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Home My WebLink About200-012DECEIVED 2a5-oi 2 Conoco`Phillips "v "I'll Z c*( TRANSMITTAL A®GCC FROM: Sandra D. Lemke, ATO -704 TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 222 W. 711 Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Core Photo well list DATE: 11/15/2019 Transmitted: Name p► -2P-417 Care photos 3 1 4 4 5 t3 -f-144 - 35-16 Core Photos 31444, >01- Atlas 1 Core photos 3 1 4 4 3 pl-CD2-24 Core Photos 3 1 4 4 2 pt. Cirque3Core photos - Tlo _N 7- )00-i12 Meltwater North 1 UVWL photos—TZ5(0(00 WHO Shark Tooth 1 Core photos —T 2_409 129 1004025835_Meltwater- N- i.pdf-'-2S(o(o Z) ,� 1004278632_35-16.pdf 3 1 4 4 4 vo t� w 1Cfi42B2603_Rendeaous-A.pdf 3 1 4 4 6 please promptly sign, scan, and e-mail to CC: Receipt: V r V Date: Alaska/IT-GGRE 1 Co ocoPhil s Alaska i Office: 907 265 6947, Mobile 907.440.4512 000- bl a_ ConocoPhillips TRANSMITTAL FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Meltwater North 1 permit(200-012-0) DATE: 05/05/2015 Transmitted: North Alaska Exploration, Alaska Meltwater North 1 (501032032600) 1 electronic file via e-mail Meltwater North 1 -Core labs Sidewall Core analysis (7/26/2000) revised from earlier 5/24/2000 data-stated `samples are not fully cleaned at this time'. Please promptly sign, scan and return electronically to Sandra.D.Lemkec COP.com CC: Meltwater North 1 transmittal folder, production well files, eSearch Receipt: Date: /, GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph; 907.265.6947 SCOW MAY 0 7 2015 w •Ir 130 Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y . Y Y Y Y . Y Y Y Y Y Y Y . Y Y Y Y Y Y 0 co co CO CO CO (0 CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO M CO CO CO (0 CO CD CO 0 A.. 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Organizing RES~AN Color items: Grayscale items: [] Poor Quality Origi halS: [] Other: NOTES: DIGITAL DAT,~ OVERSIZED (Scannable) [] Diskettes, No. [] Maps: Other, No/Type [] BY: BEVERLY ROBIN VINCENT SHERY[(~INDY Other items scannable by large scanner OVERSIZED (Non-Scannable) j Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~INDY Scanning Preparation , ~'~ x 30 = ~ ~ BY: BEVERLY ROBIN VINCENT SHERYL(~JlNDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: //7 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: BY: BEVERL~VINCENT SHERYL MARIA WINDY Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPAN~I~RE BY; BEVERLY ROBIN VINCENT SHERYL MARIA ~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) y YESNO FOUND: YESNO III IIIIIIIIIII II III ReScanned ¢~.~vid,,=~ page ~.~pecial atte~ti~¢~j ~c~nlng complezed) RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd C: \TEMP\Meltl (local) - Microsoft Internet Explorer Page 1 of 1 C Sb Vt..CeAr) \ SILAAINED APR 1 2 2011 8/22/00 9:35:14 AM M e nu 42 C:\TEMPWeltljpg (local) - Microsoft Internet Explorer Page 1 of 1 frifr y ♦ 8/22/00 9:30:42 AM MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc COSSEaV T OS TONY KNOWLES, GOVERNOI~ 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 30, 2000 Paul Mazzolini Exploration Drilling Team Leader Phillips Alaska, Inc PO Box 100360 Anchorage, Alaska 99510-0360 Re: Location Clearance, Some NPRA Wells Dear Mr. Mazzolini: On August 2, 2000 our inspector Lou Grimaldi accompanied your representatives, Lee Gooding and Rick Overstreet, on final location clearance inspections of some North Slope wells. Mr. Grimaldi concluded that thewells listed below met the requirements for Location Clearance. Well Name Nanuk #2 Clover #A Meltwater North #1 Meltwater North #2 & 2A PTD No.. '~ 200-030 "~ 200-007 "~200-012 ~ x,~ 199/130 & 200-031 The Location Clearance inspections showed the locations were in compliance with 20 AAC 25.170 Onshore Location Clearance and therefore the Commission requires no further work on subject wells, however Phillips Alaska, Inc. remains liable if problems with the wells occur in the future. Sincerely, Blair E. Wondzell, Pc. ET. Sr. Petroleum Engineer L-lc-4pans.doc MEMORANDUM TO: THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission Dan Seamount, ~,~.~ ~- DATE: August 3, 2000 Chairman ~., Blair Wondzell, ~ P. I. Supervi,,sor .~/ Lou Grimaldi, /,o~ ~.. Petroleum Inspector SUBJECT: Location Clearance Meltwater North 1 PTD #200-0.120 Wednesday, Auqust 2, 2000; I made a Location Clearance Inspection on the abandoned exploratory well Meltwater North 1. I was accompanied today by Lee Gooding (Phillips environmental tech) and Rick Overstreet (Phillips KRU drilling superintendent). We flew to the location by helicopter and verified proper location by G.P.S. coordinates. Meltwater North 1 was drilled and abandoned this last winter exploratory season. Other than the mound of clean gravel over the cellar there was no indications of any drilling activity on thiS location. We flew the ice road path this was clean and seemed well vegetated. I recommend this location be approved for final clearance. SUMMARY: I made a Location clearance inspection on Meltwater North 1. No problems were observed. Attachments: Loc Clear Meltwater North 1 8-2-00 LG.xls Digital Photographs (2); Meltwater North #1 cellar.jpg Meltwater North #1 airshot.jpg "As Built" for location cc: Phillip's Petroleum Co. NON-CONFIDENTIAL LOc Clear Meltwater North 1 8-2-00 LG.doc PHILLIPS Alaska, Inc. A Subsidiary of PHIllIpS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO1354 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Directional survey data DATE: 08/01/2000 Ak. Oil & Gas Conservation Comm. ATTN: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99510 Transmitted herewith is the following: Transmittal of directional survey data for 4 1999-2000 North Slope Exploration wells: Permit 200-012 Meltwater North 1; Sperry Sun Job # AKMM90251 Permit 200-031 Meltwater North 2A; Sperry Sun Job # AKMM90261 Permit 199-130 Meltwater North 2; Sperry Sun Job # AKMM90232 Permit 200-030 Nanuk 2; Sperry Sun Job # AKMM0002 CC: Mark McDermott Sharon AIIsup-Drake Approved for transmittal by: SandraLemke Return receipt to: ~ Phillips Alaska, Inc. ATTN: S. Lemke, ATO-1354 700 G. Street Anchorage, AK 99501 Date: AUG 0 2000 Alaska 0il & Gas Cons, Commission Anchorage Prepared by: Sandra D. Lemke Phillips Alaska IT Geoscience Group PHILLIPS Alaska, Inc. A ~lbsidid~y of PHILUPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO1354 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 Loft Taylor AOC~C 3001 Porcupine Drive Anchorage, Alaska 99501 DATE: 06/29/2000 Transmitted h~ith is the following: Meltwater North 1 (501032032600) Color log: Schlumberger FMI Images/MSD Dips-Geoframe processeXl interpretations; 3/2/2000 CC: Mark McDermott Approved for transmittal~by: Greg Wilson Receipt: Return receipt to: s Alaska, Inc. A'i'TN: $. Lemke, ATO-t3~ 700 G. Street Anchorage, AK 99501 RECEIVED Date: JUL 05 2000 Alaska 0il & Gas Cons. Commission Anchorage Prepared by: Sandm D. Lemke Phillips Alaska IT Geoscience Group Sta~e of Alaska ~~ oz.:, .'..70. Name '' loc. sca:',,s, anc~ !ocaCi:n clearance - .pr~e '~ell head =aC o~_: ' ~ ~ ..... i iiii i ~ i ii lll, · Code PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Paul Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 May 30, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Meltwater North #1 (Permit 200-012/300-052) Completion Report- Addendum Dear Mr. Christenson: Phillips Alaska, Inc., as operator of the Meltwater North #1 exploration well, submits the enclosed additional reports to the "Well Completion Report" (form 407). Attached is the production data, sidewall core analysis and conventional core analysis, P&A summary and photos of the P&A operations, time chart and a memo of abnormal pressure. