W ~149,2~ N 585,65 W 4289,~1N 7 50 50 W 8909 38 a5 7i89.81 7137,53 N ~,-50E 44~4,58 N 580.54 W 4~82,33 N 7 26 30 W -90'91"42"~ 0 ...... 7328°-45 '~'~276~i7 ....... N'-'5.00E 45~2,1~ N 571,80 W 4597,83 .... N ...... ~"' 8'38-w .... 9573 ~3 30 7682,38 7630.10 N 8.00E 4887.16 N 534,77 W ~916,34'N 6 l~ 40 W 10085 ~1 a5 8059.10 8006.82 NIO.OOE 5229,59 N a80.53 W 5251,62 N 5 15 0 W ~-~'35 ~0·'30 ..... 8322.74 ..... 8270%~&6 ...... N'l"O,~d~ .... 5.~'56,28 N" 440,56 W 5474,0~' N'--~-36-58'w .... 0,3'57 11700 39 30 9291,77 9239,49 NiO.50E 6256,42 N . 295,87 W 6253,~1N Z ~2 27 W 0,081 ~*180 3261,08 0,B57 3601%29 1.,.85~ ............38.09,69 0,31~ 0,983. ~7,0~ ~ j 1.823 0,~29 ~90b,97 0,383 5Z~6.~5 . BOTTOM HOLE"CLO$ORE" 6263,z, 1 FEET 'AT-N ~ ~;2"'27 W · SOHi_O_NELJ.._.M--16 ........................... ,5/NG LE_,SHO I._ S UR VE Y: ................... ~EASURED DEPTH AN.D OTHER'DATA FOR EVERY 'EVEN 100 FEET OF ,.SUB .5gA DEPTH. 2. OCI . .... 8,1. ........ TRUE VERTICAL SUB MEASU_R.E D MD-TVD VERT DEPTH DEPTH ' SEA'DIFFgRENCE CORRECTION TOTAL COORDINATES 1.52 252 352 · /+52 552' 652 7B2 852 952 152. 100 252. 200 352. 300 /+52. /+00 552. 500 652. 600 752. 700 0 852. 800 0 952. 900 0 1052 1052 · .1000 0 1152 1152. 1100 0 1.?, 52 ......................... 12 52 . ........... 1200 ........... ..C). ........................ 1352 1352. 13oo 1 ~,.52 1/+52 · 1/+oo ! 5_52 1.5 52_. ........ 1500 1652 1652. 16oo 1752 1752. 1700 1853 la52. 18oo 1953 1952. 19DO 2055 2052. 2000 0 0,00 5 0 0,O0 0 0,00 $ 0 0,00 5 0 0,00 S 0 0,OO S 0 0.00 S 0 0.00 S 0 0,00 5 0 0,00 $ 0 O, O0 S 0 0.00 S 0 0.00 S 0 0.00 $ 0 0,00 S 0 0,58 N 0 4,06 N 0 11,09 N 1 22,86 N 1 39.70' N 0.00 W 0,00 W 0,00 W 0.00 W 0,00 W 0,00 W: 0,00 W 0,00 W 0,00 W 13. 0,00 W 0,00 W 0 ..00 ..... W O,00 W 0,00 W 0.00 W 0,37 W 2.51 W 5,07 W 8,09 W 26 W 2 .t..58 ........................ :215..2. ........... 21 o0 ........... 5 .......................... 2262 2252. 2369 2352. 2/+78 2452. 2592 2552. 2710 - 2652. 28~4 ....... ~ .............. 2752, 296/+ 2852. 3095 2952, 322~ 3052. 3363 3152. 3501 ' 3252. 3639 3352. 3780 3/+52, 3921 3552. 2200 9 2300 16 2~oo ........... 25 ............ 2500 39 1 2600 57 : 1 2700___~..81 ................. 2 2800 2900 .30oo 3100 3200 3300 3/+00 3500 112 3 142 3 175 ................ 3 210 3 248 3 286 3 -- 327 /+1 369 /+2 '6t. .. 89. 123. 16/+' 215, 273, 3/+0. 419, 501. 588. 678, 772. .................. 867,92 .j',,l ....... 22 ,,,5 · 52_.....v,,' ...................... - 965.97 N 2~.94 W · 1065,12 N 2/+9,36 ~ SHOT MEASURED DEPTH AND OTHER DATA FOR EVERY 'EVEN 100 FEET OF SUB SEA DEPTH. TRUE ~IEASUR£D VERTICAL SUB ........ .~!~,T_..V_~ ........ VERTICAL DEPTH DEPTH SEA DIFF. ERENCE CORRECTION 'TOTAL cOORD II,~ATE5 81 4063 3652. 3600 410 41 4204 3752, 3700 452 42 4346 ..................... ._3.~8~27 .....~_&O0 493 ~ ._ ~1 4489 3952, 3900 536 43 4632 4052 · 4000 579 43 4775 4 :l..5.2, ...... ~_l..O O_ .... 6_2.'~g ........................... 43 4918 4252. 4200 666 44 5061 4352. 4300 709 43 5346 4552. 4500 794 43 5488 4652, 4600 836 42 5631 4752. 4700 878 ......... 42 5773 .4852. 4800 920 42 5915 _ 4952. 4900 962 ~2 6057 .................. ~52.. ...........5000 1004 .............. 42 6199 5152. 5100 1046 42 6340 5252, 5200 1088 42 6482 5352. 5300 1129 ............. 41 6623 5452. 9400 1171 42 6764 5552. 5500 1211 40 7045 5752. 5700 1292 40 7185 5852. 5800 1332 40 7.3~3 5952 · 5900 ..!_3_70 ....... 38 7460 6052. 6000 1408 38 7596 6152.' 6100 1443 35 7857 6352, 6300 1504 29 7984 6452. 6400 1531 27 8!!!_ ~95,~, ........ ~.QQ .l~.~O .................... 27 8236 '6652. 6600 1584 26 8361' 6752, 6700 1608 ~486 ..................... 6892. 680Q.2_16~ .......... ' 8610 6952. 6900 1657 8735 7052. 7000 1682 24 25 24 25 126~.1~ N 270.28 1363.77 N 283,85 1464.93 N 294.48 .1566.58 N 305.16 1668,39 N ~1~,97 1770.40 N 329,69 1871.82 N 342,31 1973,~0 N .... 353,23 2073.61 i~ 364,57 2173.88 N 376.40 ..... 2274..!,6._.N ........... 391..68. w._ 23 74.34 N 403.44 2474.59 N 414.70 2574,53 ;'4 42B.50 2674.70 N 439.03 2774.23 N 4~+9.49 2874.18 N 460,00 29 72 '"92 N ~+73.58 3071.~7 N 495,26 3169.93 N 497,84 3267.17 N ~12.83 ~36~.27 N 527,08 3457e83 N 3550,46 N ~7e66 3641.56 N 572.07 3797.40 N ......579.5~ 3808.22 N 3886.83 N 581.10 3964.23 N 581.79 . 4040.23 N 582.84 4115.53 N 584.00 ~189.~.6 N 4262.79 N . 585.63 4337.54 N 584.98 W w w w w w w w w W w w w w w w w w w MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET O.F ,SUB SEA DEPTH· TRUE ._E_EASU, RED ........... V. gRI I CA L,_,,SU[~.,,,~_D_-I_Y.O ............ VERT I gAL DEPTH DEPTH SEA DXFFERENCE ¢ORRECTXON TOTAL COORDINATES 8861 7152 8990 7252 .............. _3.123 ........ _________735.2 9258 7452 9395 7552 9669 7752 9806 7852 .......... 99~1 ............... __.__7.9~2 10076 8052 · 7100 1708 26 · 7200 1737 29 , 330Q .....ll!~_Z~ ............ 33 · 7400 1805 35 · 7500 1842 37 · 7600 __1~79 ..... ~.7 · 7700 1916 37 · 7~00 1953 37 ~495.99 N 577.44 4583.~8 N ......... 569.90 4674,13 N 560.97 4766.29 N ' 550·5~ ~8~9.24 .N ......... 538..6.Z..w 4952.44 N 525,38 504~.4~ N 511.40 'N ~96,80 N 481.59 , ............... Z. 9.0.0____198 ~ ........... 35 ..... 5134,8-1 · 8000 2023 3-5 5223,59 10209 8152. 8100 2056 33 5310.85 N 466 8_g~2.,___82,00~..12. Q.~9_ ............................. 33' ..................... 539..6.~._67 N .......... 4.51 8352. 8300 32 5481.11 N 436 8452. 8400 31 5564.98 N ~21 8652. 8600 31 5731,79 N 391 8752, 8700 31 581~.7~ N 377 2121 2152 21~_~ 2214 10474 10605 ...... 1Q~..~ 10867 ~3' 10998 11129, 11259 11389 11519 11649 8852. 8800 ' 2276 8952. 8900 2306 9052. 9000 2336 9152, 9100 2366 9252. 9200 2396 · 20 W · 07_.W ................................................. · 18 W .39 ._66_W .98 ,35 31 5897.39 N 362,78 30 5979,73 N 348.26 30 6061.7~ N 333.80 30 6143.52 N 319.38 30 6224e96 N 305.02 _ISLTgDPQLA_T_~D.::. VALUE5 FO SINGLE ,Si-lOT SURV~ .- R .EVEN. iOOO_Fg..gT .OF.. MEASURED DEPTH,. TRUE :.,EAS JRED VERTICAL DEPTH DEPTH 10 0 q ................. 1.0 2000 ' 19 3o0o 2'8 5000 43 6000 50 7900 57 8000 64 9000 72 IQOOO _79 11000 87 SEA TOTAL COORDINATES QQ.~ ........... ~3_~_ 0~00 $ 0.00 98, 1945. 30,02 N 10,11 79, 2827. 441.77 N 169.67 07, ......~.5~ ~ 1.~20.68 N 255.20 09. 4256, 1828.73 N 335,H2 12, 4959, 2534,74 N 421,21 19, __-5_6.~, .... ~_~_.~5-98. N... 506,87 64, 6412, 3896,56 N 581,17 59. 7207, 4502.43 N 577, g~, ........l~..~ .......... ~..!~,67 ~ ...... 490. 53, 8701, 5816,00 N 377, W W W W W O0 W 13 W 2 OCT, ~'~' ~' ~ ~"=' '' ' .... '' ';~: ~.~' ~ '.:,~ ~ ~ ' ' . . t I ~ ~ ' ~ ~ ~ - ~ · . ' m ~ . , · ' ~ . ~ , . ~ . , ~ . , , , ~ ~ , : : : ~. ,~ 'T~ ~:-: . : : ? .... : .......... . . -.;~ ~ ;;~, ~ :~:,:.. ~ ;~: ~.~: ,, ~ . ... '~ ',~ ~ "~:-' : ,-T'] .... ~--'T'~'--:'~ '-~--~'-~ ........] iT3~~ "['--~ ...... ~-~;-t ...... ~ ............... ] ...... · ..... ~. .: "-,.-'~,.~-- n', .... ~'-~ ......... , ....... , ............. ~ ............ + ......................~ ~ ........... i ,,T. ~'Tff ' , , , ~ .,'~T?':',''~-~-~ ........ t'~ ~'~m-~ ...... r~ ..... ~ .... ~ ....... ~ ..... ~ ..... ~--: ...................... .{. ................ ~ .... ~ ........ ~-.~..: ......... -I-'~ ~"~~~, ~ ~ · ....... ~"-~-:-~---~-';'~~ ...... ~"~ ~'-'-~',. ~ ........ 6800 ~-s. ; O- -:~ .... : ~..L .... -~-.~-.~- : - : . ; , . . . : ' ; ~ ~ ; ; . .~ . .~ . ~ ~ .~ ~ ; , -_ , . ...; . , ,; ~ , . ~ .... ; ~ . . ~ ... ~ - , ~ ~-~ ~ ..... ~ .................. ~ .......... ,. 6400 ........ ~ ~ ......................................... ~ ....... : ................................ L-.- ~- - ~ ...... k -'"': F"': --- :-:= ..... :" '~'-~4 ...... ~ ...... ~~-: -:'-'{ ........... ,:~-- -~-~ ............ ;--~-~---: ......... ~ ........ ~ ......... ~.: ~ ........ ~ ............. ~ .... : .... ', -~. ~:--~ ................. :---~--~-] ............. ~ ~ ...... 6000 ..... : ~ :~ ~.; : ..................................................~ ~~ 't ~ ............... [ ................ ~ ................... ' ........ . , ,.._ .: ..... = .......... . ............. ~ .............. ~ ~ :': .... :: ........ T'"::~T'-:-:'~'-F-::, . T ~". ~'" ': ....... . :' - :~0~ ............. :~':.~ ........ _ : ...... ~1 ......................... ~-~ ''~ ~~T-' ~ :-~-'~-~ ~ '" ~" =~ .'~-~W-:-~ .... ~- ,-~-~-?--~ '-~' ~ ~-- r :--: 5--~ : . :-~-' ' ' : ~ "~" ' i ~-'' :; ~ ~.: · : . - " . . ..... ~ ; T, ~,~ ~IW .... ....... : ...... ~" ~ "1 .......... . ["-"~; ............................... .... ~ .:. , ~. ' ~ ~ ~- ~--~ .... :-~-~ ..... ~: ..... : ............ i .1- .... 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T.: ~,~ -.~-~L.~L~.~.~.~_~_,~~ ~'~ ';~ ~ ;.~. , :._: i ~ t ~ ~ ! ~ ~ ~ i ~T ~ ~' :i ~ ~' ~ ~ '/ ~" i':' :' r :.~'~.~ ~ ~'-~",~ J~ ~ '~L]_~ _~ I ~ ~ ~ 7~ ~ ~'-'~-: ..... ~ ~. ~ 7' ~"~T T-~T-- ~ T"~-'~'-T~-~'7-: .......... Eastman/ Whipstock l A PETROLANE COM~ REPORT of SUB-SURFACE DIREC TION,4 L SURVEY SOHIO ALASKA PETROLEUM CO,~ COMPANY ,Pad M, Well Number 16 WELL NAME Prudhoe Bay, North Slope, Alaska LOCATION JOB NUMBER A1081G0062 SURVEY BY Hickman/Pefferkorn TYPE OF SURVEY Gyro-Multi Shot DATE 16-Oct-81 / /VOVo ~,,t~ oi/,~ ~_ ~ 1981 ~laska Eastman P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 October 20, 1981 SOHIO ALASKA PETROLEUM CO. Pouch.6-6112 Anchorage, Alaska 99502 Well Number~ Pad M~ Well Number: 16 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Gyro-Multi Shot Date: 15-Oct-81 Method of Computation: Radius of Curvature Surveyor: Hickman/Pefferkorn Job Number: A1081G0062 Attn: Gary Plisga Dear Mr. Plisga, I am enclosing the original and sixteen copies of the Gyro-Multi Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Singerely, . ' Distrf~t Surveyor aH/bb cc: file enclosure Directional Drillers/Sub-Sudace Surveyors/Instrument & Tool Rentals/Sales/Worldwide F C)i:;.:._F .:, '-' ]: G H T ,~ ..... c- ":'j r~',,' D E 0 5~.'~ ,¢'I ..... 3: N F.: E C T A ?..-" C~ U L A 0., '7 ¥ 0,2 ? L; O, 1! EZ ~ .., 5 ,'.:'. 0 .: 7 ¢ 7-, !: 7' 6 7 , -4 ;; ..... 9 7' ? i ;;1:: .J. S i., 3 g i O0 ~ ';';.: C L ;:'J {ii: 1';1. "' .'.'ii; T' A F:' "" E 0,8 O 0 , -4 4 :3 . 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'- ..............__~ ~ .j. ..1 ~ ' ..-I ..t mi ~'~Tr- , ~,, _ ~ .......... ~_ .-L.,..--,-I- .................. , .... + ....... }t--t ....... ~ __~_ .~ .1 t ...... ~_. ......... , ......... ~---I--t ; .--,-: T', ~. t i" ~ , 1 ~ t ~ , ~ : i ~ ~ [ , , _.,......~__.L. __- , .... ~_.C ...... -I--~--t- --~--~--! ...... 4-.-,-- ~ : t.t- t,,, , ! , , : -.~---?---,--t--!,, ~.~ t ~_:,._.~__. ~~--S___ i.~_~ ...... ~=L~---~.-. ~-~.--,-~ .,.~ ~-....--. ~,-, ,~ -~ ~-,~ l~ ~ ~- ,~.~--.~.~- Suggested fo,.Tn to lm i~L~ertcd in each "Active" well folder to d~eck for timely compliance witJ~ our rcx~ulations. Operator, Well N~re ~mnd N~ntcr Reports and Materials to be received by: //-d~'~--~/ Date Required Date Received Cc~pletion Report Yes Well History Yes _Samples ....... /~,~-- p~ ~re ~ips Core ~scription ...... Registered. ~ Su~ey Plat ~ ~ ~ --~ 2-' ~/ Dire~ional ~ey //- Drill St~ Test Re~s ~:,:e ,, ~o ~r~r ,' ........ ._ SOHIO RESTRICTED SOHIO ALASKA PETROLEUM COMPANY · ARCO .......... C, bcvmo · o:.. SFO/UNIT/ST: Mo~ ..... - 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 10/29/81 STATE: 10/30/81 '9' 1i49- REFERENCE: SOHIO FINAL DATA. M-!6 L/The following material is bein~"~ubmitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: M-16 DIL/SFL M-16 BHCS M-16 FDC M-I6 FDC/CNL OPEN HOLE FINAL LOGS (Sch) 9/25/81 & 9/29/81 " 9/29/81 " 9/29/81 " 9/29/81 #1&2 2" & 5" #1 2" & 5" #1 2" & 5" #1 2" & 5" STATE ONLY: M-16 Magnetic Single Shot,,Survey M-16 ~/' Gyro-Multi Shot Survey 'DIRECTIONAL SURVEYS 9/9-30/81 10/16/81 Job# 0981-030 Job# A1081G0062 C~i ,~eter W~7~Records ' SOHIO ALASKA PETROLEUM COMPANY S0H I 0 C0 IF IDENT IAL 3111 "C" ANCHORAGE. ALASKA TELEPHONE (907) 265-00OO MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 A~CO TO: EXXON Date: 10/20/81 ~ 1126 PHILLIPS SFO · REFERENCE: .~~ThefSOHIO MAGNETIC LIS TAPES ollowing material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- 'O/AEP/ST: ~/ 'ag,n, ~R-1.9 " " " "' ~A-1 ~/ " " " " OH/DILIBHC/FDC/CNL OH/DIL/BHC/FDC/CNL OH/DIL/BHC/FDC/CNL CH/TDT-M 10/3/81 ¢~1 ft62221 9/29/81 ¢I1&2 ¢/62217 9/27/81 ¢/1&2 ~/62214 10/8/81 ~/2 ~/62224 (Sch) ? 8 C~' Ca~ 1 Krie r 0CT .,.. . ], ~!.:. ~_ r/~.l_ Alaska 0il & Gas Cons. O0mmissi~l ~ords HQ ~-5 Anchorage ALASKA OIL AND -GAS CONSERVATION COMMISSION ~oyle H. Hami Chairman Thru: Lonnie C. Smith Commissioner Bobby Foster Petroleum Inspector September 17, 1981 Witn~ess BOPE Test on SOHIO'S M-16 · Sec. 1, TllN, R12E, UPM Permit #81-86 ..S._u.n.day september 13~ 198~1 - After witnessing the BOPE test on SOHiO'S 'R-19 i went. to M-16 to witness the upcoming BOPE test. Monday_ Septe~mbe_ r 1~4~_ 1981 - The BOPE test began at 2..00 a.m. and was-COmpieted at 4.'30 a.m. As the attached BOPE inspection report shows there were no failures. In summary I witnessed the BOPE test on SOHIO's M-16. InsPector . . · Operator '-. " Representative Well ' _/~ ' /& · Permit # Location: sec 'i / ;T//~R//.~ M ~d~ '-- Drilling Contractor~'~-'."~J//~,~,~ Rig #~'-~;~Representat'iv~ Location, Ge'neral .