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. If you have any questions regarding this matter, please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely, Paul Mazzolini Exploration Drilling Team Leader PA1 Drilling PAM/TJB/skad gJa~ka 0~! & ~s Cons~ Co~'~mi~ior: ARCO Alaska, Inc. Date: Subject: Internal Correspondence 3120100 Abnormal Pressure in Meltwater North #2 & #1 From/Location: Telephone: To/Location: T.J. Brassfield 265-6377 Sharon AIIsup-Drake As reqUested from the DNR for data submittal on the Meltwater North #2 & #1 wells, there were no abnormally pressured zones encountered while drilling these wells. Please find attached the mud weight graphs plotted by depth for both of the wells. Any questions, please call me at 265-6377 or Paul Mazzolini at 263-4603. ~a~ I~r~l~ ~lEd n gineer~ CC: MW'N #1 & #2 Well Files ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany i'i.'.'? ' :"'~~'~ John C Braden 05/24/2000 10:53 AM To: Sharon AIIsup-Drake/AAI/ARCO @ ARCO cc: Tom J Brassfield/AAI/ARCO@ARCO Subject: Re: MWN#1 well test ~ Here you go Sharon AIIsup-Drake ::.,., :!~ '~ ..... Sharon AIIsup-Drake :::... 05/16~2000 10:28 AM : To: John C Braden/AAI/ARCO@ARCO cc: Tom J Brassfield/AAI/ARCO @ ARCO Subject: MWN#1 welltest John, after reviewing the PBU you sent earlier, I think sending AOGCC just a summary of the production data would suffice. On the form, AOGCC only requires the following data: date of first production 3/20/2000 date of test 3/20/2000 - 3/25/2000 hours tested 116 status (flowing, gas lift, shut-in) shut-in and P&A production rate for the test period (oil, water, gas) 2373 BOPD, 117 BWPD, 1342 MSCFpD production rate for a 24-hour period (oil, water, gas) 3892 BOPD, 50 BWPD, 2265 MSCFpD GOR 566 SCF/BO choke size 60/64-68/64 oil gravity 36.3 flow tubing pressure 370-412 psig casing pressure 790-850psig thanks, Sharon Injection Test Performed injection test from 4/6/00 to 4/10/00. Total of 4495 bbls of produced water injected into MWN #1. Meltwater North #1 P&A RU Dowell cementers. Load 7"x 3.5" annulus with 130 bbls 9.3 ppg brine. RU S/L and set DV in mandrel at 5137'. PT 7" to 1000 psi. Perform down squeeze on 9-5/8" annulus to 1000' using 23,, bbls Arctic Set cement. Attempt to squeeze tubing with 35 bbls Class G cement. Well took all ~ , cement on vacuum. Overdisplaced tubing by 8 bbls with 9.3 brine and capped with 5 bbls diesel "-J for freeze protect. Set DV @ 5137' RKB. PT casing to 1000#. Good. RU Dowell cementers for resqueeze. Pump 20 bbls Class G with 600# aggregate followed by 24'"~ bbls Class G. Displace with 9.3 brine and diesel cap. Pressure out with diesel cap at 3000 psi. Estimate top at 2400'. Squeeze approximately 8 bbls with aggregate into perfs. Tagged cement at 1754'. Tbg pt good. Set CIBP at 320', punched holes 310'-312'. Lost entire toolstring (26.6') parted at weak point. Retrieved e-line tool string @ 285' SLM. PJSM. Pressure tested CIBP to 2000 psi, good test. Circulated cement for top plug down tubing and up tubing x 7" annulus. Good cement to surface. Page 1 of 1 file ://C :\TEMPWIvc-009 s .jpg 5/23/00 Page 1 of 1 file://C:\TEMPWIvc-008 s.j pg 5/23/00 Page 1 of 1 file://C:\TEMP\-0027040.jpg 5~23/00 Page 1 of 1 file://C:\TEMPWIvc-006s.jpg 2.000 5/23/00 Page 1 of 1 file :ftC :\TEMPWIvc-005 s .jpg 5 ~23/00 Core Lab ARCO Alaska ~I ~ 02 ?_000 Meltwater #1 Kuparuk Field ....... ~:~-~ ........ ~-:~:~ C~m~ r~.,,m ;'~; ~ Preliminary Rotary Sidewall Core Dean-Stark Analysis Results CL File No.: 57111- 00082 1 5423 o.0o4 2 5427 0.11 3 5466 0.010 4 5494 o.56 5 5495 22. 6 5498 0.13 7 5501- 2.7 8 5503 9.3 9 5505 0.012 10 5507 14. 11 5511 0.060 12 5513 1.9 13 5515 0.043 14 5517 13. 15 5520 15. 16 5524 1.4 17 5531 25. 18 5533 1.0 19 5535 3.7 20 5537 3.9 21 5541 .0.033 22 5543 0.024 23 5545 0.73 24 5548 6.2 25 5550 20. 26 5553 13. 27 5556 3.6 28 5559 10. 29 5561 14. 8.3 0.0 64.6 0.00 64.6 16.2 0.0 73.8 0.00 73.8 11.3 0.0 99.1 0.00 99.1 16.0 10.7 72.5 0.15 83.3 20.5 26.5 39.7 0.67 66.2 15.0 0.0 90.1 0.00 90.1 17.3 26.7 58.4 0.46 85,1 20.4 13.3 41.9 0,32 55.3 7.2 0.0 85.8 0.00 85.8 18.2 16.6 54.2 0.31 70.7 14.7 0.0 98.4 0.00 98.4 18.7 11.0 61.7 0.18 72.8 11.9 0.0 75.8 0.00 75.8 22.2 14.1 53.8 0,26 67.9 21.7 14.2 50.0 0.28 64.2 18.4 6.6 71.0 0.09 77.6 23.2 13.1 40.8 0.32 53.9 13,8 8.4 64.4 0.13 72.8 21.9 13.7 61.0 0,22 74.7 18.5 16.8 44.1 0.38 60,9 15.2 0.0 25.4 0,00 25.4 18.7 0.0 76.4 0.00 76.4 19.1 11.8 51.0 0.23 62.8 21.2 15.8 57.0 0.28 72.8 19.9 16.4 43.9 0.37 60.3 22.8 12.5 46.4 0.27 58.8 19.9 8.2 54.1 0.15 62.3 22.1 10.1 51.5 0.20 61,6 22.6 12.8 55.6 0.23 68.4 2.69 2.67 2.62 2.65 2.67 2,59 2.68 2.64 2.72 2.65 2.69 2.65 2.68 2.67 2.69 2.69 2.71 2.71 2.68 2.68 2.70 2.80 2.64 2.66 2.67 2.66 2.73 2,66 2,70 Sst gry vfgr vslty calc no stn no flu Sst gry vfgr slty no stn no flu Sst gry vfgr vslty sh in~l no stn no flu Sst tan vf-fgr slty m stn gld flu Sst tan vf-fgr slty m Stn gld flu Sst gry vfgr vslty carb strks no stn no flu Sh gry-tan vf-fgr sdy lam slty m strk stn yel-gld flu Sst tan vf-fgr Slty rn stn yel-gld flu Sst gry vfgr vslty calc no stn no flu Sst It brn vf-fgr slty rn stn yel-gld flu Sst gry vfgr vslty no stn no flu Sst tan vfgr slty m stn yel-gld flu Sst gry vfgr vslty calc no stn no flu Sst tan vfgr slty m stn yel-gld flu Sst tan vfgr slty m stn yel-gld flu Sh gry-tan vfgr sdy lam m strk stn yel-gld flu Sst tan vfgr slty m stn yel-gld flu Sst tan-gry vfgr slty sh incls m sptd stn yel-gld flu Sst tan vfgr slty m stn yel-gld flu Sst tan vfgr slty rn stn yel-gld flu Sh gry vfgr sdy lam slty no stn no flu Sst gry vfgr vslty no stn no flu Sst tan vfgr slty m stn yel-gld flu Sst tan vfgr slty m stn yel-gld flu Sst tan vfgr slty chrt incl m stn yel-gld flu Sst tan vfgr slty m stn yel-gld flu Sst tan-gry vfgr vslty cht incl m strk stn yel-gld flu Sst tan vfgr slty cht incl m stn yel-gld flu Sst tan vfgr slty cht incl m stn yel-gld flu Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Many samples have thin streaks of carbonaceous material that may have contributed to micro-fractUring. All samples with will be more closely examined for evidence of fracturing prior to issueing final data. Core Lab Sample No. ARCO Alaska MeltWater #1 Kuparuk Field Prelimina Rotary Sidewall Core Dean-Stark AnalYsis Results Por. % 30 5563 5.6 20.3 11.8 59.5 0.20 71.3 2.66 31 5565 1.8 20.7 8.5 61.7 0.14 70.2 2.89 32 5567 16. 21.9 15.7 49.8 0.32 65.5 2.70 33 5569 21. 21.0 12.0 65.3 0.18 77.3 2.70 34 5571 6.5 19.7 14.1 60.0 0.24 74.1 2.70 35 5574 0.22 16.5 10.8 74.6 0.15 85.5 2.68 36 5577 0,24 18.5 0.0 85.8 0.00 85.8 2.63 37 5579 0.19 16.5 8.3 52.2 0.16 60.4 2.61 38 5582 5.0 21.2 13.4 63.5 0.21 76.9 2.65 39 5586 13. 20.5 13.7 58.6 0.23 72.3 2.67 40 5589 7.6 22.3 9.4 58.2 0.16 67.6 2.70 41 5591 7.6 21.4 14.2 55.7 0.26 69.9 2.70 42 5593 6.8 21.5 11.4 52.0 0.22 63.4 2.69 43 5597 2.7 20.4 28.0 54.5 0.51 82.5 2.74 44 5601 0.28 19.2 6.0 65.4 0.09 71.4 2.67 Sst tan-gry vfgr slty Ig cht incl m strk stn yel-gld flu Sst tan vfgr slty sh incl m stn yel-gld flu Sst tan vfgr slty cht incl sh incl m stn yel-gld flu Sst tan vfgr slty cbt incl m stn yel-gld flu Sst gry-tan vfgr slty Ig sh incl m strk stn yel-gld flu Sst gry vfgr vslty no stn no flu Sst gry-tan vfgr vslty sh incl It strk stn yel-gld flu Sst tan vfgr slty sh incl m stn yel-gld flu Sst tan vfgr slty m stn yel-gld flu Sst tan vfgr slty m stn yel-gld flu Sst tan vfgr slty m stn yel-gld flu Sst tan vfgr slty sh incl m stn yel-gld flu Sst tan vfgr slty m stn yel-gld flu Sst tan vfgr slty m stn yel-gld flu Sst gry-tan vfgr slty Ig sh lams m strk stn yel-gld flu CL File No.: 57111- 00082 Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Dean Stark Core Lab Many samples have thin streaks of carbonaceous material that may have contributed to micro-fracturing. All samples with will be more closely examined for evidence of fracturing prior to iSsueing final data. ARCO ALASKA, INC. Meltwater North #1 2000 PRELIMINARY CORE ANALYSIS RESULTS CL File No. · 57111- 00048 Samples were not fully cleaned at this time 1 5607.1 0.118 14.3 0.0 86.8 0.00 86.8 2.64 2 5608.1 0.057 13.6 0.0 84.9 0.00 84.9 2.63 3 5609.1 0.004 12.1 0.0 92.6 0.00 92.6 2.70 4 5610.1 0.028 11.2 0.0 93.8 0.00 93.8 2.65 5 5611.4 0.010 8.6 5.6 71.8 0.08 77.4 2.68 6 5612.1 0.065 13.9 0.0 95.8 0.00 95.8 2.66 7 5613.1 0.026 11.6 0.0 90.0 0.00 90.0 2.63 8 5614.1 0.165 14.2 0.0 90.9 0.00 90.9 2.65 9 5615.1 0.139 12.9 0.0 92.7 0.00 92.7 2.66 10 5616.1 0.147 16.8 1.9 85.5 0,02 87.4 2.74 11 5617.1 0.129 11.4 0.8 73.2 0.01 74.0 2.61 12 5618.1 0.025 14.8 33.4 63.7 0.52 97:1 2.62 13 5619.1 1.491 14.8 35.7 42.4 0.84 78.1 2.63 14 5620.1 1.165 18.3 32.7 46.6 0.70 79.3 2.64 15 5621.1 5.758 20.0 28.8 51.1 0.56 79.9 2.65 16 5622.1 17. 