~/'~' ACCUMULATOR SYSTEM Wel.k Sign General Housekeeping Reserve pit ~/C/~..'' ' '1 BOPE 'stack Annular Preventer___~_~ Pipe Rams~ Blind Rams~ Choke. Lin~ valV.e.s~ H.C,. R. Valve-- Kill Line Valves'~ Check Valve Full charge Pres sure~t~i~--C~ Hydrauically operated choke Test Results: Failures ~-- TeS~" ¥ 2~-' '-'--~~~s. Repair or Replacement of failed equipment to be made within days and ps ig Pressure After Closure/~L~:9 .psig 200 psig Above Precharge ~Attained: -- 'min~ sec Full'Charge Pressure Attained: ~ . .mi~ sec N2 ~ ~/cr~ /.~o Controls: Master ~ ~ / Remote ~J O'linds switch'cover~~ Kelly and Floor Safety Valves , Upper Kelly. '" Test Pressure Lower Kelly /' Test Pressure . Ball Type /. Test Pr-assure Inside BOP / Test Pres~re Choke Manifold ~;~ Test Pressure,-~~''gf-~ No- Valves / ~ . No. flanges J~ Adjustable Chokes /. Inspector/Commission office notified. Remarks: Distribution orig.' ' AO&GCC cc - Operator cc - Supervisor Inspector '0:' /:' '1 '"' ~ ~'~' / June 23, 1981 Mr. R. R. Reiley District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Rex Prudhoe Bay Unit M-16 (41-36-12-12) ARCO Alaska, Inc. Permit No. 81-86 Sur. Loc.~ 1607'SNL, 605'W~L, .Sec 1, T12~, R12E, UPM Bottomhole Loc. I 266'SNL, 881'WEL, Sec 36,. T12N, R12E, UPM Dear Mr. Reiley I Enclosed is the apprc~ed application for permit to drill the above referenced wel 1. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to c~mmencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70} and by the Federal Water Pollution Control Act, as amended. Prior to Mr. R. H~. Reiley PBU M-16 (41-36-12-12) -2- June 23, 1981 co~mencing operations you may be contacted by a representative. of the Department of Environmental Conservation. To at~: us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded- We would also like to be notified so that a repre- sentative o£ the com~ission may be, present to witness testing of blowout preventer' equipment before surface casing shoe is dril left.. In the event of suspension or abandonment, please give this office adequate advance notification so. that we may have a witness present. Very truly yours, H. Hamilton Alaska O~1 & Gas Conse~'~ation Commission Enc lo sure cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. SOHIO ALASKA PETROLEUM COMPANY June 18, 1981 3111 °'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Cc~mission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well M-16 (41-36-12-12) Enclosed are the following documents, in triplicate, along with our check for $100.00 to cover permit filing fees. 1. Application for Permit to Drill, 2. Proposed Drilling Program Outline, 3. Blowout Prevention Equipment Diagram, 4. Surveyor ' s plat showing well location, 5. Directional plan. If you have any questions, please contact either R. H. Reiley at 265-0183 or K. W. Kolthoff at 265-0176. RHR: ja Enclosures cc: Well File 917 Yours very truly, R. H. Reiley District Drilling Engineer JUN ? 2 Oil & Gas Cons, Commission Anchorag · ~ STATE OF ALASKA ALASI~,,~ OIL AND GAS CONSERVATION[. )MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHlC I--I REDRILL [] DEVELOPMENT OIL[] SINGLE ZONE DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum ~y 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of well at surface 9. Unit or lease name 1607' SNL, 605' WEL, Sec. 01, T!IN, R12E, UPM Prudhoe Bay Unit At top of proposed producing interval ] -%, 10. Well number 780' SNL, 860' WEL, SeC. 36, T~, R12E, UPM M-16 (41-36-12-12) At total depth,'u 11. Field and pool 266' SNL, 881' WEL, Sec. 36, T~iN, R12E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF etc.) I 6, Lease designation and serial no. Prudhoe Oil Pool Est. KBE = 56 ' _.AMSLI ADL 28257 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number Safeco Ins. 2975387 · Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed' ' NW of Deadhorse 10 miles west of ADL 28279 860feet welI SW of M-14 1990 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18, Approximate spud date 12001'MD 93661TVD feet 2459 September 15, 1981 120. Anticipated pressures 3330 · .19. If deviated (see 20 AAC 25.050) psig@ Surface KICK OFF POINT 1600 feet. MAXIMUM HOLE ANGLE 45 °l(see 20 AAC 25.035 (c) (2) 4480 .... psig@. 9200 .ft. i[l~I (TVD)S 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF'CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 36" 20x30 [nsulab;d Condttctor :~..i:Z.80 Surface 110~I 110 8 cu.¥ds, concrete 17 1/~ 13 3/8 72~ L-80 Butt. 2710 'Surface 2710I 2680 3720 cu.ft, permafr°s 12 1/4 9 5/8 47~ L-80 Butt. 10760 Surface 107601 8490 1565 cu. ft. Class G; i I 130 cu.ft, permafros 8 1/2 7 29~ L-80 Butt. 1745 10255 ~, 8135 12000 I~ 9365 340 cU.ft. ClaSS G 22. Describe proposed program: W/18% salt: See attached proposed drilling program outline. '~,, ~<~ 0ii & Ga-~ Cons. C0mmlssior~ ~. A~ch0ra§~: JLG 23. I hereby certify that the foregoin_~i.s true. and correct to the best of my knowledge The space below for Commission use R. H. Re~ley .. CONDITIONS OF APPROVAL Samples required Mud Icg required Directional Survey required APl number []YES ~JNO [-]YES ~NO ~YES []NO 50-0 Permit number ~'/~ Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS 06/23/81 APPROVED B~ ,COMMISSIONER DATE June 23, 1981 by order of the Commission t Il Form 10-401 Submit ia triplicate Rev. 7-1-80 PROPOSED DRILLING & C~P~I~ PROGRAM WELL M-16 (41-36-12-12) Dry bucket 36" hole to 80'" belc~ ground level and cement 20" x 30" insulated conductor to surface using 8 cu.yds, concrete. Drill 17 1/2" hole vertically to 1600', then drill directionally to 2700' and cement 13 3/8" 72# L-80 Buttress casing to surface using 3720 cu ft. Permafrost II cement. ' Blowout Prevention Program consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer from 13 3/8" casing point to T.D. Maximum possible bottcmhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12 1/4" hole to 8490' TVD. Run 9 5/8" 47# L-80 Buttress casing to 8490' TVD and cement first stage with 1565 cu. ft. Class G cement. Cement second stage through D.V. packer collar at 2600' with 130 cu. ft. Perma- frost C cement. 9 5/8" casing will be hung at surface, the 9 5/8" x 13 3/8" annulus will be Arctic Packed. Drill 8 1/2" hole to T,D. at 9365' TVD. Cement 7" liner to 500' inside 9 5/8" casing shoe with 340 cu.ft. Class G cement with 18% salt. Run 5 1/2" 175 L-80 AB-~, Butt. IPC tbg. w/12 gas lift mandrels and a pro- duction packer assembly at 8100' TVD. A subsurface safety valve with dual control lines will be placed at 2000'. Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release. Details of proposed perforations to be submitted on Sundry .Notice to follow. JLG: ja 6/5/81 TRIPLE RAM 5O0O PSI WP DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS 2" KILL LINE CHECK GATE GATE DRILLING SPOOL CHOKE LINE GATE HYDR. ASST. GATE PiPE RAMS I I 13 ~'3/- TRIPLE RAM 5000 PSI WP DRILLING Z" KILL LINE CHECK GATE GATE ANNULAR PREYENTER ,,.1 1 PIPE t F RAMS BLIND RAMS I t CHOKE LINE DRILLING SPOOL PIPE RAMS I I HAND GATE HYDR. ASST. GATE OI 02 05 02 OI 02 R.12E., R.I$ E. i 40 I0 20 $0 40 ! I WELLS Ir LONG. 14eo57' $4.73"- Y= 5,974, 550 t I PAD DETAIL I .... ~' .................... 49o5' I SCALE I" = 300' I I I PORTION OF I CERTIFICATE OF SURVEYOR I hereby certify that tam properly registered to practice land surveying in the State of Alaska and that this plat represents a location survey of the wellpad shown and the well thereon. This survey was made by me or under my supervision and all dimensions and other details are correct. 8attain hole }ocations are furnished by others. Date Surveyor NOTE~ All bottom holes are 8800' subseo. , ,, ......,, REVISED BHL M-t6 REVISED BHL M- 12~15~l~16 REVISED BHL M-IS& M-14 FROM PROPOSED TO ACTUAL ADDED PROPOSED BHL M-Il, 12, i5, & 16 REV. LOC. PROPOSED M-IS BHL ~ REMOVED PROPOSED M- 12 BHL REVISED PLAT TOSHOW AS-BUILT SURFACE LOCATION ADD M-f2 B M-J3 PROPOSED BHL Cons. Com. missior~ k~chora~e PJR 6/2/el DHO 4 /7 /9 I PJR RDR 2/IS/81 PdR Il/lO/80 PJR I0/16/cO. PJR PAD "M" EXTENSION Located in E [/2 .PROTRACTED SEC. ! =T: IIN.~ R. t2E..,UMIAT MERIDtAN~,LASKJ Surveyed for SOHIO ALASKA PETROLEUM CO. I II Surveyed by F.M. LINDSEY 1~ ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-08I Anchorage Alaska BEU. CHECK LIST FOR NEW WELL PERMITS Company ITEM APPROVE DATE 1. Is the permit fee attached .................... 2. Is well to be located in a defined poil'iiiii: 3. Is well located proper distance from property in 4. Is well located proper distance from other wells ............. 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included ........ 7. Is operator the only affected party .......................... 8. Can permit be approved before ten-day wait ................... (3) Admin ~ ~_ g- ~x~ ~/ 9. (ythr~ 11) 10. 11. (12 thru 20) 12. 13. 14. 15. 16. 17, 18. 19. 20. 2) ~- 22'gI 21. (21 "tfiru 24) 22. 23. 24. (5) BOPE (6) Add: ~ /~-22--e~ 25. eeeee YES NO .. oo ?~- REMARKS Does operator have a bond in force .................................. Is a conservation order needed · Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones . ............... - ....... Will all ~asing give adequate safety in collapse, tension' and burst.. Is this well to be kicked off from an existing wellbore ............. is old wellb°re abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~ _ Are necessary diagrams of diverter and BOP equipment attached....... ~ Does BOPE have sufficient pressure rating - Test to &'~POO psig''' Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. __ Additional Remarks: ~/~_j /~./¢~,~i ~-~-~/.. ~~ /~?,/4. f..- Geology: Engineering: -- HWK_~ LCS~BEW__ WVA JKT ~_ RAD rev: 03/10/81 ~ INITIAL I "GE'O. ' uNiT .... ON/O~F POOL CLASS STATUS[ AREA NO.' SHORE ,, Well Histo.ry 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 ....... * ****************************** RECE ED SEP 24 1998 Naska 0i1 & Gas Cons, Commissio~ Anchorage COMPANY NAME : BP EXPLORATION (ALASKA) , INC. WELL NAME : M- 16 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292061300 REFERENCE NO : 98458 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/09/15 ORIGIN : FLIC REEL NAME : 98458 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, PRUDHOE BAY, M-16, API #50-029-20613-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/09/15 ORIGIN : FLIC TAPE NAME : 98458 CONTINUATION # : 1 PREVIOUS TAPE : COMFIENT : BP EXPLORATION, PRUDHOE BAY, M-16, API #50-029-20613-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: M- 16 API NUPIBER: 500292061300 OPERATOR: BP EXPLORATION (ALASKA) , INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 15-SEP-98 JOB NUMBER: 98458 LOGGING ENGINEER: S DECKERT OPERATOR WITNESS: L PHONG SURFACE LOCATION SECTION: 1 TOWNSHIP: 1 IN RANGE: 12E FNL : 1606 FSL: FEL: 606 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 52.30 DERRICK FLOOR: 51.30 GROUND LEVEL: 27.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .............................................. 1ST STRING 8. 500 5. 000 11592.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTD 88888.0 88887.5 88887.5 11377.0 11376.5 11376.5 11370.0 11370.0 11370.0 11338.5 11339.0 11338.0 11338.5 11336.5 11336.5 11336.0 11336.5 11332.5 11332.5 11332.5 11279.5 11280.5 11280.5 11235.5 11235.5 11235.5 11216.0 11216.0 11216.0 11204.5 11206.5 11206.5 11181.5 11181.5 11180.5 11181.5 11156.5 11158.5 11158.5 11146.5 11147.0 11147.0 11140.0 11142.0 11142.0 11133.0 11136.0 11132.5 11135.0 11114.0 11116.0 11113.5 11116.0 11096.5 11098.0 11098.0 11094.0 11096.0 11096.0 11092.5 11092.5 11092.5 11085.5 11088.0 11088.0 11083.5 11085.0 11085.0 11080.5 11082.0 11082.0 11078.0 11078.5 11078.5 11038.5 11039.0 11039.0 11024.0 11025.5 11025.5 11014.5 11015.5 11014.0 11016.0 11012.5 11013.0 11013.0 11007.0 11008.0 11006.5 11008.0 10993.5 10996.0 10996.0 10991.5 10993.0 10991.0 10993.5 10989.5 10991.0 10991.0 10979.5 10982.0 10982.0 10978.0 10980.0 10980.0 10956.0 10958.0 10958.0 10953.0 10955.0 10955.0 10950.5 10952.0 10952.0 10945.5 10947.5 10947.5 PAGE: 2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 10941.5 10944.0 10944.0 10939.5 10942.0 10942.0 10937.0 10938.5 10938.5 10935.5 10937.0 10937.0 10933.5 10936.0 10936.0 10931.0 10933.0 10930.5 10933.0 10926.5 10928.0 10928.0 10922.5 10924.0 10924.0 10916.5 10918.0 10918.0 10913.0 10914.0 10914.0 10908.5 10910.0 10908.0 10910.0 10905.0 10906.5 10906.5 10902.0 10903.0 10903.0 10897.5 10898.5 10898.5 10889.0 10890.0 10890.0 10882.0 10883.0 10883.0 10879.0 10881.0 10881.0 10875.0 10877.0 10877.0 10872.5 10874.0 10874.0 10855.0 10859.5 10859.5 10849.5 10853.0 10853.0 10848.0 10850.0 10847.5 10849.5 10840.5 10843.0 10843.0 10837.5 10840.0 10840.0 10835.5 10838.0 10838.0 10821.5 10822.5 10822.5 10810.0 10810.5 10811.0 10802.0 10804.0 10801.5 10804.0 10794.0 10795.0 10795.0 10769.0 10770.0 10770.0 10762.5 10764.0 10764.0 100.0 101.$ 101.5 $ REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTD DATA AQUIRED ON BP EXPLORATION'S M-16 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BASE GAF~VlA RAY, ALSO PASS #1 NPHI AND THE BASE GAM~A RAY, CARRYING ALL CNTD CURVES WITH THE NPHI SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREFIENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11394.5 10751.5 CNTD 11406.5 10751.