18.4 32.8 46.7 0.70 79.4 2.66 17 5623.1 21. 20.6 31.4 52.4 0.'60 83.8 2.67 18 5624.1 0.127 16.8 2.2 88.4 0.02 90.5 2.68 19 5625.1 17. 21.1 25.4 54.0 0.47 79.5 2.65 20 5626.1 1.423 19.4 13.8 67.3 0.20 81.1 2.66 21 5627.1 0.464 18.7 8.3 70.4 0.12 78.7 2.65 22 5628.4 1.703 19.7 17.0 59.7 0.28 76.7 2.63 23 5629.2 21. 19.1 14.4 63.0 0.23 77.4 2.63 24 5630.1 21. 20.2 38.8 51.4 0.75 90.2 2.66 25 5631.3 1.624 18.1 20.8 61.3 0.34 82.1 2.64 Sst gry vfgr vslty carb strks shly no stn no flu Dean Starl~ Sst gry vfgr vslty carb strks shly no stn no flu Dean Starl, Sh gry slty si calc no stn no flu Dean Starl~ Sst gry vfgr vslty Ig sh lams carb strks no stn no fkDean Starl~ Sst gry-tan vfgr vslty m strk stn yel-grn flu Dean Star~ Sst gry vfgr vslty sh lams carb no stn no flu Dean Starl, Sst gry vfgr vslty sh lams carb no stn no flu Dean Starl~ Sst gry vfgr vslty carb strks no stn no flu Dean Starl~ Sst gry vfgr vslty carb strks no stn no flu Dean Stari~ Sst gry-lt tan vfgr vslty It sptd stn yel-grn flu Dean Starl~ Sst tan vfgr vslty sh strk It stn yel-grn flu Dean Starl~ Sst gry-lt tan vfgr vslty carb strks shly It sptd stn wlDean Starl~ Sst tan vfgr slty sh incl m stn yel-grn flu Dean Starl~ Sst tan vfgr slty carb strks m stn yel-grn flu Dean Sst tan vfgr slty sh incl m stn yel-grn flu Dean Sst tan vfgr slty m stn yel-grn flu Dean Sst tan vfgr slty m stn yel-grn flu Dean Sst gry-lt tan vfgr vslty carb incl It sptd stn yel-grn fDean Sst tan vfgr slty sh incl m stn yel-grn flu Dean Sst tan vfgr slty carb incl m stn yel-grn flu Sst tan vfgr slty m stn yel-grn flu Sst tan vfgr slty m stn yel-grn flu Sst tan vfgr slty m stn yel-grn flu Sst It tan vf-fgr slty It stn yel-grn flu Sst tan vfgr slty carb strk m stn yel-grn flu Dean Dean Dean Dean Dean Dean 13-Mar-O0 13-Mar-O0 13-Mar-O0 13-Mar-O0 13-Mar-O0 13-Mar-O0 13-Mar-O0 13-Mar-O0 13-Mar-O0 13-Mar-O0 13-Mar-O0 13-Mar-O0 13-Mar-O0 Starl~ 13-Mar-O0 Starl~ 13-Mar-O0 Starl~ 13-Mar-O0 Starl~ 13-Mar-O0 Starl~ 13-Mar-O0 Starl~ 13-Mar-O0 Starl~ 13-Mar-O0 Starl~ 13-Mar-O0 Starl~ 13-Mar-O0 Starl~ 13-Mar-O0 Starl~ 13-Mar-O0 Starl~ 13-Mar-O0 Convential Core Analysis Results Page I 5/24/00 ARCO ALASKA, INC. Meltwater North #1 JUH 02 2000 .daska Oii & Gas Cons, Commksion PRELIMINARY CORE ANALYSIS RESULTS CL File No.: 57111- 00048 Samples were not fully cleaned at this time 26 5632.1 0.016 9.7 3.8 86.2 0.04 90.1 2.73 Sst gry-lt tan vfgr vslty vcalc It sptd stn wh-yel flu Dean Starl~ 13-Mar-00 27 5633.4 0.290 14.0 0.8 97.4 0.01 98.3 2.67 Sst gry-lt tan vfgr vslty carb strk It sptd stn yel-grn 1Dean Starl~ 13-Mar-00 28 5634.1 49. 20.8 34.9 53.1 0.66 88.0 2.66 Sst tan vfgr slty m stn yel-grn flu Dean Starl~ 13-Mar-00 29 5635.5 1.000 15.1 12.5 76.3 0.16 88.8 2.63 Sst tan vfgr slty m stn yel-grn flu Dean Starl, 13-Mar-00 30 5636.1 1.883 18.5 17.7 64.7 0.27 82.4 2.70 Sst tan vfgr slty m stn yel-grn flu Dean Starl~ 13-Mar-00 31 5637.1 15. 21.1 23.0 58.1 0.39 81.1 2.67 Sst tan vfgr slty m stn yel-grn flu Dean Starl~ 13-Mar-00 32 5638.1 3.989 19.5 17.2 61.7 0.28 78.9 2.66 Sst tan vfgr slty'carb incl m stn yel-grn flu Dean Starl~ 13-Mar-00 33 5639.1 62. 20.1 32.7 50.2 0.65 82.9 2.66 Sst tan vf-fgr slty sh incl m stn yel-grn flu Dean Starl~ 13-Mar-00 34 5640.2 3.724 19.0 22.9 58.0 0.40 80.9 2.68 Sst tan vfgr slty m stn yel-grn flu Dean Starl~ 13-Mar-00 35 5641.1 43. 20.7 24.1 51.8 0.46 75.8 2.68 Sst tan vfgr slty m stn yel-grn flu Dean Starl~ 13-Mar-00 36 5642.1 48. 21.2 38.1 41.0 0.93 79.2 2.66 Sst tan vfgr slty m stn yel-grn flu Dean Starl~ 13-Mar-00 37 5643.2 16. 20.3 27.3 54.2 0.50 81.5 2.67 Sst tan vfgr slty m stn yel-grn flu Dean Starl~ 13-Mar-O0 38 5644.1 8.366 17.3 23.0 62.2 0.37 85.1 2.64 Sst tan vfgr slty sh incls m stn yel-grn flu Dean Starl, 13-Mar-00 39 5645.2 0.016 10.1 1.3 72.5 0.02 73.8 2.70 Sst gry-lt tan vfgr vslty sh incl vcalc It sptd stn wh-~Dean Starl~ 13-Mar-00 40 5646.1 5.701 19.2 25.3 59.2 0.43 84.5 2.66 Sst tan vfgr slty m stn yel-grn flu Dean Starl~ 13-Mar-00 41 5647.2 0.476 19.1 8.2 74.0 0.11 82.2 2.67 Sst tan vfgr vslty carb m stn yel-grn flu Dean Starl~ 13-Mar-00 42 5648.1 0.239 20.3 9.5 70.8 0.13 80.3 2.72 Sst It tan vfgr vslty carb It stn yel-grn flu Dean Stari~ 13-Mar-00 43 5649.2 0.132 20.2 3.5 82.0 0.04 85.5 2.71 Sst It tan vfgr vslty carb It stn yel-grn flu Dean Starl~ 13-Mar-00 44 5650.1 4.896 20.6 28.0 57.4 0.49 85.4 2.65 Sst tan vfgr slty m stn yel-grn flu Dean Starl~ 13-Mar-00 45 5651.1 2.092 20.9 16.4 65.2 0.25 81.6 2.69 Sst tan vfgr slty m stn yel-grn flu Dean Star~ 13-Mar-00 46 5652.1 0.784 21.2 12.9 70.3 0.18 83.2 2.70 Sst It tan vfgr slty It stn yel-grn flu Dean Starl~ 13-Mar-00 47 5653.1 1.186 20.9 17.7 65.5 0.27 83.2 2.69 Sst tan vfgr slty carb m stn yel-grn flu Dean Starl~ 13-Mar-00 48 5654.2 2.563 21.7 16.4 65.7 0.25 82.1 2.68 Sst tan vfgr slty carb m stn yel-grn flu Dean Starl~ 13-Mar-00 49 5655.2 0.687 21.2 13.5 68.9 0.20 82.4 2.70 Sst tan vfgr slty mica It stn yel-grn flu Dean Starl~ 13-Mar-00 50 5656.2 0.919 21.6 11.2 71.6 0.16 82.8 2.70 Sst tan vfgr slty mica It stn yel-grn flu Dean Starl~ 13-Mar-00 Convential Core Analysis Results Page 2 5/24/00 ARCO ALASKA, INC. Meltwater North #1 CL File No. · 57111- 00048 PRELIMINARY CORE ANALYSIS RESULTS Samples were not fully cleaned at this time 51 5657.2 2.398 21.3 18.9 64.7 0.29 83.6 2.71 52 5658.2 8.952 20.4 24.8 54.4 0.46 79.2 2.69 53 5659.2 4.807 21.2 21.9 62.5 0.35 84.4 2.67 54 5660.2 2.690 20.0 18.3 63.3 0.29 81.6 2.70 55 5661.2 1.491 19.8 21.2 62.4 0.34 83.6 2.71 56 5662.2 0.020 9.6 6.1 77.3 0.08 83.4 2.71 57 5663.1 0.012 7.5 6.4 77.7 0.08 84.1 2.71 58 5664.3 0.012 7.9 6.9 72.5 0.10 79.4 2.71 Sst tan vfgr slty chrt incl mica m stn yel-grn flu Dean Star~ 13-Mar-00 Sst tan vfgr slty mica m stn yel-grn flu Dean Star~ 13-Mar-00 sst tan vfgr slty mica sh incl m stn yel-grn flu Dean Starl~ 13-Mar-00 Sst tan vfgr slty mica m stn yel-grn flu Dean Starl~ 13-Mar-00 Sst tan vfgr slty mica m stn yel-grn flu Dean Starl~ 13-Mar-00 Sst gry-lt tan vfgr vslty sh incl vcalc It sptd stn wh-~Dean Star~ 13-Mar-00 Sst gry-lt tan vfgr vslty vcalc It sptd stn wh-yel flu Dean Star~ 13-Mar-00 Sst gry-lt tan vfgr vslty vcalc It sptd stn wh-yel flu Dean Star~ 13-Mar-00 Convential Core Analysis Results Page 3 5~24~00 ARCO ALASKA, INC. Meltwater North #1 PRELIMINARY CORE ANALYSIS RESULTS CL File No.: 57111- 00048 Samples were not fully cleaned at this time 59 5665.3 0.012 9.5 9.5 70.6 0.13 80.0 2.72 Sst gry-lt tan vfgr vslty vcalc It sptd stn wh-yel flu Dean Star~ 13-Mar-00 60 5666.3 1.967 18.8 22.8 56.9 0.40 79.7 2.72 Sst tan vfgr slty chit incl mica m stn yel-gm flu Dean Star~ 13-Mar-00 61 5667.2 2.746 20.0 25.9 55.2 0.47 81.1 2.72 Sst tan vfgr slty chit incl m stn yel-grn flu Dean Starl~ 13-Mar-00 62 5668.1 2.667 19.2 30.0 59.8 0.50 89.8 2.72 Sst tan vfgr slty chit incl m stn yel-grn flu Dean Star~ 13-Mar-00 63 5669.2 8.886 21.2 27.3 55.1 0.49 82.3 2.74 Sst tan vfgr slty Ig chit incl mica m stn yel-grn flu Dean Star~ 13-Mar-00 64 5670.2 8.085 19.7 28.3 48.4 0.58 76.7 2.70 Sst tan vfgr slty Ig sh incl chit incl mica m stn yel-g Dean Star~ 13-Mar-00 65 5671.2 2.574 15.9 21.0 59.5 0.35 80.5 2~69 Sst tan vfgr slty Ig sh incls mica m stn yel-grn fluDean Star~ 13-Mar-00 66 5672.1 12. 