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTD .............. REMARKS: THIS FILE CONTAINS CASED HOLE CNTD PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE ARE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP RLRM CODE (HEX) DEPT FT 1224600 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTD PU-S 1224600 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTD 1224600 O0 000 O0 0 1 1 1 4 68 0000000000 CRATCNTD 1224600 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNTD CPS 1224600 O0 000 O0 0 1 1 1 4 68 0000000000 FCNTCNTD CPS 1224600 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTD CPS 1224600 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTD CPS 1224600 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTD GAPI 1224600 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTD LB 1224600 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTD V 1224600 O0 000 O0 0 1 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 11406.500 NPHI. CNTD 30.189 NRAT. CNTD 4.505 CRAT. CNTD NCNT. CNTD 2932.020 FCNT. CNTD 650.848 CFTC. CNTD 634.435 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1753.000 CCL.CNTD 0.000 DEPT. 10751.500 NPHI.CNTD 55.156 NRAT. CNTD 7.392 CRAT. CNTD NCNT. CNTD 1591.710 FCNT. CNTD 215.321 CFTC. CNTD 209.891 CNTC. CNTD GRCH. CNTD 19.538 TENS. CNTD 1747.000 CCL.CNTD 0.000 5. 067 3176. 654 7. 915 1686. 962 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : OOICO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH IN~: 0. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11395.5 10752.0 CNTD 11406.0 10753.5 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD REMARKS: THIS FILE CONTAINS CASED HOLE CNTD PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CNTD CURVES WITH THE NPHI SHIFTS. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE TYPE REPR CODE VALUE 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE AF3F~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELE~ CODE (HEX) DEPT FT 1224600 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 1224600 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTD 1224600 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTD 1224600 O0 000 O0 0 2 1 1 4 68 0000000000 NCNTCNTD CPS 1224600 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTD CPS 1224600 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 1224600 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 1224600 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 1224600 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 1224600 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 1224600 O0 000 O0 0 2 I 1 4 68 0000000000 ** DATA ** DEPT. 11406.000 NPHI. CNTD 27.211 NRAT. CNTD 4.163 CRAT. CNTD NCNT. CNTD 2949. 900 FCNT. CNTD 708. 661 CFTC. CNTD 690. 791 CNTC. CNTD GRCH. CNTD -999. 250 TENS. CNTD 1777. 000 CCL. CNTD O. 000 DEPT. 10752.000 NPHI. CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 18.943 TENS. CNTD -999.250 CCL. CNTD -999.250 4.700 3126.574 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: **** FILE HEADER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11395.5 10742.0 CNTD 11406.5 10743.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 11384.5 11384.0 11372.0 11368.5 11357.0 11352.0 11341.0 11339.0 11335.5 11330.5 11324.5 11319.0 11318.0 11303.0 11299.0 11290.5 11284.0 11282.5 11279.5 11265.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD .............. 88888.5 88887.5 11385.0 11383.5 11372.5 11370.0 11358.0 11352.0 11341.0 11339.0 11335.0 11331.0 11324.0 11319.5 11318.0 11303.0 11300.0 11290.5 11284.0 11282.0 11280.0 11264.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 11254.0 11255.5 11244.5 11244.0 11244.0 11244.0 11221.5 11221.0 11217.0 11216.0 11216.5 11215.0 11201.0 11200.5 11195.0 11195.0 11186.0 11186.5 11182.5 11182.0 11180.0 11181.0 11163.5 11164.5 11161.0 11159.0 11148.5 11150.0 11141.0 11142.0 11125.5 11124.5 11122.0 11120.5 11121.5 11124.5 11117.0 11116.5 11107.5 11108.5 11096.5 11098.0 11095.5 11097.5 11084.0 11085.0 11081.5 11082.0 11081.0 11082.0 11078.5 11078.5 11074.0 11074.0 11072.0 11071.5 11066.5 11067.5 11061.5 11062.5 11057.0 11057.0 11055.5 11055.0 11055.0 11053.5 11046.5 11046.5 11038.5 11039.0 11033.0 11033.0 11022.0 11023.0 11019.0 11020.5 11017.5 11019.5 11014.5 11015.5 11013.0 11013.5 11009.0 11008.0 11007.5 11008.0 11002.5 11004.0 10993.5 10996.0 10993.0 10993.0 10991.5 10993.0 10989.5 10991.5 10977.0 10980.0 10973.5 10976.0 10967.0 10969.5 10962.5 10966.0 10956.0 10958.0 10952.5 10955.5 10952.0 10955.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE 10 10950.0 10952.0 10945.5 10947.5 10945.0 10947.5 10939.5 10942.0 10942.0 10935.0 10936.5 10934.0 10936.0 10931.5 10933.0 10930.0 10932.5 10927.0 10928.0 10921.0 10922.0 10919.5 10920.0 10918.5 10920.0 10917.5 10918.0 10914.0 10914.0 10911.0 10912.0 10909.0 10909.5 10905.5 10906.5 10907.0 10901.0 10901.0 10900.5 10900.5 10894.0 10895.0 10890.0 10890.5 10883.0 10883.0 10884.5 10872.5 10874.0 10866.5 10868.0 10851.5 10853.0 10847.5 10849.5 10840.5 10843.0 10839.0 10842.0 10838.5 10840.0 10831.0 10833.5 10820.5 10820.5 10817.0 10818.5 10813.0 10816.0 10808.5 10810.5 10804.5 10807.0 10800.5 10801.0 10793.5 10795.5 10780.0 10782.0 10775.0 10775.5 10774.0 10777.0 10772.0 10773.5 10766.0 10767.5 10759.5 10761.5 100.0 102.0 103.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE CNTD PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYING ALL CNTD CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 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 ELE~ CODE (HEX) ....................................................................................... O0 000 O0 0 3 1 1 4 68 0000000000 DEPT FT 1224600 NPHI CNTD PU-S 1224600 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTD 1224600 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTD 1224600 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTD CPS 1224600 O0 000 O0 0 3 1 i 4 68 0000000000 FCNT CNTD CPS 1224600 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTD CPS 1224600 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTD CPS 1224600 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTD GAPI 1224600 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 1224600 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTD V 1224600 O0 000 O0 0 3 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 11406.500 NPHI.CNTD 29.045 NRAT. CNTD 4.409 CRAT. CNTD NCNT. CNTD 2970.464 FCNT. CNTD 673.684 CFTC. CNTD 656.696 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1820.000 CCL.CNTD 0.000 DEPT. 10742.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 17.955 TENS. CNTD -999.250 CCL.CNTD -999.250 4.928 3154.959 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 12 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, CNTD $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF 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 15-SEP-1998 10:40 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 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 ELE~ CODE (HEX) DEPT FT 1224600 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1224600 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1224600 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1224600 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1224600 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1224600 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1224600 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1224600 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 1224600 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 1224600 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11406.500 NPHI.CNAV -999.250 NRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV GRCH. CNTD -999.250 TENS. CNTD 1753.000 DEPT. 10751.500 NPHI.CNAV -999.250 NRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV GRCH. CNTD 19.538 TENS. CNTD 1747.000 -999. 250 CRAT. CNAV -999. 250 CNTC. CNAV -999. 250 C~T. CNAV -999. 250 CNTC. CNAV -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 14 **** FILE TRAILER **** FILE NAM~ : ~DIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : OFILE HEADER FILE NUMBER 5 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 SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 11440.0 10744.5 CNTD $ LOG HEADER DATA DATE LOGGED: 20-JUN-98 SOFTWARE VERSION: 8C0 - 609 TIME LOGGER ON BOTTOM: 1037 20-JUN-98 TD DRILLER (FT) : 11415.0 TD LOGGER (FT) : 11420.0 TOP LOG INTERVAL (FT): 10750.0 BOTTOM LOG INTERVAL (FT) : 10407.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNTD COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER ........... CGRS-A 820 CNT- D 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 15 DRILLERS CASING DEPTH (PT): LOGGERS CASING DEPTH (PT): 11592.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE Tb~4PERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 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): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS GR/CCL DATED 3-AUG-91. TEST DATA 5-25-98:2.96 MBPD, 1.05 MBOPD, .1.91 MBWPD, 2.65 M~SCFD. LIFT GAS 3.51,CHOKE 96, 118 MAN PSI, 130 DEGF MAN. LOGGED ON SANDSTONE MATRIX, USING 2.5" CNTD. LOGGED 3 PASSES @iSO0'/HR. 7"26# CASING FROM 10314 - 11750' & 5"18# FROM 10194-11592' THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 16 TYPE REPR CODE VALUE .............................. 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 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 1224600 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1224600 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1224600 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1224600 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 1224600 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1224600 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1224600 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1224600 O0 000 O0 0 5 1 1 4 68 .0000000000 GR PS1 GAPI 1224600 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1224600 O0 000 O0 0 5 1 1 4 68 0000000000 CCLD PS1 V 1224600 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11440.000 NPHI.PS1 24.351 RTNR.PS1 4.000 TArR~.PS1 RCNT. PS1 3878.788 RCFT. PS1 969.697 CNTC. PS1 4096.415 CFTC. PSi GR.PS1 0.000 TENS.PSi 800.000 CCLD. PS1 0.115 DEPT. 10744.500 NPHI.PS1 56.746 RTNR.PS1 7.301 TNRA.PS1 RCNT. PS1 1721.519 RCFT. PS1 235.789 CNTC. PS1 1796.177 CFTC. PSI GR.PS1 21.409 TENS.PSi 1749.000 CCLD. PS1 -999.250 4.334 945.244 8.097 229.844 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 17 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : OFILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 11438.0 10745.5 CNTD $ LOG HEADER DATA DATE LOGGED: 20-JUN-98 SOFTWARE VERSION: 8C0- 609 TIME LOGGER ON BOTTOM: 1037 20-JUN-98 TD DRILLER (FT) : 11415.0 TD LOGGER (FT) : 11420.0 TOP LOG INTERVAL (FT) : 10750.0 BOTTOM LOG INTERVAL (FT) : 10407.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GA~k~A RAY CNTD COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER ........... CGRS-A 820 CNT-D 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 18 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 11592.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE T~4PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 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): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS GR/CCL DATED 3-AUG-91. TEST DATA 5-25-98:2.96 MBPD, 1.05 ~iBOPD, .1.91 MBWPD, 2.65 ~SCFD. LIFT GAS 3.51,CHOKE 96, 118 MAN PSI, 130 DEGF MAN. LOGGED ON SANDSTONE MATRIX, USING 2.5" CNTD. LOGGED 3 PASSES @iSO0'/HR. 7"26# CASING FROM 10314 - 11750' & 5"18# FROM 10194-11592' THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 19 TYPE REPR CODE VALUE .............................. 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 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 ELE~I CODE (HEX) DEPT FT 1224600 O0 000 O0 0 6 1 1 4 NPHI PS2 PU 1224600 O0 000 O0 0 6 1 1 4 RTNR PS2 1224600 O0 000 O0 0 6 1 1 4 TNRA PS2 1224600 O0 000 O0 0 6 1 1 4 RCNT PS2 CPS 1224600 O0 000 O0 0 6 1 1 4 RCFT PS2 CPS 1224600 O0 000 O0 0 6 1 1 4 CNTC PS2 CPS 1224600 O0 000 O0 0 6 1 1 4 CFTC PS2 CPS 1224600 O0 000 O0 0 6 1 1 4 GR PS2 GAPI 1224600 O0 000 O0 0 6 1 1 4 TENS PS2 LB 1224600 O0 000 O0 0 6 1 1 4 CCLD PS2 V 1224600 O0 000 O0 0 6 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. RCNT. PS2 GR.PS2 11438.000 NPHI.PS2 70414.844 RTNR.PS2 1882.353 RCFT. PS2 0.000 CNTC.PS2 0.000 TENS.PS2 909.000 CCLD.PS2 DEPT. RCNT. PS2 GR.PS2 10745.500 NPHI.PS2 1656.315 RCFT. PS2 23.726 TENS.PS2 59.933 RTNR.PS2 223.176 CNTC. PS2 1764.000 CCLD.PS2 -999.250 TNRA.PS2 -1082.615 1987.966 CFTC. PS2 0.000 0.038 7.422 TNRA.PS2 8.462 1766.433 CFTC. PS2 217.548 -999.250 ** END OF DATA ** LIS Tape Veri£ication Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 2O **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : OFILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 11437.0 10738.0 CNTD LOG HEADER DATA DATE LOGGED: 20-JUN-98 SOFTWARE VERSION: 8C0- 609 TIME LOGGER ON BOTTOM: 1037 20-JUN-98 TD DRILLER (FT) : 11415.0 TD LOGGER (FT) : 11420.0 TOP LOG INTERVAL (FT) : 10750.0 BOTTOM LOG INTERVAL (FT) : 10407.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNTD COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER ........... CGRS-A 820 CNT- D 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 21 DRILr. R~S CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 11592.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~4PERATURE (DEGF) : BOTTOM HOLE T~4PERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 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): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS GR/CCL DATED 3-AUG-91. TEST DATA 5-25-98:2.96 MBPD, 1.05 MBOPD, .1.91 MBWPD, 2.65 M~SCFD. LIFT GAS 3.51,CHOKE 96, 118 MAN PSI, 130 DEGF MAN. LOGGED ON SANDSTONE MATRIX, USING 2.5" CNTD. LOGGED 3 PASSES @iSO0'/HR. 7"26# CASING FROM 10314 - 11750' & 5"18# FROM 10194-11592' THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 22 TYPE REPR CODE VALUE .............................. 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 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 ELE~ CODE (HEX) ....................................................................................... DEPT FT 1224600 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1224600 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1224600 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1224600 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1224600 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1224600 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1224600 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1224600 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1224600 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1224600 O0 000 O0 0 7 1 1 4 68 0000000000 CCLD PS3 V 1224600 O0 000 O0 0 7 I 1 4 68 0000000000 ** DATA ** DEPT. 11437.000 NPHI.PS3 24.351 RTNR.PS3 4.000 TNRA. PS3 RCNT. PS3 4000.000 RCFT. PS3 1000.000 CNTC. PS3 4224.429 CFTC. PS3 GR.PS3 27.969 TENS.PS3 823.000 CCLD.PS3 -0.010 DEPT. 10738.000 NPHI.PS3 63.438 RTArR.PS3 9.244 TNRA. PS3 RCNT. PS3 1685.950 RCFT. PS3 182.383 CNTC. PS3 1783.720 CFTC. PS3 GR.PS3 21.340 TENS.PS3 1769.000 CCLD.PS3 -999.250 4.334 974.783 8.863 177.784 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-SEP-1998 10:40 PAGE: 23 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/09/15 ORIGIN : FLIC TAPE NAME : 98458 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : BP EXPLORATION, PRUDHOE BAY, M-16, API #50-029-20613-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/09/15 ORIGIN : FLIC REEL NAME : 98458 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, PRUDHOE BAY, M-16, API #50-029-20613-00 * ALASKA COMPUTING CENTER * . . * ............................ . * ....... SCHLUMBERGER ....... * RECEIVED SEP ~4 ~998 Gas Cons. Commi~on Anchorage COMPANY NAME : BP EXPLORATION WELL NAME : M- 16 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292061300 REFERENCE NO : 98450 14-SEP-1998 12:36 PAGE: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/09/14 ORIGIN : FLIC REEL NAME : 98450 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, M-16, PRUDHOE BAY, API# 50-029-20613-00 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE : 98/09/14 ORIGIN : FLIC TAPE NAME : 98450 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, M-I6, PRUDHOE BAY, API# 50-029-20613-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: M- 16 API NUMBER: 500292061300 OPERATOR: BP Exploration LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 14-SEP-98 JOB NUMBER: 98450 LOGGING ENGINEER: H. KIRKBY OPERATOR WITNESS: JACK RATHERT SURFACE LOCATION SECTION: 1 TOWNSHIP: 1 IN RANGE: 12E FNL: 1606 FSL: FEL: 606 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 52.30 DERRICK FLOOR: 51.30 GROUND LEVEL: 27.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .............................................. 1ST STRING 8. 500 5. 000 11750.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. 88888.0 11381.0 11379.5 11378.5 11341.0 11339.5 11335.0 11333.5 11229.0 11189.0 11188.0 11161.5 11137.5 11095.0 11084.0 11022.5 11021.5 11013.0 11012.5 11010.0 10994.5 10994.0 10990.5 10990.0 10970.0 10969.5 10951.5 10943.0 10940.5 10939.5 10935.0 10933.0 10926.5 10923.5 10922.0 10917.5 10898.5 10880.0 10872.5 10872.0 10847.5 10846.5 10838.0 10835.5 10819.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88885.5 88887.0 11378.5 11378.5 11376.0 11339.0 11339.0 11332.5 11332.5 11229.0 11229.0 11189.0 11189.0 11162.0 11162.0 11138.5 11138.5 11096.0 11096.0 11085.0 11085.0 11023.0 11023.0 11013.0 11013.0 11010.0 10995.5 10995.5 10991.0 10991.0 10970.5 10970.5 10952.0 10952.0 10944.0 10942.0 10942.0 10936.0 10936.0 10927.5 10927.5 10924.0 10924.0 10921.5 10921.5 10918.0 10918.0 10898.5 10898.5 10880.5 10880.5 10874.0 10874.0 10849.5 10849.5 10840.0 10840.0 10820.0 10820.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 10769.0 10770.0 10770.0 100.0 101.0 101.0 $ CONTAINED HEREIN IS THE RST SIGMA-MODE DATA ACQUIRED ON BP EXPLORATION WELL M-16 ON 30-MAY-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA-MODE PASS #1 GRCH TO THE BASELINE GAMMA RAY PROVIDED BY THE CLIENT (GR.BCS) ; AND RST SIGMA-MODE PASS #1 SIGM TO GR. BCS. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/14 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 SUM~NL~Y LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11382.0 10762.0 RST 11401.0 10762.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GR PASS NUMBER: 1 BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. REFZAPJfS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ~ 14-SEP-1998 12:36 PAGE: 4 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** 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 EL~ CODE (HEX) ....................................................................................... DEPT FT 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1244212 O0 000 O0 0 i 1 1 4 68 0000000000 SBNA FIL CU 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1244212 O0 000 O0 0 1 I 1 4 68 0000000000 CIRNFIL 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 BSALRST PPK 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 CRRARST 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1244212 O0 000 O0 0 1 1 1 4 68 0000000000 14-SEP-1998 12:36 PAGE: 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** DATA ** DEPT. 11400.000 NBAC.RST 2592.521 FBAC.RST 3581.742 SBNA.FIL SFNA.FIL 18.989 SBFA.FIL 44.616 SFFA.FIL 16.150 TRAT. FIL IRAT. FIL 0.399 CIRN. FIL 0.828 CIRF. FIL 2.165 BSAL.RST SIBF. RST 80.009 TPHI.RST 39.674 SFFC.RST 14.253 SFNC.RST SIGM. RST 14.200 DSIG.RST 2.648 FBEF. RST 56.127 CRRA.RST GRCH.RST -999.250 TENS.RST 1722.000 CCL.RST 0.000 DEPT. 10763.000 NBAC.RST 2518.438 FBAC.RST 3491.361 SBNA.FIL SFNA.FIL 50.676 SBFA.FIL 63.940 SFFA.FIL 52.174 TRAT. FIL IRAT. FIL 0.478 CIRN. FIL 0.229 CIRF. FIL 0.350 BSAL.RST SIBF.RST 80.000 TPHI.RST 57.499 SFFC.RST 47.937 SFNC.RST SIGM. RST 47.975 DSIG.RST 1.285 FBEF. RST 38.224 CRRA.RST GRCH. RST 87.372 TENS.RST 1739.000 CCL.RST -0.014 62.851 0.965 154.132 17.201 2.422 70. 750 1.404 154.111 47.484 2.107 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUF~fARY LDWG TOOL CODE START DEPTH STOP DEPTH 14-SEP-1998 12:36 PAGE: 6 LIS Tape Verification Listing Schlumberger Alaska Computing Center GRCH 11382.0 10742.0 RST 11401.0 10742.0 $ CURVE SHIFT DATA - PASS TO PASS (~AS[PRF~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 BASELINE DEPTH .............. 88888 0 11379 5 11340 0 11339 0 11335 0 11333 5 11329 5 11316.0 11285.5 11257.5 11232.0 11196.5 11183.0 11167.5 11141.5 11138.5 11109.0 11095.0 11085.0 11084.0 11078.5 11072.0 11062.5 11057.0 11051.0 11036.0 11023.0 11021.5 11019.5 11013.5 11012.5 10995.5 10991.5 10990.0 10980.0 10969.5 10954.0 10952.0 10943.5 10942.5 10939.0 10933.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH RST .............. 88884.5 88887.0 11378.5 11336.5 11333.0 11284.0 11138.5 11096.0 11085.5 11072.5 11058.0 11023.0 11013.0 10995.5 10991.0 10968.5 10952.0 10944.0 11339.0 11332.5 11328.0 11315.5 11257.5 11231.5 11.197.5 11184.0 11168.0 11142.0 11110.0 11085.0 11080.0 11063.0 11052.0 11037.0 11023.0 11020.0 11013.0 10991.0 10981.0 10970.5 10954.5 10943.5 10941.5 10935.5 ~, 14-SEP-1998 12:36 PAGE: 7 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10927.5 10927.5 10923.0 10923.5 10918.5 10918.0 10908.0 10908.0 10903.5 10903.0 10899.5 10899.0 10896.0 10896.0 10885.0 10885.0 10883.5 10883.0 10880.5 10880.5 10873.5 10874.0 10872.0 10874.0 10863.0 10864.0 10854.5 10857.0 10848.5 10849.5 10841.5 10842.5 10839.5 10842.5 10836.0 10840.0 10829.0 10832.5 10826.0 10828.0 10809.5 10809.5 10800.5 10801.0 10790.5 10790.5 10770.5 10770.5 100.0 100.0 100.0 $ REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA-MODE PASS #2 GRCH TO RST SIGMA- MODE PASS #1GRCH; AND RST SIGMA-MODE PASS #2 SIGM TO RST SIGMA-MODE PASS #1SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ 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 O. 5 9 65 FT 14-SEP-1998 12~36 P~E: 8 LIS Tape Verification Listing Schlumberger Alaska Computing Center TYPE REPR CODE VALUE .............................. 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 ELM CODE (HEX) DEPT FT 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 BSAL RST PPK 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 CRRA RST 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1244212 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11400.000 NBAC. RST 2516.934 FBAC.RST 3770.053 SBNA.FIL SFNA.FIL 19.499 SBFA.FIL 56.383 SFFA.FIL 16.961 TRAT. FIL IRAT. FIL 0.389 CIRN. FIL 0.802 CIRF. FIL 2.105 BSAL.RST SIBF.RST 77.971 TPHI.RST 39.676 SFFC.RST 14.919 SFNC.RST SIGM. RST 14.986 DSIG.RST 2.917 FBEF. RST 54.114 CRRA.RST GRCH.RST -999.250 TENS.RST 1798.000 CCL.RST -0.005 61. 798 O. 965 149.169 17. 604 2.513 14-SEP-1998 12:36 LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 10742. 000 NBAC.RST SFNA.FIL 56. 778 SBFA.FIL IRAT. FIL O. 469 CIRN. FIL SIBF. RST 87. 633 TPHI.RST SIGM. RST 47. 995 DSIG.RST GRCH. RST 100. 526 TENS.RST 2540. 999 FBAC.RST 64. 424 SFFA.FIL 0.212 CIRF. FIL 57 . 231 SFFC. RST 1.978 FBEF. RST 1727. 000 CCL.RST 3383 . 716 SBNA. FIL 52.172 TRAT. FIL O . 333 BSAL . RST 48. 022 SFNC.RST 35.101 CRRA. RST O. 001 71. 058 1.367 172. 400 52. 837 2. 060 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11382.0 10752.0 RST 11401.0 10752.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 10 88888.0 88886.0 88887.5 11379.0 11378.5 11356.0 11356.0 11340.5 11338.5 11338.5 11339.0 11335.0 11333.0 11332.0 11332.0 11315.0 11315.5 11284.5 11284.0 11257.0 11257.5 11231.0 11231.5 11209.0 11210.5 11182.5 11184.0 11171.0 11171.5 11163.0 11164.5 11164.0 11140.0 11142.5 11136.5 11138.5 11130.5 11132.0 11108.5 11110.0 11099.0 11101.0 11093.0 11094.5 11084.0 11084.5 11083.0 11085.0 11072.0 11073.0 11061.5 11063.0 11057.5 11058.0 11035.0 11037.0 11022.5 11023.0 11013.0 11013.0 11011.5 11013.0 11008.5 11009.5 10992.5 10993.5 10989.0 10991.0 10976.5 10977.0 10966.0 10968.0 10951.0 10952.0 10952.5 10942.5 10944.0 10941.5 10943.5 10938.5 10942.0 10931.5 10933.0 10935.5 10929.0 10931.5 10926.5 10927.5 10922.0 10924.0 10917.5 10917.5 10907.0 10908.0 10902.0 10903.0 10896.0 10896.0 10894.0 10894.0 10892.5 10892.5 10889.0 10890.0 10884.0 10885.0 10879.0 10880.5 10872.0 10874.0 10871.0 10874.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 11 10863.0 10865.0 10848.0 10849.5 10846.0 10849.5 10841.5 10845.5 10838.0 10842.5 10837.5 10840.0 10828.0 10833.0 10816.0 10819.5 10809.0 10808.0 10794.5 10794.5 10775.0 10777.5 10770.0 10771.0 10768.0 10770.0 100.0 102.0 101.0 $ REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTHCORRECTEDDATA FOR RST SIGMA-MODE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA-MODE PASS #3 GRCH TO RST SIGMA- MODE PASS #1 GRCH; AND RST SIGMA-MODE PASS #3 SIGM TO RST SIGMA-MODE PASS #1SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ 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 I1 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 14-SEP-1998 12:36 PAGE: 12 ** SET TYPE - CHAN ** ....................................................................................... NA~E SERV UNIT SERVICE API API API API FILE NUF~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT PT 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1244212 O0 000 O0 0 3 1 1 -4 68 0000000000 FBAC RST CPS 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF FIL 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 BSALRST PPK 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST CU 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RST UA 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 CRRARST 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V 1244212 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11400.500 NBAC.RST 2794.118 FBAC.RST 3825.298 SBNA.FIL SFNA.FIL 19.022 SBFA.FIL 45.990 SFFA.FIL 15.356 TRAT. FIL IRAT. FIL 0.389 CIRN. FIL 0.835 CIRF. FIL 2.345 BSAL.RST SIBF. RST 82.791 TPHI.RST 35.547 SFFC. RST 13.595 SFNC.RST SIGM. RST 13.548 DSIG.RST 3.391 FBEF. RST 54.190 CRRA.RST GRCH. RST -999.250 TENS.RST 1817.000 CCL.RST 0.000 DEPT. 10753.000 NBAC.RST 2619.430 FBAC. RST 3578.911 SBNA.FIL SFNA.FIL 49.923 SBFA.FIL 64.134 SFFA.FIL 50.775 TRAT. FIL IRAT. FIL 0.468 CIRN. FIL 0.250 CIRF. FIL 0.383 BSAL.RST SIBF. RST 86.326 TPHI.RST 58.303 SFFC. RST 46.594 SFNC.RST SIGM. RST 46.605 DSIG.RST 0.659 FBEF. RST 37.050 CRRA.RST GRCH. RST -999.250 TENS.RST 1787.000 CCL.RST -0.003 66.787 0.921 160.852 17.100 2.527 66. 