20.1 31.2 45.5 0.68 76.7 2.70 Sst tan vfgr slty sh incl chrt incl ns stn yel-grn flu Dean Star~ 13-Mar-00 67 5673.1 0.220 12.6 0.0 91.9 0.00 91.9 2.70 Sst gry vfgr vslty vshly no stn no flu Dean Star~ 13-Mar-00 68 5674.1 0.248 14.9 5.9 75.1 0.08 81.0 2.62 Sst tan vfgr vslty It stn yel-grn flu Dean Star~ 13-Mar-00 69 5675.1 5.051 12.6 0.0 93.5 0.00 93.5 2.62 Sst gry vfgr vslty carb strks no stn no flu Dean Starl~ 13-Mar-O0 70 5676.2 0.076 15.8 0.0 93.7 0.00 93.7 2.70 Sst gry vfgr vslty mica no stn no vis flu Dean Star~ 13-Mar-00 71 5677.2 0.077 17.4 0.0 91.7 0.00 91.7 2.73 Sst gry vfgr vslty mica carb incl no stn no vis flu Dean Star~ 13-Mar-00 72 5678.2 5.052 19.3 27.6 53.3 0.52 81.0 2.67 Sst tan vfgr vslty mica m stn yel-grn flu Dean Starl~ 13-Mar-00 73 5679.1 12. 19.9 32.1 46.6 0.69 78.7 2.67 Sst tan vfgr slty mica ns stn yel-grn flu Dean Star~ 13-Mar-00 74 5680.2 2.793 18.8 25.3 54.9 0.46 80.3 2.67 Sst tan vfgr slty mica rn stn yel-grn flu Dean Star~ 13-Mar-00 75 5681.2 0.002 8.4 8.3 76.0 0.11 84.4 2.70 Sst gry-lt tan vfgr vslty calc mica It sptd stn wh-yel Dean Star~ 13-Mar-00 76 5682.2 13. 20.5 27.3 50.7 0.54 78.0 2.69 Sst tan vfgr slty mica m stn yel-grn flu Dean Star~ 13-Mar-00 77 5683.2 4.051 19.2 27.6 53.1 0.52 80.7 2.65 Sst tan vfgr slty sh incl mica m stn yel-grn flu Dean Star~ 13-Mar-00 78 5684.2 2.571 19.9 20.9 56.6 0.37 77.5 2.68 Sst tan vfgr slty chrt incl mica m stn yel-grn flu Dean Star~ 13-Mar-00 79 5685.1 1.289 16.7 14.8 64.3 0.23 79.1 2.65 Sst tan vfgr slty mica m stn yel-grn flu Dean Star~ 13-Mar-00 80 5686.1 1.740 18.4 16.3 62.2 0.26 78.5 2.64 Sst tan vfgr vslty carb incl micaq m stn yel-grn flu Dean Star~ 13-Mar-00 81 5687.1 63. 20.2 41.2 47.1 0.87 88.3 2.67 Sst tan vf-mgr slty sh lam chrt incl mica m stn yeP(. Dean Starl 13-Mar-00 82 5688.2 6.459 19.7 22.8 58.2 0.39 81.1 2.69 Sst tan vfgr slty chrt incl mica m stn yel-grn flu Dean Starl 13-Mar-00 83 5689.2 43. 21.0 30.0 49.2 0.61 79.2 2.67 Sst tan vfgr slty chrt incl mica m stn yel-grn flu Dean Stad 13-Mar-00 Convential Core Analysis Results Page 4 5/24/00 ARCO ALASKA, INC. Meltwater North #1 02 2000 PRELIMINARY CORE ANALYSIS RESULTS CL File No. - 57111- 00048 Samples were not fully cleaned at this time 84 5690.2 2.792 16.4 17.2 63.8 0.27 81.0 2.65 Sst 85 5691.2 3.639 19.5 17.6 62.7 0.28 80.2 2.67 Sst 86 5692.1 20. 20.6 30.6 47.4 0.65 78.0 2.67 Sst 87 5693.2 2.845 18.6 15.1 63.5 0.24 78.6 2.68 Sst 88 5694.1 3.425 18.9 18.1 60.8 0.30 79.0 2.68 Sst 89 5695.2 5.408 19.5 17.5 60.4 0.29 77.9 2.70 Sst 90 5696.1 6.628 19.7 21.7 57.3 0.38 79.0 2.70 Sst 91 5697.2 7.548 19.9 21.0 58.5 0.36 79.5 2.70 Sst 92 5698.2 5.980 20.1 21.2 59.5 0.36 80.7 2.69 Sst 93 5699.2 3.928 19.7 15.4 62.1 0.25 77.6 2.68 Sst 94 5700.2 2.373 19.2 14.2 64.5 0.22 78.7 2.68 Sst 95 5701.3 2.128 -19.6 11.7 65.0 0.18 76.7 2.67 Sst 96 5702.1 2.850 19.0 24.5 62.0 0.39 86.5 2.70 Sst 97 5703.2 0.072 12.8 2.5 76.3 0.03 78.8 2.70 Sst 98 5704.1 0.079 13.1 2.9 77.4 0.04 80.3 2.70 Sst 99 5705.2 0.092 9.7 13.6 71.1 0.19 84.7 2.70 Sst 100 5706.2 0.013 11.4 5.3 81.7 0.06 87.0 2.70 Sst 101 5707.2 0.023 11.9 7.8 78.4 0.10 86.2 2.72 Sst 102 5708.1 0.010 11.4 5.9 82.4 0.07 88.4 2.74 Sst 103 5709.2 0.014 8.7 4.6 84.5 0.05 89.1 2.65 Sst 104 5710.2 0.020 10.5 0.1 83.7 0.00 83.8 2.65 Sst 105 5711.2 0.087 14.1 0.5 79.0 0.0 79.5 2.63 Sst 106 5712.2 0.044 13.4 0.9 85.1 0.0 86.0 2.61 Sst 107 5713.1 0.103 11.4 0.1 95.6 0.0 95.8 2.63 Sst 108 5714.0 0.034 11.3 1.2 90.9 0.0 92.1 2.62 Sst tan vfgr slty sh lams chrt incl mica m stn yel-gr: tan vfgr slty chrt incl mica m stn yel-grn flu tan vfgr slty mica m stn yel-grn flu tan vfgr slty mica m stn yel-grn flu tan vfgr slty chrt incl mica m stn yel-grn flu tan vfgr slty chrt incl m~ca m stn yel-grn flu tan vfgr slty chrt incl m~ca m stn yel-grn flu tan vfgr slty chrt incl m~ca m stn yelogrn flu tan vfgr slty chrt incl m~ca m stn yel-grn flu tan vfgr slty chrt incl m~ca m stn yel-grn flu tan vfgr slty chrt incl m~ca m stn yel-grn flu tan vfgr slty chrt incl m~ca m stn yel-grn flu tan vfgr slty chrt incl m~ca m stn yel-grn flu gry-lt tan vfgr vslty calc mica It sptd stn yelogrn gry-lt tan vfgr vslty calc mica It sptd stn yel-grn gry-lt tan vfgr vslty calc mica It sptd stn wh-no, gry-lt tan vfgr vslty calc mica It sptd stn wh-no, gry-lt tan vfgr vslty chrt incl calc mica It sptd str gry-lt tan vfgr vslty calc mica It sptd stn wh-no, gry-lt tan vfgr vslty calc mica It sptd stn wh-no, gry-lt tan vfgr vslty calc mica It sptd stn wh-no, gry-lt tan vfgr vslty carb strks mica It sptd stn n gry-lt tan vfgr vslty carb strks mica It sptd stn n gry-lt tan vfgr vslty sh. lams carb strks It sptd st, gry-lt tan vfgr vslty sh lams It sptd stn wh-no vi~ Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Stad 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Dean Starl 13-Mar-00 Convential Core Analysis Results Page 5 5/24/00 ARCO ALASKA, INC. Meltwater North #1 CL File No. ' 57111- 00048 PRELIMINARY CORE ANALYSIS RESULTS Samples were not fully cleaned at this time 109 5715.2 0.253 14.7 8.3 60.2 0.1 68.5 2.66 110 5716.1 0.674 13.2 3.0 70.5 0.0 73.5 2.62 111 5717.4 0.097 15.2 1.8 76.0 0.0 77.8 2.63 112 5718.2 0.006 7.1 5.0 82.2 0.1 87.2 2.67 113 5719.1 0.006 9.3 2.4 90.8 0.0 93.2 2.70 114 5720.1 0.895 13.3 0.6 87.1 0.0 87.7 2.62 115 5721.2 0.004 11.7 1.4 82.0 0.0 83.4 2.59 116 5725.8 0.000 6.0 0.0 77.1 0.0 77.1 2.67 Sst tan vfgr slty carb incl m stn yel-grn flu Dean Starl 13-Mar-00 Sst gry-lt tan vfgr vslty sh lam carb strks It strk stn Dean Starl 13-Mar-O0 Sst It tan-gry vfgr vslty carb mica It sptd stn wh-no Dean Starl 13-Mar-00 Sst gry-lt tan vfgr vslty carb incl calc mica It sptd st Dean Starl 13-Mar-00 Sst gry-lt tan vfgr vslty calc mica It sptd stn wh-no, Dean Starl 13-Maro00 Sst gry-lt tan vfgr vslty sh lam carb It strk stn wh-n¢ Dean Starl 13-Mar-00 Sst gry-lt tan vfgr vslty carb incl It sptd stn wh-no v Dean Starl 13-Mar-00 Sst gry vfgr vslty no stn no flu Dean Starl 13-Mar-00 Convential Core Analysis Results Page 6 5/24/00 !! DRILLING TIME AND MUD WEIGHT CURVE ............ Mud Weight i "* Meltwater North #1 ........ ..... 10.8 0 16 set@lO8 ......... ~ ........~ .......... - ..... , ..... , .............. , ........ · ...... - ..... - ............................. I ..... ' -" " ..................... "'!~ .... : ..... i ....... ! i'-'i '-- '--. , , . i '- lo.6 i ii lj:b;ili"~'~_,i: ;:'H;ie i ! .... .; ......: . . ;. ; ': "' , _ _! i' ' , ' ~ ' ' ~ ' ' - -'-, ........ ~ ...... I ' ' : ' : .... ' i .... ;" : ' , ............... 10.4 1000 'I ............. i .......................... : ............ ' ....., ' , ' ' , , I , ' ' ' ' ,- ' i . . , ' ' '_ .. ;. _[ . , -. , I ..... ; t .......... ~ : : i:.., . : 10.2 i .... i. : i- i : .... i i ...... i...: :- !-- :--: : .... : - ' 'i : ': ' I .... : · : · ' .... : ; ; ; ......... ' .... ;- . ~ooo i;;::; .... i ...... i-' ...... !-:_:.:::.-:-.:. !..::_:.:!-.-:_: I:.:.::---e "!--- ,, ........ I ......... i" i ... i : i ..... I . ! ,. i ~o ~i~iiiii :_!'.'i..!i 'i"-~zs"s"t~~!'":-' ': : ..... ..... r-'~" ': : : : : : ...:. ..:: -~-~,-;:';~':::~"-'~'~-::'-":-:~'-"~ , , [ ......... ...... :.__; .........~.--: ..... :--~: ......... : .... ~--':--' : : : : : ..... : ..... ~ .... :..,: . :...: ~.4 [.['5;~i-~i~:~'~;- -'-~'--~"'~ ...... : .......... : .... ~"-~_ ................. .... : ~ : : ~ _: ..... : -: .... : ..... : .... ~ .... :-~-i .... ~..': .... -': .... :' '~:'-: ' ,~.~.. , 4000 -~___~ .... ~ .... I .... :. -:.--: --: --I .... : .... : :--~ .... : ............... ~' ' ': ':" ' 5000 ' : ...... '- ................... : ....... ~ , , - ' - - " ' '- ' ~' ' ~' ~:~: 8.8 , ' I ' ~- ~' ~ "~."' ~ ,, ._ "__~.~ ........... ~.__i ....... ~.,.., : .~ .i .... ~ :~ - - :. ~ '.. ' ..... ~ .... ~- ,¢ ........... · ~ ..... ~ , , , , ~ ,' , . ; , ,, ' .... ~.-~-1/2" ~ :Loo Hole RunT,&Completel ' . :. ~ ...... - ' "' ' ' ..... . 8.6 ~ ~ · ' , ~v~ ~ v ~ ] ~ ~ . . ~ , ~ , ~ ' · ' - - ' ,-- ' ..... ~ ....... I ................. 5---- , ..... :~- ' ' ' ~ i ' , · , '... ' .. ' · , .... Hole ' 6000 ...... ~ ', ~ ..... ','-, ~. ......... . ~ ~~~~-~.-~_ re : : : : .... I_ _:.l-'~ei~a~'Rigto~WU~2A Sidetrack~ .... '. ' .:... : ---; ....:---; .... ~ ............................... ,--'-:- "I-"-. :''': .... ;; ........... ~'-"--~ ......... r .... · ........ ,-:"-" ...... 7'~' ~' ' ' : ~ ..... : ........... :__: .... : . .: .i .... ~ . ....... : ..: ._.:..-~. -: - ~ ' 8.4 "'"'"" : I ' ..... ..... ---~ .....:---4 ', ........~ ..... ', : _: .... ~ ................ ~ ............... : ........ : - , ' r' ~, ' ' : i , : : · g.2 ...... ' ' ' I ~ · ' ' ~ I ~ - .... ~ ............. ' ' ' 7000 .......................... ' ...... : ............ : .... : ........ "~' .............. ~ ............................ 0 {'~ 5 10 15 20 25 30 35 TIME TO DRILL (DAYS) Rig Release est ~ 0000 hrs 318100 Spud 1330 hrs 2~23~00 3/7/00 TRANSMITTAL CONFIDENTIAL DATA was GOllY. ~orflrlllSSiOtl FROM: Sandra D. Lernke, ATO1354 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Ak. Oil & Gas Conservation Comm. ATTN: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99510 DATE: 05/30/2000 Transmitted herewith is the following: Meltwater North 1 .2 o'e,. o \ ~ Reproducible log films + 1Bluelines each: Schlumberger CIBP & tubing puncher P&A procedure log CC: Mark McDermott Approved for transmittal by: Mark Myers Receipt: ~~/~~t%x Return receipt to: Pl~i~ips Alaska, Inc. ATTN: S. Lemke, ATO-1354 700 G. Street Anchorage, AK 99501 'CEIVED Date: II Ilkl f~ ~1 ~lfl/lfl ~aska 0ii & Gas Cons. ~mmi~ion Prepared by: Sa~~E~mke Phillips Alaska IT G~science Group PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Paul Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 May 17, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Meltwater North #1 (Permit 200-012/300-052) Completion Report Dear Mr. Christenson: Phillips Alaska, Inc., as operator of the Meltwater North #1 exploration well, submits the enclosed "Well Completion Report" (form 407). Other attachments to the completion report include the Jdirectional survey,'geologic tOps, report of dailY well operations, memo for Abnormal Pressure, time and mud weight chart, core description and asrbuilt. We will send under separate cover the logs, the mud logs and production data. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. If you have any questions regarding this matter, please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely, Paul Mazzolini Exploration Drilling Team Leader PAI Drilling PAMITJB/skad f'" STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r-] Gas E] Suspended [-'] Abandoned r~ Service["] 2. Name of Operator ~u~;CMI~3~I~i~.~ r. 7. Permit Number Phillips Alaska, Inc. ~~ i 200-012 / 300-52 3. Address 100360, Anchorage, [~r ~~ i 8. APl Number P. O. Box AK 99510-0360 ~~. 50-103-20326-00 4. Location of well at surface 9. Unit or Lease Name 2359' FNL, 1798' FWL, Sec. 20, T8N, R7E, UM (ASP: 443730, 5862240) I ,~',L;i'..i?L[-!:i0!~; i Exploration ! / i~'E ~ .- At Top Producing Interval14,,/~' ..~ ,?~ .~ 10. Well Number At Total Depth iV~z~'-1~ !!. 11. Field and Pool 2334' FNL, 1825' FWL, Sec. 20, TSN, RTE, UM (ASP: 443756.7, 5862264.6)~i 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Exploration RKB 28 feet] ADL 389058 ALK 4998 12. Date Spudded 13. Date T.D. Reached 14. Date O~o~_.p., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Oompletions February 23, 2000 March 2, 2000 4/,;W/2000'""' (P&A'd) -~I N/A feet MSL 1 '17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness 0~'Permafrost 6122' MD/6121'TVD 6025' MD/6024'TVD YES [~] No D] N/A feetMD 1451' 122. Type Electric or Other Logs Run I EWR/GR, PEX/CMR/NGT, DSI/FMI, RFT, MSCT 33. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# L-80 Surface 108' 20" 2oo cf 9.625" 53.5# L-80 Surface 2271' 12.25" 493 sx AS III Lite & 280 sx Class G ,, , 7" 29# L-80 Surface 6107' 8.5" 65 sx Class G & 189 sx Class G Top plug to surface. ,, 24. Perforations open to Production (MD + TVD of Top and BOttom and 25. TUBING RECORD interval, size and number) SIZE !DEPTH SET (MD) PACKER SET (MD) 3.5" 5337' 5224' , 5650'-5670' MD 5649'-5669' TVD 5 spf .... 5630'-5650' MD 5629'-5649' TVD 5 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5620'-5630' MD 5619'-5629' TVD 5 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Frac: 285000# 16/20 proppant behind pipe and 0 RIG IN A L 7ttu0e:zP::P2:at:~Aff;: wellbore 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) To be sent under separate cover ... Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure CalcUlated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 24-Hour Rate > 28. CORE DATA , , Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. Refer to attachments for core description and core analysis ,,, Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Geologic Markers: Refer to attachment GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravily. GOR, and time of each phase. Well P&A'd 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Geologic Tops, Abnormal Pressure memo, time and mud weight chart, as-built 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Tom Brassfleld 265-6377 ,Signed P~ )/~~ Title Ex_Dloration/Tarn Team Leader Date Paul Mazzolini INSTRUCTIONS Prepared by Sharon Al/sup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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 cementing and the location of the cementing tool. Item 27: Shut-in, Other-explain. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~ KI(MWN-01(W4-6)) WELL JOB SCOPE JOB NUMBER ' " MWN-01 DRILLING SUPPORT-CAPITAL 0316000742.1 DATE DAILY WORK UNIT NUMBER 04/26/00 P&A SET TOP PLUG DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 18 YES YES DS-ZIERKE ODELL FIELD AFC# CC# Signed ESTIMATE AX9918 FDUNDV4MI Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY I ANNULUS. GOOD CEMENT TO SURFACE. PRESSURE TESTED ClBP TO 2000 PSI, GOOD TEST. CIRCULATED CEMENT FOR TOP PLUG DOWN TUBING AND UP TBG X 7" TIME LOG ENTRY 14:00 MIRU DS CEMENTING EQUIP. 15:00 PRIME UP CEMENT VAN W/FRESH WATER. HOLD SAFETY MEETING (3 DS, 1 APC, 1 ARCO) MUSTER AREA, JOB DISCUSSION. 15:15 PT LINES TO 2000 PSI, BEGIN PUMPING FRESH WATER DOWN TBG TAKING RETURNS OFF OF ANNULUS TO LOAD WELL. AT 25 BBLS PUMPED, STARTED GETTING FLUID RETURNS TO THE TANK. PUMPED ADDITIONAL 2 BBLS FRESH WATER. 15:25 PT ABOVE CIBP AT 320' TO 2000 PSI. ALSO PRESSURE TESTING ANNULUS, AS TUBING IS PERFORATED ABOVE CIBP. STARTING PT PRESSURE = 2135 PSI. 15:35 PRESSURE = 2088 PSI. 15:45 PRESSURE = 2074 PSI. 15:55 PRESSURE = 2069 PSI, GOOD TEST. 16:00 PUMP 2 BBLS OF FRESH WATER W/RED DYE AS INDICATOR OF CEMENT FRONT. PUMPING DOWN TUBING, TAKING RETURNS FROM ANNULUS TO THE TANK. BATCH UP CEMENT, 10.2 BBLS (61.5 SACKS) 15.7 PPG ARCTIC SET 1 CEMENT. 16:08 START PUMPING CEMENT DOWN TUBING AT 2 BPM, TAKING RETURNS TO TANK. AT 10 BBLS PUMPED, SAW DILUTED CEMENT RETURNS AT TANK. PUMPED 1ST BATCH (10.2 BBLS) SAW ONLY DILUTED CEMENT AT TANK. BATCHED UP 2 MORE BBLS, PUMPED AT 2 BPM. HAD STRONG CEMENT RETURNS AT TANK. CEMENT IN PLACE AT 16:18. CASING AND MASTER VALVES SHUT-IN. 16:20 VAC OUT LINES AND TREE. CYCLED SWAB, WING, COMPANION VALVES WHILE VAC'ING OUT TREE TO REMOVE AS MUCH CEMENT RESIDUE AS POSSIBLE. 