797 1.417 169. 301 46.331 2.107 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 13 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, RST $ REFiARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 14 TYPE REPR CODE VALUE 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 ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELaM CODE (HEX) ....................................................................................... DEPT FT 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA RSAV CU 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA RSAV CU 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA RSAV CU 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA RSAV CU 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT RSAV 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT RSAV 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNRSAV 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF RSAV 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 BSALRSAV PPK 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RSAV CU 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RSAV PU-S 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RSAV CU 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RSAV CU 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RSAV CU 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RSAV CU 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RSAV UA 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 CRRARSAV 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1244212 O0 000 O0 0 4 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. SFNA. RSAV IRAT. RSAV S I B F. RSA V SIGM. RSAV GRCH. RST 11424 500 -999 250 -999 250 -999 250 -999 250 -999 250 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC. RSAV -999~250 DSIG.RSAV -999.250 FBEF. RSAV -999.250 CRRA.RSAV -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 15 DEPT. 10712.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV -999.250 IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBF. RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF.RSAV -999.250 CRRA.RSAV -999.250 GRCH. RST -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... RST 11424.5 $ 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) : STOP DEPTH .......... 10712.5 30-MAY-98 8Cl -205 1513 30-MAY-98 11427.0 11416.0 10800.0 11402.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 16 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY RST RESEVOIR SATURATION $ TOOL NUM~ER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 11750.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 9.00 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL ' SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: Tied into Atlas GR / CCL log dated 3-Aug-1991 Two casing strings in the hole: 5" 18#NT13CR-80 Scab liner from 10,194'-11,592' 7" 26# L80 from 10,314'-10,750' RST Sigma passes logged with well flowing Well test data from 05-25-98: 1050 BOPD; 1910 BWPD; 64.5~ water cut; 2.65 ~SCFD Formation Gas and 3.51 ~4~SCFD Lift Gas Choke opening 96.0 Only scab liner perforations are presented on log GR activated on passes 2 & 3 due to minitron LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 17 GOC appears to be at 10956'. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS1 F/HR 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS1 S 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS1 V 1244212 O0 000 O0 0 5 I 1 4 68 0000000000 RCFR PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) RCAKPS1 1244212 O0 000 00 0 5 1 1 4 68 0000000000 RTDF PS1 1244212 00 000 00 0 5 1 1 4 68 0000000000 FPHVPS1 V 1244212 O0 000 O0 0 $ 1 1 4 68 0000000000 FPDE PS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS1 S 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SF6P PS1 PSIG 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 HVPV PS1 V 1244212 O0 000 O0 0 $ 1 1 4 68 0000000000 BMCU PS1 UA 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 GDCU PS1 MA 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 EXCU PS1 UA 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 NBEF PS1 UA 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF PS1 UA 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 FPGF PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 BSTR PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 XHV PS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 X~2V PS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 RXFR PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 RXRC PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 RXAKPS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SHCU PS1 MA 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 BSALPS1 PPK 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL SIG PPK 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNPS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG PS1 CU 1244212 O0 000 O0 0 5 t 1 4 68 0000000000 FBAC PS1 CPS 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS1 CPS 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS1 CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA PS1 CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA PS1 CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA PS1 CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA SIG CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA SIG CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA SIG CU 1244212 O0 000 O0 0 $ 1 1 4 68 0000000000 SBFA SIG CU 1244212 O0 000 O0 0 $ I 1 4 68 0000000000 SFNA FIL CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1244212 O0 000 O0 0 5 t 1 4 68 0000000000 SBFA FIL CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NUF~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) SIBF PS1 CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PS1 CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC PS1 CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF SIG CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM SIG CU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT SIG 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS1 K~Z 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS1 KHZ 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS1 DEGC 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 XTM PS1 DEGC 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 TAV PS1 KV 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS1 AMP 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CACU PS1 AMP 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 BUSP PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS1 1244212 O0 000 O0 0 5 I 1 4 68 0000000000 TPHI PS1 PU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 CCLC PS1 V 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 RSCS PS1 1244212 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS1 AQTM. PS1 CM2 V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR. PS1 XPSV. PS1 RXLC. PS1 BSAL.PS1 CIRN. FIL IRAT. PS1 SFFA.PS1 SFFA.SIG SFFA.FIL SFNC. PS1 SIGM. SIG GR.PS1 CTM. PS1 11424.500 1464.501 0.441 -12.250 0.000 1. 764 160.156 23.263 50.009 5.069 0.000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 13 459 103 027 CS.PS1 NSCE.PS1 CHV. PS1 RCFR.PS1 RTDF. PS1 FSCR.PS1 BMCU. PS1 FBEF. PS1 BSPR.PS1 XP2V. PS1 RXRC. PS1 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS1 SBNA.SIG SBNA.FIL SFFC. PS1 TRAT. PS1 RDIX. PS1 XTM. PS1 1878.547 2.448 201.339 0.000 0.000 0.098 32.226 58.301 1.144 12.100 0.000 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 6062.000 102.051 TENS.PSi 1205.000 NPHV. PS1 CRRA.PS1 2.506 NSCR.PS1 CP5V. PS1 5.050 CP2V. PS1 RCLC. PS1 0.000 RCRC. PS1 FPHV. PS1 1423.341 FPDE. PS1 AQTF. PSI 0.441 SF6P. PSI GDCU. PS1 60.340 EXCU. PS1 NPGF. PS1 0.985 FPGF. PS1 MARC.PSI 0.000 XHV. PS1 X~2V. PS1 -12.368 RXFR.PS1 RXAK. PS1 0.000 SHCU. PS1 CIRN. PS1 -999.250 CIRF. PS1 DSIG.PS1 -999.250 FBAC. PS1 NBAC. PS1 -999.250 SFNA.PS1 SBFA.PS1 -999.250 SFNA.SIG SBFA.SIG -999.250 SFNA.FIL SBFA.FIL -999.250 SIBF. PS1 SIGM. PS1 -999.250 SIBF. SIG TRAT. SIG -999.250 TRAT. FIL CRNI. PS1 445.938 CRFI.PS1 TAV. PS1 95.031 FICU. PS1 1511.231 0.499 12.143 0.000 1382.791 164 146 9 469 1 000 201 096 0 000 27 317 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 177.935 2.241 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 2O CACU. PSi 2. 500 BUST. PS1 TPHI.PS1 -999.250 TPHI.SIG 3.000 BUSP. PS1 -999.250 CCLC. PS1 3.000 RSXS. PS1 0.010 RSCS.PS1 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .005 SERVICE : FLIC VERSION : O01COi DATE : 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUFmlARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 11428.0 10694.0 RST $ LOG HEADER DATA DATE LOGGED: 30-MAY-98 SOFTWARE VERSION: 8Cl-205 TIME LOGGER ON BOTTOM: 1513 30-MAY-98 TD DRILLER (FT) : 11427.0 TD LOGGER (FT) : 11416.0 TOP LOG INTERVAL (FT) : 10800.0 BOTTOM LOG INTERVAL (FT) : 11402.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 21 VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESEVOIR SATURATION $ TOOL NUFIB~ CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 8.500 11750.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE TE~fPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 9.00 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: Tied into Atlas GR / CCL log dated 3-Aug-1991 Two casing strings in the hole: 5" 18# NT13CR-80 Scab liner from 10,194'-11,592' 7" 26# LBO from 10,314'-10,750' RST Sigma passes logged with well flowing Well test data from 05-25-98: 1050 BOPD; 1910 BWPD; 64.5~ water cut; 2.65 ~MSCFD Formation Gas and 3.51MMSCFD Lift Gas Choke opening 96.0 Only scab liner perforations are presented on log GR activated on passes 2 & 3 due to minitron GOC appears to be at 10956'. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #2. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 22 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS2 F/HR 1244212 O0 000 O0 0 6 1 i 4 68 0000000000 TENS PS2 LB 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 NPHVPS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 NSCR PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 AQTMPS2 S 1244212 O0 000 O0 0 6 1 i 4 68 0000000000 CHV PS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CP5V PS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CM2V PS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 RCFR PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 RCLC PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 RCRC PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 RCAKPS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 FPHVPS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 ~ 14-SEP-1998 12:36 PAGE: 23 LIS Tape Verification Listing Schlumberger Alaska Computing Center NA~E SERV UNIT SERVICE API API API API FILE NUMB NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... FSCE PS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS2 S 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS2 PSIG 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 HVPV PS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 BMCUPS2 UA 1244212 O0 000 O0 0 6 1 i 4 68 0000000000 GDCU PS2 MA 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS2 UA 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 NBEF PS2 UA 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PS2 UA 1244212 O0 000 O0 0 6 1 I 4 68 0000000000 NPGF PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 BSPR PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 MARC PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 XHV PS2 V 1244212 O0 000 O0 0 6 1 i 4 68 0000000000 XP5V PS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 X~2V PS2 V 1244212 O0 000 O0 0 6 1 i 4 68 0000000000 RXFR PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 RXLC PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 RXRC PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 RXAKPS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS2 MA 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 BSALPS2 PPK 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 BSALSIG PPK 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNPS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNFIL 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PS2 CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1244212 O0 000 O0 0 6 1 i 4 68 0000000000 IRAT PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC PS2 CPS 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PS2 CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA PS2 CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA PS2 CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA PS2 CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA SIG CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA SIG CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA SIG CU 1244212 O0 000 O0 0 6 1 i 4 68 0000000000 SBFA SIG CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF PS2 CU 1244212 O0 000 O0 0 6 1 i 4 68 0000000000 SFNC PS2 CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS2 CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 14-SEP-1998 12:36 PAGE: 24 LIS Tape Verification Listing Schlumberger Alaska Computing Center NAME SERV UNIT SERVICE API API API API FILE NUM~ NUFI~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) ....................................................................................... SIBF SIG ' CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 SIGMSIG CU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1244212 00 000 O0 0 6 1 1 4 68 0000000000 TRAT SIG 1244212 00 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 RDIX PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS2 KHZ 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS2 IOqZ 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS2 DEGC 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS2 DEGC 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 TAV PS2 KV 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS2 AMP 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CACU PS2 AMP 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 BUST PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS2 V 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 RSCS PS2 1244212 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11428.000 CS.PS2 NPDE. PS2 1471.101 NSCE. PS2 AQTM. PS2 O . 