16:30 WASH UP CEMENT VAN TUB, FLUSH RINSE WATER AND 20 BBLS FRESH WATER THROUGH HARDLINE TO TANK TO CLEAN LINES AND CHOKE. BLOW DOWN LINES TO TANK FOR FREEZE PROTECTION. 17:00 DS RIGGED DOWN, WELL SECURE. ARCO Alaska, Inc. KUPARUK RIVER UNIT ~, WELL SERVICE REPORT ~' KI(MWN-01(W4-6)) WELL JOB SCOPE JOB NUMBER ' " MWNo01 DRILLING SUPPORT-CAPITAL 0316000742.1 DATE DAILY WORK UNIT NUMBER 04/20/00 P&A RESQUEEZE OF PERFS DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 15 NOI NO FERGUSON FIELD AFC# CC# Signed ESTIMATE AX9918 FDUNDV4MI Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 500 PSI 500 PSIJ 0 PSII 0 PSI DALLY SUMMARY RU DOWELL CEMENTERS FOR RESQUEEZE. PUMP 20 BBLS CLASS G WITH 600 #'S AGGREGATE FOLLOWED BY 24 BBLS CLASS G. DISPLACE WITH 9.3 BRINE AND DIESEL CAP. PRESSURE OUT WITH DIESEL CAP AT 3000 PSI. ESTIMATE CEMENT TOP AT 2400'. SQUEEZE APPROXIMATELY 8 BBLS WITH AGGREGATE INTO PERFS.[Cement-Poly Squeeze] TIME LOG ENTRY 08:00 ARRIVE LOCATION, DOWELL CEMENTERS RU HARDLINE 09:00 PUMP 2 BBLS FW AND PT LINES TO 2200 PSI. 09:20 LEAD 3 ADD'L BBLS FW AND FOLLOW WITH 20 BBLS CLASS G WITH 600#'S AGGREGATE. PUMPING 1 3/4 BPM AND 1050 PSI. 09:35 8 BBLS SLURRY AWAY, 1.8 BPM AND 500 PSI. 09:45 25 BBLS SLURRY AWAY, 1.5 BPM 09:50 TOTAL SLURRY AWAY 44 BBLS, FOLLOW WITH 5 BBLS FW, FOLLOWED WITH 10 BBLS 9.3 BRINE, FOLLOWED WITH 5 BBLS DIESEL 10:05 GET 5 BBLS FW AWAY AND 8 BBLS BRINE AWAY, WHP COMING UP TO 1500 PSI, SWITCH TO DIESEL, 1 BBL DIESEL AWAY, 1/4 BPM, 1780 PSI WHP 10:15 DISPLACE WITH A TOTAL OF 5 BBLS DIESEL AT LESS THAN 1/4 BPM, AND PRESSURE OUT AT 3000 PSI 11:00 WOC AND ATTEMPT TO PRESSURE UP ON TUBING, BREAK BACK TO 700 PSI, CONTINUE DISPLACING SLURRY WITH DIESEL, PRESSURE OUT AGAIN AT 3000 PSI AFTER ADD'L 2.5 BBLS. SD TO MONITOR PRESSURE. 11:30 PRESSURE HOLDING STEADY AT 2900 PSI AFTER 30 MINUTES. 11:45 FINAL DISPLACEMENT 21 BBLS WITH 8 BBL DIESEL CAP. ESTIMATED TOC AT 2400'. 8 BBLS AGGREGATE PLACED BEHIND PIPE 12:00 RDMO Date: 03/31/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:MELTWATER NORTH #1 RIG:DOYON 141 WI: 0% SECURITY:0 STATE:ALASKA API NI/MBER: 50-103-20326-00 COUNTY: NORTH SLOPE WEST FIELD: WILDCAT BLOCK: SPUD: 2/23/00 START COMP: FINAL: 02/21/00 (D1) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 110/0 ( 110) RIG ON STANDBY W/ FULL CREWS - LOCATION NOT READY SUPV:DEARL W. GLADDEN Rig on standby w/full crews, location not ready. 02/22/00 (D2) TD/TVD: 108/0 SUPV:MIKE WHITELEY MW: 0.0 VISC: 0 PV/YP: 0/ 0 ( 0) RIGGING UP APIWL: 0.0 Rig on stand by, waiting for conductor pipe to be set on MWN#1. Move camp and rig modules to MWN#i. 02/23/00 (D3) TD/TVD: 140/140 SUPV:MIKE WHITELEY MW: 10.0 VISC: 172 PV/YP: 66/42 ( 32) DRILLING AHEAD AT 512' APIWL: 9.6 Moved rig'from MWN#2 to MWN#1. NU diverter. Accepted rig ~ 1330 hrs. Function test diverter. Pre-spud safety meeting. Clean out conductor. Drill to 140' with plugged jets. Pulled up, broke bit, cleaned gravel out of bit. 02/24/00 (D4) MW: 10.2 VISC: 70 PV/YP: 27/27 APIWL: 5.0 TD/TVD: 1832/1831 (1692) TRIP FOR BIT AT 1,845' -RIH WITH NEW BIT@ 0600 HRS SUPV:MIKE WHITELEY Pre-spud meeting. Drill from 140' to 1832' 02/25/00 (D5) MW: 10.2 VISC: 70 PV/YP: 31/33 TD/TVD: 2281/2280 (449) CEMENTING 9 5/8" CSG SUPV:MIKE WHITELEY APIWL: 5.4 Drill from 1832' to 1845' POOH for bit, hole in good shape. RIH. No problems. Drill from 1845' to 2281'. Circ for samples, pumped sweep around. Observe well. Short tripped to 900'. No problems. Circ and condition mud and hole to run 9-5/8" casing. POOH. PJSM. Run 9-5/8" casing. PJSM. 02/26/00 (D6) TD/TVD: 2281/2280 ( SUPV:MIKE WHITELEY MW: 9.3 VISC: 33 PV/YP: 7/ 4 0) DISPLACE HOLE WITH 9.0 PPG LSND MUD APIWL: 9.6 Finished running 9-5/8" casing. PJSM. Pumped LCM pill. Pump cement. Plug bumped. Floats held. ND diverter. NU head and test to 1000 psi. NU BOPs. Test BOPs to 250/5000 psi. Date: 03/31/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 02/27/00 (D7) MW: 9.2 VISC: 48 PV/YP: 16/18 TD/TVD: 4203/4202 (1922) DRILLING AHEAD AT 4810' SUPV:MIKE WHITELEY APIWL: 6.5 Kick drill and kill drill. Test 9-5/8" casing. Drill out plugs, good cement, floats, and 20' new formation to 2301' Circ and condition mud to 9.2 ppg flor LOT. Performed FIT EMW=15.9 ppg. Displaced hole with LSND mud. Drill from 2301' to 3800'. Short trip to shoe at 2271'. Slight swabbing. Drill from 3800' to 4203' 02/28/00 (D8) MW: 9.5 VISC: 44 PV/YP: 12/13 TD/TVD: 5410/5409 (1207) DRILLING AHEAD AT 5596 SUPV:MIKE WHITELEY APIWL: 4.6 Safety meeting, kick drill. Drill 8.5" hole from 4203' to 5410'. Pump sweep around, circ clean. OBserve well. Small flow. Circ bttms up, no loss or gain in pits. Observe well, stable. Start POOH. Slight swabbing. Pulled to shoe, swabbing in casing, observe well, slight flow. RIH, no problems. Circ hole clean. No gas. Observe well, Pump slug. 02/29/00 (D9) MW: 9.3 VISC: 43 PV/YP: 11/16 APIWL: 4.4 TD/TVD: 5727/5726 ( 317) M.U. CORE BARRELS FOR RUN#2 SUPV:MIKE WHITELEY Drill from 5410' to core point at 5607'. CBU. Flowcheck, POOH for core barrel. Kick drill. PJSM. RIH with coring assembly. RIH to 5580'. Ream to bottom from 5580' to 5607' Cut core #1. CBUo POOH w/core barrels. 03/01/00 (D10) MW: 9.4 VISC: 44 PV/YP: 9/16 APIWL: 4.4 TD/TVD: 5757/5756 ( 30) TD'D 8.5" HOLE AT 6,122' - MAKING WIPER TRIP AT 0600 H SUPV:MIKE WHITELEY Finish POOH slow with core barrel. PJSM. Lay down 12' core, full recovery. RIH, taking weight at 5687'. Ream from 5687' - 5727'. Cut core #2 from 5727' to 5757'. CBU. POOH slow with core barrels. RIH. MAD pass with LWDs from 5607' to 5688' 03/02/00 (Dll) MW: 9.3 VISC: 48 PV/YP: 12/20 TD/TVD: 6122/6121 ( 365) LOGGING -RUN#2 - DIPOLE SONIC / DIPMETER SUPV:MIKE WHITELEY APIWL: 4.2 ~MAD PASS LOG FROM 5688' TO 5727'. DRILL FROM 5727' TO 6122' PUMP SWEEP AROUND. CIRC CLEAN. WIPER TRIP TO SHOE AT 2271'. HAD 20K-30K DRAG FROM 5900' TO 5500'. RIH TO 5506' WASH AND REAM FROM 5506' TO 5947'. PUMP SWEEP AROUND. CIRC HOLE CLEAN. POOH FOR LOGS. PJSM. RIH WITH LOGGING TOOLS. RUN #l-PLATFORM EXPRESS/CMR/NGT FROM 6098' TO 2271'. TIGHT SPOTS AT 5780' AND 5500' Date: 03/31/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 03/03/00 (D12) TD/TVD: 6122/6121 ( SUPV:MIKE WHITELEY MW: 9.4 VISC: 48 PV/YP: 9/17 0) LOGGING - VEOCITY SURVEY APIWL: 4.6 Run #2 dipole sonic/dipmeter. Logged from 6098' to 2271' POOH. Run #3, RFT's. POOH. Run #4, rotary sidewall core. Cut 25 cores from 5603' to 5541'. POOH. Run #5, Rotary sidewall cores. Cut 25 cores from 5537' to 5423' 03/04/00 (D13) MW: 9.4 VISC: 45 PV/YP: 11/19 APIWL: 4.3 TD/TVD: 6122/6121 ( 0) LD DRILL PIPE SUPV:MIKE WHITELEY Finished Run #5, rotary sidewall cores from 5537' to 5423', ~ecovered 23 cores. Run #6, seismic velocity survey. H2S .drill. Test BOPs to 250/5000 psi. OK. Start washing and reaming to bottom, at 6090' 03/05/00 (D14) TD/TVD: 6122/6121 ( SUPV:MIKE WHITELEY MW: 9.3 VISC: 44 PV/YP: 9/12 0) PREPARE TO PICK UP TUBING APIWL: 4.4 Washed to bottom at 6122'. Circ and condition mud and hole for 7" casing. Pump sweep around and circ clean. POOH. Set test plug. Tested door seals to 250/2500 psi. PJSM. Run 7" casing. Wash and spud casing to bottom at 6107'. Circ and condition mud and hole for cement job, reciprocate pipe/ full returns. PJSM. 03/06/00 (D15) TD/TVD: 6122/6121 ( SUPV:MIKE WHITELEY MW: 9.3 VISC: 28 PV/YP: 0/ 0 0) PERFORATING APIWL: 0.0 Dowell cemented 7" casing. Displaced with seawater. Reciprocated pipe, full returns. Plug bumped, floats held. Install 7" pack-off. Freeze protected annulus. RIH with 3.5" tubing. Wash down and taagged bottom, PBTD 6033' Displace well with clean seawater. Dipslace hole with brine. POOH with tubing. P/U USIT log. 03/07/00 (D16) MW: 9.3 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 