661 CHV. PS2 CM2V. PS2 -12.172 RCFR.PS2 RCAK. PS2 O . 000 RI]DF. PS2 FSCE. PS2 1. 742 FSCR.PS2 HVPV. PS2 160.156 BMCU. PS2 NBEF. PS2 21.715 FBEF. PS2 BSTR.PS2 64.056 BSPR.PS2 XPSV. PS2 5.069 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS2 -999.250 IRAT. FIL SFFA.PS2 -999.250 SBNA.PS2 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC. PS2 -999.250 SFFC. PS2 SIGM. SIG -999.250 TRAT. PS2 GR.PS2 67.293 RDIX. PS2 CTM. PS2 104.004 XTM. PS2 CACU. PS2 2.500 BUST. PS2 TPHI.PS2 -999.250 TPHI.SIG 3178.808 2.624 200.612 0.000 0.000 -0.050 31.933 54 026 0 998 12 129 0 000 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 32614.000 100.586 3.000 -999.250 TENS.PS2 CRRA.PS2 CP5V. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 XM2V. PS2 RXAK. PS2 CIRN. PS2 DSIG.PS2 NBAC. PS2 SBFA. PS2 SBFA. SIG SBFA. FIL SIGM. PS2 TRAT. SIG CRNI. PS2 TA V. PS2 BUSP. PS2 CCLC. PS2 1041.000 2.488 5.050 0.000 1416.017 0.661 60.012 1 004 0 000 -12 368 0 000 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 450.383 94.888 3.OOO 0.010 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS. PS2 RSCS.PS2 1508.790 0.394 12.173 0.000 1387.673 174.380 10.652 0.993 200.854 0.000 26.666 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 181.024 2.207 8878.000 8463.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 25 DEPT. 10693.500 CS.PS2 NPDE. PS2 1472.093 NSCE. PS2 AQTM. PS2 0.661 CHV. PS2 ~2V. PS2 -12.211 RCFR.PS2 RCAK. PS2 0.000 RTDF. PS2 FSCE. PS2 1.759 FSCR.PS2 HVPV. PS2 160.121 BMCU. PS2 NBEF. PS2 16.634 FBEF. PS2 BSTR.PS2 88.016 BSPR.PS2 XPSV. PS2 5.083 XP2V. PS2 RXLC.PS2 0.000 RXRC. PS2 BSAL.PS2 172.502 BSAL.SIG CIRN. FIL 0.212 CIRF. FIL IRAT. PS2 0.461 IRAT. FIL SFFA. PS2 57.073 SBNA.PS2 SFFA.SIG 3.730 SBNA.SIG SFFA.FIL 53.987 SBNA.FIL SFNC.PS2 50.697 SFFC. PS2 SIGM. SIG 2.558 TRAT. PS2 GR.PS2 86.885 RDIX. PS2 CTM. PS2 102.051 XTM. PS2 CACU. PS2 2.483 BUST. PS2 TPHI.PS2 57.995 TPHI.SIG 3606.397 TENS.PS2 2.601 CRRA.PS2 201.339 CPSV. PS2 0.000 RCLC. PS2 0.000 FPHV. PS2 0.037 AQTF. PS2 27.288 GDCU. PS2 35.650 NPGF. PS2 1.215 MARC. PS2 12.100 X~2V. PS2 0.000 RXAK. PS2 3.247 CIRN. PS2 0.328 DSIG.PS2 0.463 NBAC.PS2 72.904 SBFA~,PS2 4.373 SBFA. SIG 72.488 SBFA.FIL 49.757 SIGM. PS2 1.401 TRAT. SIG 43402.000 CRNI.PS2 101.005 TAV. PS2 3.000 BUSP. PS2 6.900 CCLC.PS2 1706.000 2.143 5.040 0.000 1416.017 0.661 59.871 1.005 0.000 -12.373 0.000 0.217 1.964 2453.654 61.766 5 919 63 724 49 797 0 087 455 859 94 990 3.000 -999.250 NPHV. PS2 NSCR. PS2 CP2 V. PS2 RCRC. PS2 FPDE.PS2 SF6P.PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS.PS2 1516.114 0.467 12.158 0.000 1388.703 175.403 12.737 1.004 200.958 0.000 33.867 0.331 3444.322 56.711 2.700 54.556 87.676 1.373 1.396 212.699 2.166 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE · 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-i998 12:36 PAGE: 26 Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... RST $ LOG HEADER DATA DATE LOGGED: 11428.0 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 10701.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 30-MAY-98 8C1-205 1513 30-MAY-98 11427.0 11416.0 10800.0 11402.0 1800.0 NO TOOL NUMBER ........... CGRS-A RST-A 8.500 11750.0 PRODUCED FLUIDS 9.00 THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 27 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REF~ARKS: Tied into Atlas GR / CCL log dated 3-Aug-1991 Two casing strings in the hole: 5" 18# NT13CR-80 Scab liner from 10,194'-11,592' 7" 26# L80 from I0,314'-10,750' RST Sigma passes logged with well flowing Well test data from 05-25-98: 1050 BOPD; 1910 BWPD; 64.5% water cut; 2.65 F~qSCFD Formation Gas and 3.51 M~SCFD Lift Gas Choke opening 96.0 Only scab liner perforations are presented on log GR activated on passes 2 & 3 due to minitron GOC appears to be at 10956'. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 28 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP Rr~,~ CODE (HEX) DEPT FT 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS3 F/HR 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1244212 00 000 O0 0 7 1 1 4 68 0000000000 NPHVPS3 V 1244212 O0 000 O0 0 7 1 I 4 68 0000000000 NPDE PS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CRRA PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS3 S 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CPSV PS3 V 1244212 O0 000 O0 0 7 1 I 4 68 0000000000 CP2V PS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CM2V PS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 RCAKPS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 RTDF PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 FPHVPS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 FPDE PS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS3 S 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PS3 PSIG 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS3 UA 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 GDCU PS3 MA 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PS3 UA 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS3 UA 1244212 O0 000 O0 0 ? 1 1 4 68 0000000000 FBEF PS3 UA 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS3 1244212 O0 000 O0 0 7 1 i 4 68 0000000000 BSPR PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 XHV PS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 X~2V PS3 V 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS3 1244212 O0 000 O0 0 7 I 1 4 68 0000000000 RXRC PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SHCU PS3 MA 1244212 O0 000 O0 0 7 I 1 4 68 0000000000 BSAL PS3 PPK 1244212 O0 000 O0 0 7 1 ~1 4 68 0000000000 BSAL SIG PPK 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 29 NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DSIG PS3 CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS3 CPS 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS3 CU 1244212 O0 000 O0 0 7 1 I 4 68 0000000000 SFFA PS3 CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS3 CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS3 CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS3 CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS3 CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS3 CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS3 KHZ 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS3 KHZ 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS3 DEGC 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS3 DEGC 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 TAV PS3 KV 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS3 AMP 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS3 AMP 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 RSXS PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS3 V 1244212 00 000 O0 0 7 1 1 4 68 0000000000 RSCS PS3 1244212 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11428.000 CS. PS3 2421.796 TENS. PS3 870.000 NPHV. PS3 NPDE. PS3 1473.313 NSCE. PS3 2.650 CRRA.PS3 2.573 NSCR.PS3 AQTM. PS3 0.661 CHV. PS3 201.581 CP5V. PS3 5.050 CP2V. PS3 CM2V. PS3 -12.250 RCFR.PS3 0.000 RCLC. PS3 0.000 RCRC. PS3 1511.231 -0.358 12.158 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 3O RCAK. PS3 2.000 RTDF. PS3 0.000 FPHV. PS3 FSCE. PS3 1.833 FSCR.PS3 -0.362 AQTF. PS3 HVPV. PS3 160.401 BMCU. PS3 31.054 GDCU. PS3 NBEF. PS3 21.283 FBEF. PS3 54.771 NPGF. PS3 BSTR.PS3 54.036 BSPR.PS3 1.089 MARC. PS3 XPSV. PS3 5.079 XP2V. PS3 12.100 XM2V. PS3 RXLC. PS3 0.000 RXRC. PS3 0.000 RXAK. PS3 BSAL.PS3 -999.250 BSAL.$IG -999.250 CIRN. PS3 CIRN. FIL -999.250 CIRF.FIL -999.250 DSIG.PS3 IRAT. PS3 -999.250 IRAT.FIL -999.250 NBAC. PS3 SFFA.PS3 -999.250 SBNA.PS3 -999.250 SBFA.PS3 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC. PS3 -999.250 SFFC.PS3 -999.250 SIGM. PS3 SIGM. SIG -999.250 TRAT. PS3 -999.250 TRAT. SIG GR.PS3 33.647 RDIX. PS3 48671.000 CRNI.PS3 CTM. PS3 101.563 XTM. PS3 101.563 . TAV. PS3 CACU. PS3 2.485 BUST. PS3 3.000 BUSP. PS3 TPHI.PS3 -999.250 TPHI.SIG -999.250 CCLC.PS3 DEPT. 10701.000 CS.PS3 NPDE. PS3 1473.619 NSCE. PS3 AQTM. PS3 O. 661 CHV. PS3 CM2V. PS3 -12.211 RCFR.PS3 RCAK. PS3 O. 000 RTDF. PS3 FSCE. PS3 1.747 FSCR.PS3 HVPV. PS3 160.261 BMCU. PS3 NBEF. PS3 16.245 FBEF. PS3 BSTR.PS3 71.975 BSPR.PS3 XP5V. PS3 5.082 XP2V. PS3 RXLC.PS3 0.000 RXRC.PS3 BSAL.PS3 175.083 BSAL.SIG CIRN. FIL 0.247 CIRF. FIL IRAT. PS3 0.477 IRAT. FIL SFFA.PS3 53.779 SBNA.PS3 SFFA.SIG 3.373 SBNA.SIG SFFA.FIL 51.686 SBNA.FIL SFNC. PS3 48.281 SFFC.PS3 SIGM. SIG 2.352 TRAT. PS3 GR.PS3 88.792 RDIX. PS3 CTM. PS3 101.563 XTM. PS3 CACU. PS3 2.473 BUST. PS3 TPHI.PS3 58.853 TPHI.SIG 3542.603 TENS.PS3 2.576 CRRA.PS3 202.308 CP5V. PS3 0.000 RCLC. PS3 0.000 FPHV. PS3 -0.213 AQTF. PS3 26.827 GDCU. PS3 33.824 NPGF. PS3 1.178 MARC. PS3 12.093 X~2V. PS3 0.000 RXAK. PS3 3.268 CIRN. PS3 0.361 DSIG. PS3 0.477 NBAC. PS3 71.359 SBFA.PS3 4.476 SBFA.SIG 67.742 SBFA.FIL 47.472 SIGM. PS3 1.441 TRAT. SIG 59109. 000 CRNI. PS3 101. 214 TAV. PS3 3. 000 BUSP. PS3 6. 854 CCLC. PS3 1418.458 0.661 60.340 0.992 0.000 -12.289 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 456.749 94.888 3.000 0.000 1796.000 2.082 5.050 0.000 1411.134 0.661 59.684 1.004 0.000 -12.365 1.000 0.244 1.468 2669.340 56.258 5.872 62.491 47.607 0.086 457.572 95.011 3.000 -999.250 FPDE. PS3 SF6P. PS3 EXCU. PS3 FPGF. PS3 X~V. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA. PS3 SFNA o SIG SFNA. FIL SIBF. PS3 SIBF. SIG TRAT. FIL CRFI.PS3 FICU. PS3 RSXS. PS3 RSCS. PS3 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC. PS3 FPDE.PS3 SF6P. PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 SFNA.SIG SFNA.FIL SIBF. PS3 SIBF. SIG TRAT. FIL CRFI.PS3 FICU. PS3 RSXS. PS3 RSCS. PS3 1388.589 176.939 11.047 0.999 201.096 0.000 27.967 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 177.487 2.222 8878.000 8463.000 1501.466 -0.244 12.187 0.000 1388.894 177.231 12.681 1.000 200.889 0.000 33.867 0.351 3521.390 53.014 2.464 52.089 88.770 1.387 1. 427 219. 764 2.153 8878.000 8459.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-SEP-1998 12:36 PAGE: 31 **** FILE TRAILER **** FILE NAM~ : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 98/09/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/09/14 ORIGIN : FLIC TAPE NAME : 98450 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, M-16, PRUDHOE BAY, API# 50-029-20613-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/09/14 ORIGIN : FLIC REEL NAME : 98450 CONTINUATION # : PREVIOUS REEL : COGENT : BP EXPLORATION, M-16, PRUDHOE BAY, API# 50-029-20613-00 ~1~ OF ALASKA COP~ PAG~ I ORI'GIN : COMMENTS SIZE CODE 000 000 030 O65 015 O65 01! O65 03 O65 O3 O65 001 O65 0O7 O65 000 000 006 065 000 000 003 065 t bVP 010 H02 VERIFICA?IrJ~-blS. T~-~Gi,;-'-. :_ . PAGE ****************************************************************************** * ALASKA COMPUTING CENTER *********************~*******~'~.~**.************* COMPANY = SOHIO A[~AsKA'i~ETAO~U~ COMPANY FIEbD COUNTY STATE CASING CA~ING YPE FLUID PRUDHOE BAY NORTM,-~SO!PE ;BOR;OUGft ~ ALASKA " SUR 3 = .7..000" SURFACE TO 10750 ** DATA FORMAT RECORD ** ' i:' . ? .:!i ENTRY BLOCKS YPE .-SIZE R. EPR CODE · ENTRY 2 i 66 0 8 4 73 6O DATUM SPECIFICATION p ~ ~N~M UNIT APl AP1 APl AP:[ F~bg $I~ ~' :" ' "" ZE SpL REpR PROCESS ~R TRAT ~ACK ~!DT · XDT P~ ~SI6 ps~ RAT R ACK BAC PS2 TDT RAT P~3 8AC P83 TDT ?RAT P$4 GR BACK P$4 ~BAC P$4 N~DT P~DT ~aC~ PaS FBAC P$5 NTOT FTDT PS5 ** DATA .TD1 TRAT RAT 1!62~ '2,19 '2 O0 000 u o( O! 0 4 GAP ~0000000 )0 1 0 4 0000000 )000 )ooo CPS )0 0 0 4 68 0000 0000000 CPS )000 CO O0 400 01 0 0 4 i 68 000 )000 CPS )000 )000 ,0000 GR ,6934 GR o000 FTDT 4844 GR 1250 FI'DX 5488 ~R 18.1875 2 3 ' 5 7 S 1 18,6094 59 '6250 19,5469 8 ' 1250 NTDT 202 5000 NTDT 167 NTDT !95 6250 NTDT NTDT 1 ~TDT 200 FTDT NTDT !62 000 NTDT NTDT TDTRAT NTDT TRAT NTDT 8750 FTDT 6920. GR ,0 FTDT 11400,0000 GR 172,5000 FTDT 18!'i1250 FTDT 182;6250 ~TDT 196,2500 FTDT 185 2 194 2 208 191 FTDT 6 .~50 FTDT 17 1 17 i94 7500 16 G 8 9 ' 79 ! 0 19,6250 112' 8750 ~87 3 ~5 iO00 ;3125 16 ;3906 ,~g750 ,1719 ,53!3 ,8086 500 '52'28 ! 3 14.12$o 4 ' ! 250 14,3125 59 25 14~4686 64 ' 5625 13,6758 72, ! 675 14,3281 58 ' 3 436 :{,5'8281 41 '53 t ;3 G !5,2969 !, 4063 15,8203 66 · 0000 15,3594 1,5,o8 5 9 57,9375 b~P 0i0 H02 VERIF1CATZON, LI:STZ!G DEPT 11200, TRAT l~ NTDT 145, NTDT 14 TaAT TRAT ' NTDT !5~ TRAT NTDT 150 ' , 100 TRA~ RAT " TRAT NTDT 318 TRAT NTDT TRAT RA~' 2 NTDT TRAT NTDT DEPT 1090~ TRAT NTDT TRAT TDT NTDT 39~ TRAX TDr 4 TRAT NTDT 442 ~EPT I082~ RAT ~' NTDT 431 TRAX ~ NTDT 44 TRAX 4 5 o000 ~R 5 F 2500 FTDT 8425:.GR o0o0 F'TD: 0000 GR 4434 GR 9375 FTDT 1406 GR 0000 FTDT 50 F '250 ~ F""D T o000 GR 1797 F$IG 192 TG 2 235 275 O0 28~ 7500 66.7500 2637 ~R ~ :;I20 ~VO05 P TDT 299 2559 ~R 5OO 7500 .. I'OX 25o0 FTDT 371 2969 IG 12 : 7 o 12 72 74 12 68 13 F$IG FSIG t4 : 125 F$IG 15 1:0 2 FSIG i5 IG 15 ~C 75 iG 15 3O 109 27 26 90 27 ,1250 ,6875 .6094 2500 ~6172 i0625 ,0947 ,0156 ~8750 437 I25 9531 5000 640b 0000 1211 9375 3594 5000 ,3828 ,0000 ,:1250 .7656 ;0000 ;1941 ,1641 '8750 0781 8i25 6250 8750 8906 1875 7222 18809 18281 ,4375 42,3750 !17'9375 40,9062 114'9375 37;5625 118'8750 ?RAT ':4-14!922'/:i?GR:..!/.-':i: 4< ::~. i:'<:;'~:!:'32/~~ '< C 93,2676 NTD~ 456 1'11.9 FT'DT '298,6250' SlGM ;t7'9687 FSIG 38,1875 NTDT 51B ,5000 FTDT 305~500 CONTINUATiOii ~, SER~!C~ NAM~ ~EDIT 0 C.) DVP PAC~E ! ** REE ME ' DATE ;8210,';~/ 9 ORIGIN ~ CONTINUATION COMMENTS · " .REEL CO~4~aENTS *~ TAPE HEADER. SERVICE NAMg :SERVIC DATE 18~/09 9 O~IGI~' 1655~ ' TAP~ NA~E ~ CON'TINUAT!ON ~ :01. PREVIOUS TAPE COMMENTS :TAPE COMMENTS FILE NAME :SERVlC,OO1 DATE : MAXIHU~ LENGT!~ : 1024 .w . .Ib~; TYPE PREVIOUS FILE ** INFOR~ATION RECORDS ** CN : SOHIO ALASKA PETR©LEbM 000 000 ~N : M,,16 000 000 FM : PROD'HOE BAY 0o6 OOO R A .~ G: 12 E 000 000 TOWN ~ 11 N 000 0fi0 SECT: 1 ('~o0 000 COUM: [..lO RTH SI, OPE STAT: ALASKA 000 000 M~M~ CONTENTS U~IT TYPE CATE 81 Z K C 0 b E 022 0{55 004 00,5 012 065 003, Oe,-5 003 0ol 065 012 0~,5 0o6 0~5 O 06 (; 6) 5 .,.. Z ~, C 0 '1} ~ C~O~PANY ELL I ~TATfl JOB NUMBR.. AT ACC: 10707,65543 RUN #!, DATE LOGGED.': 3I-.AUG"82 BOTTOM DEPTH lOP DEPTH A$tN¢ A$tNG UBING bINER TYPE FLUID FLU/D LR~EL - 1!.68.5 10740 : 13 378. = .. '5 IN, 10283 FT', TO SURF, 0 IL , ~ Ul.,b · P' SINES . bVP 010,MOl VE;RIFICATICN_LI6~ING :: -_ :.._ ~. -: PAGE ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE DATUM SPECIFICA~'IO, BLOCKS t D ORDER ~ ~T RAT PS1 OR BACK PS1 FBAC NTDT F~DT PS SIGN PS FSIG P82 TRAT PS2 GR P82 BACK PS~ FBAC P82 NTDT PS2 TDT ISM PS3 T~T PS3 AC~ PS3 FBAC PS3 NTDT PS3 FTDT PS3 ~RAT PS4 GR PS4 BACK PS4 NTDT PS4 TDT ISM PS5 FSIG PS LOG 'TYPE CLASS P~OD'-}~O' ~' LEVEL O -O . O 0 0-- 4 0 0 ,40 i 0 0 4 0 -0 _~ 0 O- 0 ~--_0_ 4 ~ 0 42 l 0 0 4 0 GAPi O' 31 32 -0 : ~O~ 4 0 CPS 0 '0 0 4 0 P.: O- ~0~ '. O~ -~0:- 4 0 PS O 0 0 0 0 4 0 CPS · O O 0 0 0 0 CO 0 40 O: 0 4 0 O O .O 0 - 4 0 42 0 4 O APi -0 3.1 3-~ 0 0 4 0 PS ~ 0 0 0 0 0 4 0 u 0 40 ~ o o 4 o hVP 010.H01 VERIFICATION LISTING PAGE 4 TRAT PS5 BACg PS5 F AC PS5 FTDT PS5 I 1 DATA DEPT FTDT FTDT TDT GR FTDT GR FTDT DEPT FTDT GR FTDT GR FTDT GR FTDT FTDT DEPT GR FTDT TDT FTDT FTDT DEPT FTDT FTDT 11698,5000 SIGn 999,2500 -99912500 ~99'9,2500 BACK -999,2500 $IG~ -999,2500 BACK -999.2500 -999,2~00 ~999~2500 SIG~ ~999'~500 -999,2'500 11600.0000 8IG~ 27~90~2 8AC~ 214'1250 SIG~ 31,7969 ~ACK 190,8750 StG~ 36,0313 ~AC~ ~97~3906 SIG~ 40,1289 BAC~ I88'1.719 SI'Gg 43'2187 BACK 205;3594 1!500 2O9 22 20~ 201 t5 209 0000 S!G~ sAC 3750 5IG~ 0.0~0 BAC~ 2500 SlGM 1875 BACK 1250 SiC~ 5000 6IG~ ~750 ~AC~ i750 -999.2500 -999 '999 -999 '9~9 -999 '999 -999 '999 --999, -'999 . 2500 TRAT .-999 O0 NTDT 20,328! FSIG 47,8750 FBA¢ I22'~875 i~,E796 150 68t6 I9 2373 14! 8594 !7. 3750 TRAT i6,2255 TRAT 5381 1. RA~. 56.2076 NTDT 18 153~ 149. 4219 f'SAC 'D] 1 :~ FSIG !7 '0469 TRA? 5.6, 1 ~} 06 1.1400,0000 14,023.4 179~.1250 20,!719 ,69 7500 "' 2 ,3750 96.35!6 t6. SIG~ 16,5625 FSJG !3.$359 TRAT BAC~ 80,b000 ~8AC 32,0°25 i~l'bT SIG~ ,8i15 FSI~ 1421455 ~AT MACK 165~2500 FBAC "'~.658~ ~TDT gAC~ 165.6~50 FMAC ol.343d N'I~DT -999,2500 -999.25©0 -999.2500 999'2500 Z999,2500 999,2500 -999 2500 -999:2500 -999.2500 2,7344 219,3750 2.695] 215.B750 2.5869 204.0352 217449 200.5234 2.6071 206.79~9 2.8633 218.o250 2.8750 226 2~7~56 235.0000 3.01J4 ~45.6b~3 2.7539 194.2500 1't9.3750 2.8624 193.1875 2,7402 208.8750 bVP 0lO,HO1 VERIFICATION blBTI : : FTOT 187,7500 SIG~ GR 39,!75~ BAC~ FTDT 15io5938 DEPT 11300 'R FTDT 200 GR 22 FTDT 199 TDT 210 GR 35 FTDT 211 GR 30 FTDT 181. DEPT TDT FTDT FTDT TD~ GR FTD~ DEPT GR FTDT FTDT GR FTDT FTDT TDT DEPT TDT FTDT FTDT FTDT FTDT DEPT 11200 1o 212 ~0 0000 000 $iG~ 040~ BACK 1094 SIG~ o? l 8125 $IGM 266 125 SiG~ 687 BACK .'.000 0000 o~8 75 o0o ~'! 188 :6328 PAGE 25.8750 BACK 20!'3682 29.6055 BACK 193'6 I S IG.~ , 21. 198,8125 11. i00 0000 $IGi~ ~" 0 16 250 BACK. 295 SO00 264 4375 29,609~ 277,9375 28.0469 ~ACK 291.2832 36,4023 BACK i8,9219 11000. 0000 21. 1406 232, 75OO 26 ~555 24O 8750 31 6094 260 75OO 269 8594 39,5625 ~59'7656 ]00,0000 15949727 F~AC 63,2842 N't'DT lb4,0602 9z,4375 F~AC . 34,5{00 i:l[: 1 21~;3750 149~3{d~ FdAC 53,9745 ~TD'r Z1~.1406 !7;4629 ~SiG :i~; ~0:3.~ TRAT 2'6069 I72~0781 F~AC 65,6348 NTDT 195,8945 :'i?;500~ FSI~ 15;363~ TRAT 2;8328 163~5000 F~AC 61,3340 a:~DT 21~,300~ !7;7344 FSIG 1~,I953 TRt~T 2,7031 167~8250_ ~'BAC 62,4688 N:I~DT 188,2500 ..... ' ' ' ~'~ 5000 BACK i06,6875 FB:AC 50,.~/50 ~i.r[. I 179, S!G~ 'i3~4805 FSIG - 12,6336 TRAT 2.2092 BACK i 56,~507 FSAC 69,4033 NTDT 13~.2695 SIG~ ' i~;86~5 FSI~ I2~3529 TR~,T '1164 178,1367 FBAC 74,~781 NTDT 1'10,6875 i6:0027 FS!G 1'2:i421 ~RAT 2,0945 179i5254 F~AC 71~969 NTDT 177,8750 'i4;S262 FSIG 1221035 T~: _2'0817 . 16.7969 FSIG ~.5 .~69 TR~%7 2,8203 '" . ...... '~" '~" ',". 5000 ' ' ........ f' ',~ 284 43'15 162,O1.2 ~ ~AC 61,0000 ,~br , 16;8486 FSIG 14~6270 TPAT 2.6736 175~7500 ~'SAC 69~4375 ~t3; bT 305.92~9 175'I~0 ~"BAC 73,4i2~ NTDI 3OI,9658 ~9; 88~.8 FS!G 53;5000 TP~.T 1.3770 I8'1094 FSIG !5.3750 T~AT 3.0566 SIGM 18;I689 ~$ i<; 15,6208 TR~i~ 3.0714 ~ACK IO2, 1532 ~'~AC bb,34~ / m't'bT 285,3750 250 ~ i'0 ~ I:7;6133 FSI6 I6.0889 TPAT .0659 BAC~ 179,5000 FbAC .70:,b09~ .~ l-t:~ 276.5234 8IG~ ! 7,5bgi:l FSIG I5,721 .i. lh~T 3.1789 BACK 162.2500 ~AC 67,796g~ . aTDT~ !68.'4~8- S'I C;~a 29,6-)94 ~ S [ <;, .... · nar~ ~ 9~. {')i~(~o ~-a~c ~9. ~oz~ ~4 i'O 404. 5000 bVP 010 HOI 'VERIFICA'i '~ ..... ' FTOT ~03 FTDT 304 FTDT .. G~ $9 FTDT 307 GR 93 FTDT 296 OEPT 10800 GR 57 FTDT 271 TDT 3]0 R 75 TDT 303 GR 68 FTDT 293 GR 80 FTDT 287 DEPT TDT FTDT ~TOT GR FTDT FTOT 0000 $IG~ 29 5000 BACK 167 8984 S I'G~'~ 30 9062 . ACK 175 76i'1 0000 SiG~ !25 ~ACK 0000 SIGN 8437 BACK 1562 2500 25OO !4t GACK 500 .484ooo 30.86 FS!G 26'5557 T~ A'r 900 ' FSIG 2713486 TRAT 3027 ' ~SIG 26,5344 TPAT ~5000 F'.B AC 82, ~496 202 ~Sic 26~8283 T~AT 37,5000 }?SIC 37'~750 T~AT 133,7500 F.~AC 6~,-0938 NTDT 37,2!.56 FSIG ' 38 ~;6~ TROT 177,1250 FaiC 71.8750 37.7813 F3I~ 38~28i3 TPAT 191,0000 FBAC 79,062~ 37.9687 FSiG 38i0313 TRAT 195,8250 FBA~ 74,2500 36;78~3 FSIG 38i9062 TRAT 175-~ 1250 FBAC 74,625o NTDT ~73o.oooo 999,2500 '999;~500 S!G~ '999 2500 BAC..,, -999 2500 SIG~ -999 ~500 B C '999 2500 -999 2500 9ACK -999 2500 42 345~ BACK -999 ~50 -999.2500 FStG -999 2500 'r~T -99 2500 F~A -999, St o ~ ~'u-~ -99 .2500 FSfC -999. 509 TRAT 9 .99,2500 : FMAC -999,250Q N:i~DT 999~2500 FSIG -999 ;2500 T~ -999,2500 ~MAC -9~9 .~500 .NTDy -9991 ~-500 F$I(~ '999,250~ T~AT -999,2500 ~AC -999 ,2500 NI'OT -99912500 FSI(; -999,2500 TRI. T - 99 ' 500 FgAC -999 -500 NTDT 9:..~ .2 ......... - ............. .2 ...... FIL~ILE~TRAIbER VERSION ? DATE MAXIMUM LENGTH : 1024 NEXT FIbE NAME : PAGE 3.8274 419,1328 3,9912 '.434 424,9706 3,9903 396.1.250 5,332o 452.2500 5,3~09 487.7891 5.38~7 539,5000 5,3242 525,5000 5.246] 491.0000 -999,2500 2999.2500 999.2500 -999.2500 -999.2500 -999,25U0 -999,2500 -999.2500 -999.2500 -999.2500 ** TAPE TRAIbEN ** SERVICE NAME :SMRVIC o O /4 9 DATE . 821 9 ORIGIN : 6.~55 TAPE NAM~ : CONTINUA ~N # :01. bYP 010,M0! VERI~ICA~I[N L!STIMG COMMENTS ~TAPE CO~ENT5 ** RgEb TRAILER ** SERVICe; NAME ~$ERViC DATE :82/09/ 9 ORIGIN : REEL MANE ~REEL ID C..N~INUATION # ,01 NEXT 'REEb NAM'E · COMMENTS IREEL COMMENTS ~m~mmmmmmmmmmmmmmmm~m~ ~ .... ~CHLU~BERG~R .... · ~mmmmmmmmmmmmmmmmmmmm~ LIS TAPE VERIFICATION LISTING uo!ss!tu~,oO 'suoO s~9 '~ !!0 ~s~[~ LVP 009.H05 VERIFICATION LISTING PAGE ~ REEL HEADER SERVICE NAME :SERVIC DATE :81/10/27 ORIGIN : REEL NANE :REEL ID CONTINUATION ~ ~01 PREVIOUS REEL COMMENTS ~REE5 COMMENTS ~* TAPE HEADER SERVICE NAME :SERVIC DATE ~81/10127 ORIGIN :1070 TAPE NAME :62217 CONTINUATION # PREVIOUS TAPE COMMENTS :TAPE COMMENTS ~ FILE HEADER FILE NAME :$ERVIC.OO1 SERVICE NAME VERSION # : DATE : MAXIMU~ LENGTH : 1024 FILE TYPE PREVIOUS FILE INFORMATION RECORDS MNEM CONTENTS CN : SDHIO ALASKA PETROLEUM RANG: TOWN: llN SECT: COUN: NORTH SLOPE STAT: ALASKA CTRY:, USA MNE~ CONTENTS PRES: DILOOIF RECORD TYPE 047 ~ UNIT TYPE CATE SIZE CODE 000 000 022 065 000 000 024 065 000 000 022 065 000 000 003 065 000 000 003 065 000 000 OO1 065 000 000 012 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 OO7 O65 LVP 009,H05 VERIFICATION LISTING RECORD TYPE 047 RECORD '£YPE 047 ** COMMENTS ************************************************ JOB # 1.0707,6221! DIL RbN #1, LOGGED 25-SEP-81 BOTTOM LOG INTERVAL TOP LOG INTERVAL CASING-LOGGER BIT SIZE TYPE HOLE FLUID DENSITY VISCOSITY PH FLUID LOSS RM ~ ~EAS. TEMP. RMF 0 HEAS TEMP. RMC ~ MEAS: TEMP. RM 9 BHT 10785 FT. 2732 FT, 13.38 IN, ~ 2732 FT, 12,25 IN. LIGNO- =,9.9 39.0 9.5 ~.5 Mb · 74 S 76 F 2.98 ~ 68 F 2.42 ~ 68 F 1.476 9 147 F RUN #2 GR.DIb & GR.BHC SAME DATA; PAGE LVP 009.HO5 VERIFICATION LISTING PAGE 3 MERGE OF RUN #1 & #2 JOB ~ 10707,62217 RUN #2, LOGGED 29-SEP-81 BOTTOM LOG INTERVAL TOP LOG INTERVAL CASING-LOGGER BIT SIZE TYPE HOLE FLUID DENSITY VISCOSITY PH FLUID LOSS RM ~ MEAS. TEMP, RMF ~ MEAS, TEMP. RMC 9 MEAS. TEMP, RM ~ BHT = 11750 FT. = 10765 FT, = 9.625 IN. ~ 10772 FT, = 8.5 IN, = GEL -- 9.5 = 10 '= 4.9 C3 = 2.56 ~ 68 F = 2.50 Ca 68 r = 2.10 e 68 r '- .974 ~ 190 F MATRIX LIMESTONE ************************************************ LVP 009,H05 VERIFICATION LISTfNG PAGE 4 ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE 4 1 9 4 0 ! DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT APl ID ORDER # LOG TYPE DEPT FT 0 0 IbM OIL OHMM 7 0 ILD OIL OHMM 7 i2 SP OIL MV 7 ! GR DIL GAPI 7 GR 5HC GAPI 60 DT BHC U$/F 60 52 NPHI NUC PU 0 68 RHOB NUC G/C3 0 35 GR FDN GAPI 42 DRHO NUC G/C3 0 44 CALI FDN IN 42 28 NRAT NUC 0 42 NCNb NUC 0 34 FCNL NUC 0 34 DATA DEPT li700,O00 SFbU SP -21,719 GR NPHI 23,242 RHOB CALI 8,46! NRAT DEPT 11600.000 SFLU SP -76,000 GR NPHI 15,918 RHOB CALl 8,172 NRAT DEPT 11500,000 SFLU SP -75 312 GR NPHI 21:143 RHOB CALl 8,289 NRAT DEPT 11400,000 6FbU SP -74.438 GR NPHI 17,871 RHOB REPR CODE 66 73 65 66 ENTRY I 60 ,lIN 0 APl AP1 FILE SiZE PROCESS CLASS MOD NO. LEVEL 0 0 0 4 0 0 0 0 4 0 0 0 0 4 0 46 0 0 4 0 0 0 0 4 0 32 0 0 4 0 32 0 0 4 0 32 0 0 4 0 2 0 0 4 0 I 0 0 4 0 32 0 0 4 0 0 0 0 4 0 3 0 0 4 0 1 0 0 4 0 92 0 0 4 0 93 0 0 4 0 50 IbM ,250 GR ,250 NCNb 9.758 IbM 71.271 GR 2,705 GR 2,566 NCNb 6,586 IbM 40.I15 GR 2.408 GR 2,049 NCNb 4.80t ILM 22.~08 GR 2. 14 GR 2,408 NCNb 16 938 IbM 22:651 GR 2,285 GR ~99 50 -999,250 -999,250 8,859 71,27i 109.042 2846.000 2,992 40,115 42,667 4082,000 2.078 22 08 3896,000 22 37.031 IbP DT DRHO FCNL DT DRHO FCNL DT DRHO FCNL ILD DT DRHO FCNL IbP DT DRHO SAMPLE 1 1 1 1 1 REPR CODE 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 999 250 -'999:250 -999,2~0 -999,250 8.789 70.583 0.116 1086.000 2.877 81.77I 0.001 1987.000 1.973 86.563 -0.001 1621.000 9,094 87.625 0.001 bVP 009.H05 VERIFICATION LISTING PAGE 5 CALl 8,680 NRAT 2,223 DEPT 11300.000 SFLU Sp -74.000 GR NPHI 18.994 RHOB CAbI 8.281 NRAT 16.844 19.859 2.377 2.266 DEPT 11200.000 $FbU $P -64.750 GR NPHI 11.133 RHOB CALI 8.641 NRAT 37.063 . 1,768 DEPT 11100.000 SFbU 8P -55,813 GR NPHI 22.412 RHOB CAbI 8.414 NRAT 53.2813 22. 34 .246 .508 DEPT 11000.000 $FLU $P -55.594 GR NPHI 19.678 RHOB CALI 8.500 NRAT 32.438 21.859 .318 2.328 DEPT 10900 000 $FLU $P 8:633 GR NPHI 15.967 RHOB CALI 9.742 NRAT 29,531 100.167 2.553 2.182 DEPT 10800.000 SFLU SP 1.846 RHOB NPHI ~1.975 GE CAbI 19.938 NRAT 1.795 93.938 2.104 4.215 DEPT 10700.000 SFLU SP -94.563 GR NPHI -999.250 RHOB CALI -999.250 NRAT 2.074 110.938 999.250 DEPT 10600,000 SFLU SP -116.750 OR NPHI -999.250 RHOB CAbI -999.250 NRAT 2.701 1i4.t88 -999.250 -999.250 DEPT 10500.000 $FLU SP -114.563 GR NPHI -999.250 RHOB CALI -999.250 NRAT 1.866 110.917 -999,250 -999.250 DEPT 10400.000 SFLU Bp -119,000 GR NPHI '999.250 RHOB CALI '999.250 NRAT 3.391 85.542 999.250 DEPT 10300.000 8FLU $P -129.375 GR 2.]50 91. 33 NCNb ILM OR GR NCNb ILM GR GR NCNb IbM GR GR NCNb GR GR NCNb GR GR NCNb IbM GR GR NCNb IbM OR GR NCNb IbM GR GR NCNb IbM OR GR NCNb IbM GR NCNb IbM GR 4016.000 10.219 19.859 17.880 4116.000 1 29'2~5 5188.000 3 t9 3800. 28,156 27.859 27.042 3716.000 18.797 100.167 99.250 4296.000 ,5899 .~38 95. 67 1665.000 99 . 250 2.396 '999.250 '999.250 '999.250 1.658 '999.250 '999.250 '999.250 3.311 '999.~50 '999. 