6033/6121 ( 0) SLICK LINE RE-INSTALLING DV IN TOP GLM AFTER PUMPING F SUPV:DEARL W. GLADDEN Run USIT log. TOH. POS & #1 perf assy, lub failed to "test". RD Lub, change out conn. "O-ring", R/U lub. test to 1000 psi, OK. Perf Run #1 - Perf from 5650' to 5670'. Perf Run #2, Perf from 5630' to 5650'. Perf Run #3, Perf from 5620' to 5630'. Run Pkr assy, set pkr ~ 5224'. Monitor well fluid while TIH, No loss. TOH. PJSM. N/D BOPs. N/U tree and test 250/5000 psi, Ok. 03/08/00 (D17) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 6033/6121 ( 0) SUPV:DEARL W. GLADDEN PJSM. Test tree to 5000 psi, OK. Retrieve Baker ball & rod assembly. PJSM. Secure tree & cellar area. released ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~ KI(MWI(W4-6)) WELL JOB SCOPE JOB NUME~ER ' " MW1 DRILLING SUPPORT-CAPITAL 0307001435.15 DATE DAILY WORK UNIT NUMBER 03/18/00 FRACTURING DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I YESI YES DS-GALLEGOS FERG USON FIELD AFC# CC# Signed ESTIMATE AX9917 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann , Initial Outer Ann , Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 10 PSI 0 PSI DALLY SUMMARY RU DOWELL PUMP EQUIPMENT. PUMP BREAKDOWN FOLLOWED BY DATAFRAC. PUMP FRAC TREATMENT AND PLACE 285,000#'S 16/20 PROPPANT BEHIND PIPE AT MAX CONC. OF 14 PPA. FLUSHED 15 BBLS SHORT OF DISPLACEMENT AND LEFT 7300#'S PROPPANT IN WELLBORE.[Frac-Refrac] TIME LOG ENTRY 08:30 ARRIVE LOCATION AND RU DOWELL PUMP EQUIPMENT. 12:00 SAFETY MEETING 12:15 ATTEMPT TO PT LINES. LEAK AT ZERK FITTING ON MISSLE VALVE. REPAIR 12:30 PT LINES TO 8900 PSI 12:45 COMPLETE BREAKDOWN WITH 20 # GEL. NO XS PERF FRICTION. ISIP- 722 PSI, FG 0.58 12:55 START DATAFRAC 13:10 SD FOR DATAFRAC ANALYSIS. ISIP=806 PSI, PC-806 PSI, TC= 9 MIN, EFF-31%ADJUST PAD FROM 800 TO 900 BBLS. RUN 20 PPT REGAIN IN FRAC PAD. 14:00 START FRAC AT 30 BPM. FRAC TREATING VERY EASY AT 2500 PSI 15:47 EXTEND RAMP TO 14 PPA DUE TO LOW TREATING PRESSURES. POSSIBLY SEEING TSO. 16:00 14 PPA ON FORMATION AND START FLUSH, BEGIN SLOWING RATE FROM 30 BPM DOWN TO 10 BPM. STOP FLUSH 15 BBLS SHORT OF DISPLACEMENT TO MAINTAIN 14 PPA ON FORMATION. 16:30 PLACE 285,000 #'S BEHIND PIPE AT MAX CONC OF 14 PPA. TOTAL PROP PUMPED 292,300#'S, LEFT 7300 #'S IN TUBING. FREEZE PROTECT WITH DIESEL ON FLUSH TO ABOUT 1100 FT. 17:30 RD GEOLOGIC TOPS FORMATION Top W. Sak Base Prmfrost Base W. Sak C-80 (K-10) c-4o (K-S) Top Cairn Top Bermuda Mid Bermuda Base Bermuda C-35 (Absent) Top Albian TD MELTWATER NORTH #1 MEASURED DEPTH 1298 1451 2023 2500 3422 5403 5495 5638 5780 NP 5780 6122 CONFIDENTIAL SUBSEA DEPTH 1 OO5 1158 1730 2207 3129 5110 5202 5345 5487 NP 5487 5929 rla~m 1. BASIS OF HORIZONTAL AND VERTICAL CONTROL iS '"k.~, !:." , ~ · MONUMENTS 13-8-7 &: 22-8-7 PER LOUNSBURY ' -I' '. 4 ~ ~,~...~.. 2. COORDINATES SHOWN ARE ASP ZONE 4, NAD-27. ' ; ""'-x ~ ~,/" 4. ALL DISTANCES SHOWN ARE TRUE. ,, ..... ,, 5. ICE PAD ROTATION FROM GRID NORTH IS 20'. , .,, LOCAT[~ WITHIN PROTRACT[~ ! .?~. ,~%~..,, c. OU.D EL~V. = 2S3. e ~ ~/ SC~E: 1' 5 MILES SUR~YOR'S CER~FICA ~ REOtSTEREO aNO LtcENsEo TO PR~CTtCE L~ND SUR~YIN6 IN THE STATE OF ~L~SK~ ~ND T~T THIS PL~T REPRESENTS ~ SURVEY DONE BY DIRECT SUPERVISION ~NO T~T ~LL DI~NSIONS ~ND OTHER DETAILS ~RE CORRECT ~S & ~SSOCI~T~8, I~C. E~NEE~ P~NNE~ SURVEYO~ ~k MEL~A~R NORm ARO0 InD. EXPLORATORY ~ CONDUOTOR Subs)diory of Atlontic Richfiemd Compon~ AS-BUILT .... LK6elO318 2/23/ee CEA-MIXX-6el D318 Arco Alaska Inc. North Slope Alaska Alaska State Plane 4 Meltwater North Meltwater North #1 Surveyed: 23 February, 2000 SURVEY REPORT 15 March, 2000 Your Reft API-501032032600 Surface Coordinates: 5862239.80 N, 443729.91 E (70° 02' 03.3897" N, Kelly Bushing: 292.70ft above Mean Sea Level 150° 26' 59.6729" W) Survey Ref: svy9131 Arco Alaska Inc. North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Depth (ft) Survey Report for Meltwater North #1 Your Ref: API-501032032600 Surveyed: 23 February, 2000 0.00 0.000 0,000 -292,70 0.00 108.00 0.000 0,000 -184.70 108.00 154.95 0,370 346.980 -137.75 154.95 385.27 0.370 356.410 92.56 385.26 596.80 1.260 8.270 304.07 596.77 773.77 1.420 13.570 480.99 773.69 1022.76 2.550 18.950 729.83 1022.53 1080.81 2.850 23.710 787.82 1080.52 1111.36 2.740 21.580 818.33 1111.03 1199.07 2.570 18.790 905,94 1198.64 1328.63 1.420 11.780 1035.42 1328.12 1452.99 1.060 333.980 1159.76 1452.46 1576.38 0,540 74.950 1283.14 1575.84 1794.01 0.610 69.830 1500.76 1793.46 2209.19 0.870 118.270 1915.91 2208.61 2305.93 0.770 120,150 2012.64 2305.34 2770.83 0.810 115.450 2477.49 2770.19 3238,67 0.650 99.200 2945.30 3238.00 3726.68 0.970 67,630 3433.26 3725.96 4194,65 0.070 172.590 3901.21 4193.91 4661.48 0.250 229.120 4368.03 4660.73 5124.74 0.670 252.800 4831.28 5123.98 5373.53 0.800 260,940 5080.05 5372.75 5576.75 0.250 230.850 5283.26 5575,96 5674.24 0.170 208.990 5380.75 5673.45 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5862239.80 N 443729.91 E 0.00 N 0.00 E 5862239.80 N 443729.91 E 0.15 N 0.03W 5862239.95 N 443729.88 E 1.61N 0.25W 5862241.42 N 443729.67 E 4.60 N 0.04 E 5862244.40 N 443729.99 E 8.65 N 0.84 E 5862248.45 N 443730.81 E 16.89 N 3.36 E 5862256.67 N 443733.40 E 19.44 N 4.36 E 5862259.20 N 443734.41 E 20.81N 4.93 E 5862260.57 N 443735.00 E 24.62 N 6.34 E 5862264.37 N 443736.43 E 28.94 N 7.60 E 5862268.69 N 443737.73 E 31.48 N 7.41 E 5862271.23 N 443737.55 E 32.66 N 7.47 E 5862272.41 N 443737.62 E 33.33 N 9.55 E 5862273.06 N 443739.71E 32,60 N 14.40 E 5862272.29 N 443744.55 E 31.92 N 15.61E 5862271.61N 443745.76 E 28.94 N 21.28 E 5862268.58 N 443751.40 E 27.10 N 26.88 E 5862266.70 N 443756.99 E 28.23 N 33.44E 5862267.78 N · 443763.55 E 29.45 N 37.14 E 5862268.97 N 443767.26 E 28.50 N 36.40 E 5862268.03 N 443766.52 E 27.04 N 33.05 E 5862266.59 N 443763.16 E 26.33 N 29.95 E 5862265.91N 443760.05 E 25.83 N 28.20 E 5862265.42 N 443758.30 E 25.57 N 27.97 E 5862265.16 N 443758.07 E Dogleg Rate (°/100ft) 0.000 0.788 0.026 0.426 0.114 0.459 0.645 0.495 0.243 0,906 0.702 1.036 0.040 0.157 0.107 0.016 0.056 0.110 0.212 0.047 0.098 0.067 0.294 0.115 Alaska State Plane 4 Meltwater North Vertical Section (ft) Comment 0.0o 0.00 0.15 1.61 4.60 8.65 16,89 19.44 2o.81 24.62 28,94 31.48 32.66 33.33 32.60 31.92 28.94 27.1o 28.23 29.45 28.50 27,04 26.33 25.83 25.57 Cont~ued... 15 March, 2000 - 14:21 - 2 - DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for Meltwater North #1 Your Ref: API-501032032600 Surveyed: 23 February, 2000 Arco Alaska Inc. North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim, Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 6052.46 0.250 263.810 5758.97 6051.67 24.99 N 26.87 E 5862264.59 N 443756.97 E 6122.00 0.250 263.810 5828.51 6121.21 24.96 N 26.57 E 5862264.56 N 443756.67 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.995° (23-Feb-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6122.00ft., The Bottom Hole Displacement is 36.46ft., in the Direction of 46.796° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 6122.00 6121.21 24.96 N 26.57 E Comment Projected Survey Dogleg Rate (°/100ft) 0.054 0.000 Alaska State Plane 4 Meltwater North Vertical Section (ft) Comment 24.99 24.96 Projected Survey 15 March, 2000 - 14:21 - 3 - DrillQuest 1.05.04e ARCO ALASKA INC. 700 G STREET ANCHORAGE, AK 99510 907-276-1215 To: AOGCC 3001 Porcupine Dr. Anchorage, AK 99501 Attn: Lori Taylor Date: April 26, 2000 From: Mark Myers ATO 1446 ARCO Alaska Inc. P.O.Box 100360 Anchorage, Alaska 99510-0360 ..-O [~ Enclosed is the final data for Meltwater North gl (AP1 # 501032032600) as listed below. 