50 '999.250 2.865 -999,250 FCNb DT DRHO FCNb DT DRHO FCNb DT DRHO FCNb ILD DT DRHO FCNL DT DRHO FCNb ZbD DT DRHO FCNL DT DRHO FCNL DT DRHO FCNL DT DRHO FCNb ILD DT DRHO FCNL ILD DT 1775.000 8.977 81.771 0,053 1725.000 375 0,032 2868.000 50 563 94:521 0.036 1445,000 34.719 89.563 0 017 1618:000 2 344 0 O28 1815."000 1,489 106.958 0.041 363.500 .9991,585 '250 0 -999. 2.205 -999,250 -999.250 -999.250 i 599 -99 250 -999 250 -999 250 3.010 '999,~50 '999, 50 '999,250 2.670 -999.250 LVP 009,H05 VERIFICATfON LISTfNG , NPHI -999 250 RHOB CAUI -999:250 NEAT DEPT 10200.000 SFbU SP -12~ 312 GR NPHi -99~:250 RHOB CALf -999.250 NEAT DEPT 1~100 000 SFbU SP -127~500 GR NPHI -999'250 RHOB CALX -999;250 NEAT DEPT 10000,000 SFLU SP -128.875 GR NPHI '999.250 RHOB CALI -999,250 NEAT DEPT 9900 000 SFLU SP -127:750 GE NPHI -999.250 RHOB CAUI -999.250 NRAT DEPT 9800 000 SFLU SP -104:750 GR NPHI -999'250 RHOB CAbI -999.250 NEAT oo.ooo NPHI 9 250 RHOB DEPT 9600,000 $FLU sP NPHI -999*250 RHOB CAbI -999.250 NRA~ DEPT 9500.000 SFLU SP -99.000 GR NPHI 999 250 RHOB CALl ~999 :250 NRA~ DEPY 9400 000 SFbU SP -91:688 GR NPHI -999,250 RHOB CAbI -999.250 NRAT DEPT 9300,000 SFbU $P -99.000 GE NPHI -999 250 RHOB CALI -999:250 NRAT DEPT 9200.000 $FbU :999,250 999.250 2.6il 72 312 -9 9:2so -999.250 2.998 6b,042 '999,250 -999.250 1.549 107.479 -999.250 '999.250 1 631 104~417 -999 5 2,072 92.125 -999,250 -999,250 -999,250 -999.250 3.252 7~ 563 -99:250 -999.250 1 509 -999.250 -999.250 1.196 i07,167 -999.250 -999.250 377 -999.250 -999.250 1.468 GR NCNb GR NCNb GR GR NCNU GR NCNb GR NCNb NCNb GR NCNb ~R NCNb GR NCNb NCNb GR NCNb -99 250 2,826 -999.250 3.029 -999,250 -999,250 -999,250 1.507 -999.250 -999.250 -999,250 ! 91 -999 50 2,176 -999 50 -999.250 2.~67 -999. 50 -999 50 3.488 -999~250 -999,2~0 -999'250 1.402 -999.250 999 50 1,217 :999 250 999:250 -999.250 1.447 -999.250 -999.250 -999.250 1,611 DRHO FCNL IUD DT DRHO FCNb ILD DT DRHO FCNU DT DRHO FCNb IUD DT DRHO FCNb IUD DT DR~O FCNb DT DRHO FCNb IbD DY DRHO FCNL DY DRHO FCNL ILD DT DRHO FCN5 DT DRHO FCNU PAGE 999,250 :999.250 2.676 999,250 :999.250 -999.250 2,877 '999,250 '999,250 '999,250 1,420 '999,250 '999,250 '999,250 I 600 m -999,250 -999,250 -999,250 2 055 -999: so -999.250 -999.2S0 2.912 -999,2~0 -999,250 -999,250 3,42O -999 250 -999:250 -999,250 1,352 -999.250 999,250 -999250 -999~250 -999.250 1.410 -999,250 -999,250 -999,250 1.553 LVP 009,H05 VERIFICATION bI$?ING PAGE ? Sp -88,500 GR NPHI -999.250 RHOB CALI' -999.250 NRAT DEPT 9~00,000 SFbU SP 92,000 GR NPHI -999.250 RHOB CALI -999.250 NRAT DEPT 9000.000 SFLU Sp -94.063 GR NPHI -999.250 RHOB CALI -999'250 NRAT DEPT 8~00.000 SFbU Sp 96.500 GR NPHI ~999,250 RHOB CALI 999.250 NRAT DEPT 8BO0.O00 srbu SP .688 GR NPHI -999.250 RHOB CALf -999.250 NRAT DEPT 8600.000 SFLU Sp -96.688 GR NPHI -999 250 RHOB CALI '999:250 NRAT DW. PT 8..~00,000 SFLU Sp 52,406 GR NPHI 999.250 RHOB CALI -999.250 NRAT DEPT 8~00.000 SFLU SP 44.469 GR NPHI -999.250 RHOB CALl -999.250 NRAT DEPT 8200,000 SFLU SP -35,219 GR NPHI -999,250 RHOB CALl -999.250 NRAT [06 -999 '999 2 106 :999 999 2 90 .-999 999 2 999 -'999 1 9 -9979 -999 -999 -999 2 92 -999 -999 2 lO0 3 86 -999 -999 4 291 :999 999 2 -9 -999 ,729 .250 ,250 .318 .333 .250 .250 ,596 .OB3 .250 .250 859 '604 . ° .83! · i67 , 50 .250 .031 .917 .250 ,250 ,076 .521 ,250 ,250 .090 .000 .250 .250 ,094 813 :250 ,250 .447 . .250 GR GR NCNb IbM GR GR NCNb GR GR NCNb IbM GR GR NCNb GR GR NCNb GR GR NCNb GR GR NCNb GR GR NCNb IL~ GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb '999,250 -999.250 -999.250 '9992:225250 -999,250 -999,250 2,648 99 250 99 250 -999, -999.250 -999.250 ,946 -99~,25 · -999.25 '999.250 -999,250 -999,250 1.853 -999,250 -999,250 -999,250 2,330 -.999,250 999 250 -999:250 2.975 :999. 50 999,~250 -999,250 4.164 -999. 50 :999,250 999,250 i,845 999,150 : 99. 5o '999,250 DT DRHO FCNL ILD DT DRHO FCNL DT DRHO FCNL DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO FCNL 5O -99 250 . 2:1 25o -999 250 -999:250 2.621 99 . 50 999.250 . 2,961 999'25O -999. 1 920 -999 250 5O -999.250 -999.250 1.835 999 250 999 250 2 377 -999:250 -999,250 -999,250 2,961 299 50 9999:~50 '999.250 . 4 ~55 -99 250 1.723 i999!250 999250 -999 25O DEPT SP NPHI CALl DEPT SP NPHI CALI DEPT SP NPHI CAb! DEPT SP NPHI CALl DEPT SP NPHI DEPT SP NPHI CALl DEPT SP NPHI CALI DEPT SP NPHI CALI DEPT SP NPHI CALI DEPT SP NPHI CAbI DEPT SP NPHI 009,H05 VERIFICATION 8100.000 SFbU -3 719 GR -999.250 NRAT 8000.000 SFLU ~41,469 GR ' 99,250 RHOB -999.250 NRAT 7~00,000 SFLU 82,188 GR -999.250 RHOB -999,250 NRAT 7800,000 SFLU '88,125 GR '999.250 RHOB '999,250 NRAT 7700.000 SFbU -89.875 GR -999,250 RHOB -999.250 NRAT 7.6~0,000 SFLU 5.875 GR -999,250 RHOB -999,250 NRAT 00,000 SFLU '90'625 GR 999,250 RHOB -999,250 NRAT 7400.000 SFbU -88 375 GR -999;250 RHOB -999,250 NRAT 7300,000 SFLU -95,125 GR -999.250 RHOB -999.250 NRAT 7200,000 SFbU -95,625 GR -999,250 RHOB -999,250 NRAT 7100.000 SFLU -93.188 GR -999,250 RHOB -999,250 NRAT LISTING 2 35 -999,250 -999,250 4,066 93.52i -999.250 -999,250 2.326 84.250 -999.250 -999.250 2.920 .250 -999,250 2.949 85.729 -999.250 -999.250 3.281 -999. 0 -999.250 3 063 94!438 9999 250 299 250 2,756 81.208 -999.250 -999.250 990 -999 250 -999:250 3.271 81.958 -999 250 -999:250 ggg~250 GR GR NCNb IbM GR GR NCNb GR GR NCNb NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR OR NCNb .99~ '020 .250 -999.250 -999,-250 3.963 -999.250 -999.250 -999.250 2.350 -999,250 -999,250 -999,250 2,898 2999.250 999,250 -999,250 - 50 -999 50 3,441 -999 5 50 -999,250 3.295 -999.250 ,250 2.926 '999.250 '999.250 '999.250 .9993.242 .250 -999 250 3.80t -999,~50 -999, 50 -999,250 3,)18 '999. 50 999,2250 1999 ' 50 ILD DT DRHO FCNb ILD DT DRHO FCNb ILD DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO FCNL DT DRHO FCNL DT DRHO FCNb ILD DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO PAGE .959 -99 .250 -999.250 -999.250 3.699 999,250 -'999.250 -999.250 2,336 -999.250 999.250 2.963 -999,250 -999.250 -999.250 3 268 -999!250 -999 250 -999.250 3.547 -999,250 -999.250 -999.250 3.348 999.250 -'999.250 -999,250 3 014 -999:250 -999.250 -999,250 3.361 -999.250 -999.250 -999.250 3.928 -999.250 -999.250 -999.250 3.688 -999.25O -999.250 -999.250 bVP 009,H05 VERIFICATION bISTING PAGE 9 DEPT 7000,000 SP -95,000 NPHI -999,250 CAbI -999,250 DEPT 6900.000 SP -94.875 NPHI -999.250 CALI -999.250 DEPT 6800.000 SP -95.813 NPHI -999.250 CAbI -999.250 SP 98. NPHI -999.250 CALI -999.250 DEPT 6600.000 SP -96.312 NPHI -999.250 CAbI -999.250 DEPT 6~00,000 SP 95.625 NPHI -999.250 CAbI -999.250 DEPT 6400.000 SP -1~9.125 NPHI -999,250 CAbI -999.250 DEPT 6300.000 SP -130.125 NPHI -999.250 CAbI -999.250 DEPT 6200.000 SP -83 875 NPHI :9991250 CAbI 999.250 DEPT 6100.000 SP -81.063 NPHI _-999.250 CAbI 999.250 DEPT 6000.000 SP -80.375 NPHI -999.250 SFLU GR RHOB NRAT SFLU GR RHOB NRAT SFLU GR RHOB NRAT SFbU GR RHOB NRAT RHOB NRAT SFbU GR RHOB NRAT 8FbU GR RHOB NRAT SFbU GR RHOB NRA~ $FbU GR RHOB NRAT SFbU GR RHOB NRAT $FLU RHOB 3.3i6 88.500 -999.250 -999.250 10.258 73.292 9.250 4.289 8~.563 -99 .250 -999.250 3.~60 91, 58 -999.250 -999.250 5.855 72.729 '999.250 -999.250 3.500 62.260 :999.250 999.250 9.367 53.979 -999.250 -999.250 10.~58 59. 98 '999.250 -999.250 3.3O3 76.146 999.250 :999.250 4.727 60.958 999.250 3.465 84,229 '999.250 IbM GR GR NCNb GR NCNb GR GR NCNb IbM GR GR NCNb GR GR NCNb IbM GR GR NCNb GR GR NCNb IbM GR GR NCNb GR GR NCNb IbM GR GR NCNb GR GR 3.572 '999,250 m999.250 '999.25O 6,453 '999.250 '999 250 -999:250 4.742 :9 .2so -999.250 -999.250 -999.250 6.566 2so -999,250 3,572 ..'999i250 999 250 999 250 7,461 '999.250 -999.250 '999.250 . 7. 90 999'0250 '999.250 '999.250 3,723 99 ,250 999,250 55 -999,250 -999.250 3.898 -999.250 -999.250 ILD DT DRHO FCNL DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO FCNb ILD DT DRHO FCNL DT DRHO FCNb DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRMO 3.688 -999.250 -999.250 -999.250 . 5.727 999'250 -999.250 -999.250 5.027 -999.~50 -999. 50 -999.250 , 50 -99~.250 -99 .250 6.242 -99 250 -999.250 999.~50 :999, 50 7,469 999 250 . 6.~54 999" 50 -999'250 -999:250 4 035 :999!250 .999 250 999 25O 25O -999 250 -999:250 4 113 -999:250 -999.250 bYP 009,H05 VERIFICATION CALl -999,250 NRAT DEPT 5900.000 SFLU SP -132.125 GR NPHI -999,250 RHOB CAbI -999,250 NEAT DEPT 5800,000 SFLU SP -98,625 GR NPHI -999,250 RHOB CALI -999,250 NRAT SP --92~375 GR NPHI 999.250 RHOB CALf -999,250 NEAT DEPT 5600,000 SFLU SP -99,875 GR NPHI -999'250 RHOB CALX -999,250 NRAT DEPT 5500 000 SFEU SP -411594 GR NPHI -999 250 RHOB CALI -999 250 NEAT DEPT 5400,000 SFLU SP 63,125 GR NPHI -~99,250 RHOB CALI -999.250 NEAT -41:i NPH[ -999,250 RHOB CALl -999,250 NRAT DEPT 5200.000 SFLU SP 59~, 781 GR NPHI -~9 ' 250 EHOB CALI -99250NRAT~: DEPT 5100,000 SFLU SP -31,828 GR NPHI -999,250 RHOB CALI -999.250 NRAT DEPT 5000,000 SFLU SP 45,813 GR NPHI -~99.250 RHOB CALI -999,250 NRAT DEPT 4~00,000 SFbU SP 43.531 GR LISTING -999.250 443 -.999.250 999.250 6.348 52.2i9 .'999.250 999.250 11.0938 49, O0 .-99 2s° 25O 5.414 44.865 -999.250 -999,250 792 999.2250 3.312 60.729 -999.250 -999.250 643: 47! 594 -999.250 -999,250 7.977 52.854 -999,250 -999.250 5.746 57.115 5O 5,117 60.104 -999.250 -999.250 3,920 73,625 NCNb GR GR NCNb GR OR NCNb GE OR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR OR NCNb IbM GR GR NCNb IbM GR GR NCNL GR -999,250 .9919 .964 ,250 -.999.250 999,250 2.738 -999.250 -999,250 -999,250 4.793 -999~250 -999~250 -999.250 3.459 999, 0 999.250 3,605 -999.250 -999 s° o 2.715 -9 ,250 '999,250 3.918 -999.250 '999,~50 '999, 50 4.695 9 '250 -999,250 4.965 -999.250 -9 ,'250 4,488 -999.250 4,906 -999,250 FCNL ILD DT DRHO FCNL DT DRHO FCNL ILD DT DRHO FCNL ILD DT DRHO FCNb DT DRHO FCNb DT DRHO FCNb ILD DT DRHO FCNb DT DRHO FCNL ILD DT DRHO FCNL DT DRHO FCNL IbD DT PAGE -999.250 ,695 -99 .250 -999,250 -999.250 2,449 -999,250 -999.250 -999,250 3.943 -999,250 -999,250 -999,250 3.021 -999,250 -999,250 -999,250 3.908 -999,250 =999,250 =999.250 2,525 99 , 250 -999,250 3.891 -999.250 :999.250 999,250 4.473 -999.250 =999,250 =999,250 6 434 -999,250 -999.250 -999.250 4.496 :999.~50 999, 50 '999,250 5 371 -999,"250 10 bVP 009,H05 VERIFICATION bISTING PAGE NPHI '999,250 RHOB CALI -999.250 NRAT DEPT 4800,000 SFLU SP -46,312 GR NPHI -999,250 RHOB CALI -999.250 NRAT DEPT 4700,000 SFLU SP -76.813 GR NPHI -999.250 RHOB CALI -999.250 NRAT DEPT 4600.000 SFEU SP -57.531 GR NPHI -999,250 RHOB CALI -999.250 NRAT DEPT 4500,000 SFSU SP -46,251 GR NPHI -999,250 RHOB CASI -999,250 NRAT DEPT 4400.000 SFLU SP -80.813 GR NPHI -999.250 RHOB CALI -999.250 NRAT DEPT 4300.000 SFLU SP -44.063 GR NPHI -999,250 RHOB CALI -999,250 NRAT DEPT 4200,000 SFLU SP -42,563 GR NPHI :999,250 RHOB CALI 999.250 NRAT DEPT 4100.000 SFLU SP -58,312 GR DEPT 4000,000 SFLU SP 46,844 GR NPHI -~99.250 RHOB CALI -999.250 NRAT DEPT 3900.000 SFLU SP -57.750 GR NPHI -999.250 RHOB CALl -999.250 NRAT DEPT 3800.000 SFLU -999,250 -999,250 5.906 54.260 '999.250 -999.250 5.234 45,125 -999,250 -999,250 14.219 66 188 -999.250 5.316 70.854 -999.250 '999,250 6.598 32,589 -999.250 -999.250 4.22~ 54.25 -999,250 -999.250 5.402 72.667 '999.250 -999.250 8,820 66'396 -999.250 -999.250 .250 7 .792 -999.250 -999.250 7.227 45,208 -999.250 -999.250 6,531 GR NCNL GR GR NCNb GR GR NCNL GR GR NCN5 GR NCNL GR GR NCN~ GR NCNb GR GR NCNb ~R NCNL GR NCNb GR GR NCNL ~99 99~'250 .250 5,430 '999.250 '999,250 '999,250 ,0 04 '99 ,250 '999,250 '999,250 - 250 :999,250 999,250 5,379 -999,250 -999,250 -999,250 5,230 -999 250 -999,250 336 ,250 6 121 -999:250 -999,250 -999,250 8,859 '999.250 '99~,250 '99 ,250 5,051 Z999, 50 999,~50 -999,250 99~'363 -.250 -9 6,297 DRHO FCNb DT DRHO FCNL D~ DRHO FCNb DT DRHO FCNL DT DRHO DT DRHO FCN5 DT DRHO FCN5 DRHO FCNL DT DRHO FCNb DT DRHO FCNb DRHO FCNL ILD ~99 250 5.375 -999,250 -999.250 -999.250 . 670 -99 .250 -99 25O 16,750 -999,250 -99~,250 -99 .250 5 227 -999 50 -999 50 4 840 -999i250 -999 250 -999.250 6.707 -999,250 ,250 6,637 '99~.250 '99 ,250 '999.250 -999 250 -999 250 5,484 -99~ 250 -99:250 -999.250 99~:297 - 250 -999 250 6.883 LVP 009,H05 VERIFfCATION biSTING SP 39.813 GR NPHI '~99.250 RHOB CAbI '999.250 NRAT 77.8 -999.2 -999.2 DEPT l!O0.O00 SFbO SP 67.375 GR NPHI 999.250 RHOB CAbI -999.250 NEAT -.99 99~,2 DEPT 3600.000 SFbU SP -42.813 GR NPHI -999 250 RHOB CALl '999:250 NRAT 5 -99~ -999 DEPT 3500 000 SFhU SP 43:594 GR NPHI ~999 250 RHOB CALI 999,'250 NRAT 7 8 73:0 -999 2 DEPT 3400.000 SFLU 8P -72.i25 GR NPHI -999.250 RHOB CAbI -999.250 NRAT 6.8 48.5 -999.2 -999.2 DEPT 3~00 000 SFbU SP - 74:063GR NPHI -999.250 RHOB CALl -999.250 NRAT B 0 51:4 -999 DEPT 3200.000 SFLU SP -82 375 GE NPHI -999:250 RHOB CALI -999'250 NEAT 5.9 49 7 -999!2 -999 2 DEP2' 3100.000 SFLU SP -52.344 GR NPHI :999.250 RHOB CALl 999'250 NEAT 7.2 58.9 -999.2 -999.2 DEPT 3000.000 SFbU SP -70.063 GR NPHI -999.250 RHOB CALI -999.250 NRAT 6.9 54.1 -999 2 -999:2 DEPT 2.9.00!000 SFLU SP 48 031 GR NPHI 999 250 RHOB CALl -999.250 NRAT 5.2 66,5 -999.2 -999.2 DEPT 2800.000 SFbU SP 36.094 GR NPHI -~99.250 RHOB CAbI -999,250 NEAT 3.4 82 3 -999i2 -999 2 33 50 50 66 65 50 50 38 79 50 50 O1 83 5O 50 67 63 50 50 08 58 50 50 O8 5O 50 27 50 50 8O O4 5O 5O 58 O0 5O 5O 86 75 5O 50 GE GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR GR NCNb IbM GR NCNb IbM GR GR NCNb '99g.2250 -99 . 50 -999.250 7 5 -999 -999 ~50 5O 7.000 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