1 pre-fold color print and sepia: Epoch mudlog 2" 110 -6122' Upon receipt, please sign and return to: Thank You Catherine Worley ATO 1355 P.O. Box 100360 Anchorage, AK 99510. Received by:' ~~'~ RECEIVED :IttAY 04 Date: Alaska 0il & Gas Cons. Commission Anchorage ARCO ALASKA INC. 700 G STREET ANCHORAGE, AK 99510 907-276-1215 To: AOGCC 3001 Porcupine Dr. Anchorage, AK 99501 Attn: Lori Taylor Date: April 27, 2000 From: Mark Myers ATO 1446 ARCO Alaska Inc. P.O.Box 100360 Anchorage, Alaska 99510-0360 Enclosed is the final data for Meltwater North #1 (API# 501032032600) as listed below. 1 blUeline and sepia each: Sperry-Sun MWD ROP/DGR/EWR Final MD 2" 5" Sperry-Sun MWD ROP/DGR/EWR Final TVD 2" 5" 02MAR00 02MAR00 1 CD'Rom: Sperry-Sun MWD Well DATA (DGR/EWR/ROP) 86-6066' 02MAR00 1 paper copy: Sperry-Sun LIS Scan Listing Upon receipt, please sign and return to: Catherine WorleYATo 1355 P.O. Box 100360 Anchorage, AK 99510. Thank You Received by: L,..) RECEIVED U:AY 04 000 Date: Alaska 0ii & Gas Cons. Commission Anchorage Sperry-Sun Drillin9 Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Mar 24 22:43:29 2000 Reel Header Service name ............. LISTPE Date ..................... 00/03/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writin9 Library. Scientific Technical Services Fape Header Service name ............. LISTPE Date ..................... 00/03/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writin9 Library. Scientific Technical Services Physical EOF ~omment Record FAPE HEADER Exploration 4WD/MAD LOGS YELL NAME: %PI NUMBER: )PERATOR: ~OGGING COMPANY: FAPE CREATION DATE: IOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 A/<-MM-90251 J. MARTIN M. WHITELY Meltwater North #1 501032032600 ARCO klaska, Inc. Sperry Sun 24-MAR-00 MWD RUN 3 AK-MM-90251 J. SACK M. WHITELY MWD RUN 2 AK-MM-90251 R. MCNEILL M. WHITELY' RECEIVED Alaska Oil & Gas Cons. Commission Anchorage JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: ~URFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 4 AK-MM-90251 R. MCNEILL M. WHITELY MWD RUN 5 AK-MM-90251 R. MCNEILL M. WHITELY 2O 8N 7E FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: ~ELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 2359 1798 .00 294.00 266.00 ~EMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 16.000 110.0 8.500 9.625 2282.0 8.500 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISED NOTED. 2. MWD RUNS 1-5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. DIGITAL DATA IS DEPTH CORRECTED TO THE PDC GR LOG OF 03/02/00 (SWS AIT GR) WITH KBE OF 294' A.M.S.L. LOG HEADER DATA RETAINS ORIGINAL DRILLER' S DEPTH REFERENCES. 4. MWD RUNS 1-5 REPRESENT WELL MELTWATER NORTH #1 WITH API#: 50-103-20326-00. THIS WELL REACHED A TOTAL DEPTH OF 6122'MD, 6121'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORmaTION EXPOSURE TIME. $ 'ile Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 86.5 6066.5 FET 94.5 6077.0 RPD 94.5 6077.0 RPM 94.5 6077.0 RPS 94.5 6077.0 RPX 94.5 6077.0 ROP 136.0 6122.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 86.5 92.0 2194.5 2200.0 2211.0 2216.5 2268.0 2271.0 2270.0 2272.5 2276.0 2278.5 2277.5 2280.0 2289.5 2292.0 2292.5 2295.0 2296.5 2300.0 2304.5 2307.5 2311.0 2313.5 2314.5 2317.0 2316.0 2318.5 2317.0 2320.0 2323.5 2327.5 2329.5 2335.5 2341.0 2344.0 2344.5 2347.5 2351.5 2356.0 2356.5 2359.5 2358.5 2362.0 2379.5 2382.0 2398.5 2402.0 2409.0 2411.5 2424.5 2427.0 2430.5 2434.0 2433.5 2437.0 2439.5 2443.0 2454.0 2457.0 2470.0 2473.0 2476.0 2478.0 2489.5 2492.0 2492.5 2495.5 2496.5 2498.5 EQUIVALENT UNSHIFTED DEPTH 2509 2545 2547 2550 2559 2580 2585 2596 2600 2604 2630 2646 2655 2661 2663 2666 2672 2674 2675 2687 2688 2700 2702 2709 2711 2714 2716 2717 2721 2726 2727 2732 2736 2739 2744 2748 2754 2760 2763 2766 2769 2776 2783 2785 2789 2794 2809 2819 2825 2827 2829 2834 2842 2845 2849 2853 2859 .5 .0 .5 .0 .0 .0 .5 .5 .5 .5 .5 .0 .5 .0 .5 .5 .5 .5 .5 .5 .5 .0 .5 .0 .5 .5 .0 .0 .0 .0 .5 .5 .5 .5 .5 .5 .5 .0 .0 .5 .0 .5 .0 .5 .5 .0 .5 .0 .5 .5 .0 .0 .0 .0 .0 .0 .0 2513.0 2547.5 2550.0 2552.5 2561.5 2582.5 2588.5 2598.5 2603.5 2607.0 2633.0 2649.0 2659.0 2664.5 2667.0 2670.0 2675.0 2677.0 2679.5 2690.5 2691.5 2703.0 2705.5 2712.0 2714.5 2717.5 2719.0 2721.0 2725.0 2729.0 2730.5 2735.5 2739.5 2742.5 2747.5 2751.5 2758.0 2763.0 2766.0 2769.5 2772.0 2779.5 2786.0 2789.5 2792.5 2797.0 2812.5 2821.5 2828.5 2830.5 2831.5 2837.0 2845.0 2848.0 2852.5 2856.0 2862.5 2867.5 2870.0 2871.0 2873.5 2873.0 2875.5 2875.0 2878.0 2878.0 2880.5 2879.5 2882.0 2883.0 2885.5 2886.0 2888.5 2890.0 2893.0 2897.0 2899.5 2898.5 2901.5 2907.0 2910.0 2914.0 2916.5 2918.5 2921.0 2933.5 2936.5 2943 . 5 2946 . 0 2957.5 2960.0 2963.0 2965.0 2971.5 2973.5 2980.0 2982.5 2986.5 2989.0 2991.0 2993.5 3002.0 3005.5 3017.0 3020.0 3018.5 3022.0 3024 . 0 3028 . 0 3033.0 3036.0 3039.5 3042.5 3042.5 3045.5 3048.0 3050.5 3056.0 3059.5 3058.5 3061.5 3061 . 0 3064 . 5 3065.0 3068.5 3072.5 3076.0 3080.0 3083.5 3085.5 3088.5 3095.0 3098.0 3097 . 0 3100 . 5 3099.0 3102 . 0 3106.5 311'0.0 3112 . 5 3116 . 0 3123 . 0 3126 . 0 3124 . 5 3128 . 0 3132.5 3136.0 3135.5 3139.0 3146.0 3149.5 3152.0 3155.0 3157.0 3160.0 3160.5 3164.0 3167.0 3169.5 3170.5 3173.0 3171.0 3175.0 3183.5 3186.0 3185.5 3188.0 3195.5 3199.0 3198.0 3201.5 3201.5 3209.5 3213.5 3215.5 3226.0 3228.0 3236.5 3243.0 3247.0 3255.5 3268.0 3273.5 3279.0 3289.5 3298.5 3308.0 3310.0 3314.5 3324.0 3331.0 3335.0 3342.5 3345.5 3349.5 3368.5 3386.5 3403.0 3409.0 3419.5 3423.5 3439.5 3449.0 3451.5 3463.0 3471.0 3472.0 3482.5 3485.5 3489.5 3495.0 3498.5 3519.0 3535.5 3536.5 3546.5 3555.0 3585.0 3594.5 3597.0 3611.0 3616.5 3619.5 3623.0 3629.0 3633.0 3640.5 3668.5 3204.5 3213.5 3216.0 3219.0 3229.0 3231.0 3239.5 3245.5 3249.5 3257.5 3271.5 3275.5 3282.5 3292.5 3302.0 3310.0 3313.0 3317.5 3325.5 3332.5 3336.5~ 3345.0 3348.5 3351.5 3371.0 3388.5 3404.5 3410.5 3421.0 3425.0 3441.0 3450.5 3453.5 3465.0 3472.5 3476.0 3485.0 3487.5 3491.0 3496.5 3500.0 3521.0 3537.5 3540.0 3547.5 3557.0 3587.5 3597.0 3599.5 3613.0 3618.5 3621.5 3625.5 3632.0 3635.0 3642.5 3670.5 3676.0 3681.0 3689.0 3704.5 3708.5 3715.5 3725.0 3731.0 3746.5 3748.0 3762.0 3772.0 3776.0 3780.5 3802.5 3809.5 3838.5 3854.5 3876.5 3906.0 3911.5 3922.5 3932.0 3936.5 3941.0 3958.0 3968.0 3971.0 3980.5 3999.0 4002.0 4003.0 4014.5 4020.0 4029.5 4037.5 4040.5 4041.5 4042.5 4047.5 4053.0 4059.5 4068.0 4070.5 4075.5 4078.5 4091.5 4106.0 4107.5 4128.0 4131.5 4143.5 4147.5 4160.0 4168.0 4176.5 4179.0 3678.0 3683.0 3691.5 3710.5 3712.5 3717.5 3727.0 3733.0 3749.0 3750.5 3764.5 3774.0 3778.0 3782.5 3804.5 3812.0 3840.5 3856.5 3878.5 3908.0 3913.5 3924.5 3935.0 3938.5 3943.0 3960.0 3971.0 3973.5 3982.5 4001.0 4004.0 4006.0 4017.0 4022.5 4031.0 4040.0 4043.5 4045.5 4047.0 4050.0 4056.5 4063.0 4071.5 4073.0 4078.0 4081.0 4092.5 4108.0 4109.5 4130.0 4133.0 4145.5 4149.5 4161.5 4170.5 4178.0 4180.5 4192.0 4209.5 4217.0 4226.5 4228.0 4234.5 4240.5 4247.0 4250.5 4252.5 4255.5 4263.0 4283.0 4292.0 4304.0 4307.0 4309.5 4319.0 4325 5 4327 5 4330 5 4332 5 4341 0 4342 5 4345.0 4354.5 4358.5 4375.5 4377.5 4391.5 4398.5 4403.5 4410.5 4427.5 4434.0 4437.5 4450.0 4452.0 4463.0 4475.5 4498.0 4505.0 4508.0 4512.0 4516.0 4517.5 4536.0 4546.5 4592.0 4595.5 4614.5 4615.5 4625.0 4632.5 4655.0 4670.0 4681.0 4194.5 4211.0 4218.0 4228.0 4229.5 4236.0 4242.0 4248.5 4252.0 4254.0 4257.0 4264.5 4284.5 4293.5 4305.5 4308.5 4310.5 4320.0 4327.0 4329.0 4331.5 4333.5 4342.5 4344.0 4346.5 4355.5 4360.0 4376.5 4378.5 4393.0 4399.0 4404.5 4411.5 4428.5 4435.0 4439.5 4451.0 4453.0 4465.0 4476.5 4498.0 4506.0 4509.0 4513.0 4517.0 4518.5 4537.0 4547.5 4593.0 4596.5 4615.5 4617.5 4626.0 4633.5 4656.0 4671.0 4681.5 4684.5 4715.5 4747.5 4772.5 4784.0 48O5.O 4806.5 4830.5 4832.5 4840.5 4842.5 4860.5 4872.0 4909.0 4925.5 4966.5 4971.0 4987 5 5006 0 5026 0 5037 5 5056 5 5061 5 5065 5 5069.0 5075.0 5083.5 5104.5 5111.0 5118.5 5128.5 5137.0 5140.0 5145.5 5155.0 5163.5 5167.5 5176.5 5179.5 5188.5 5192.0 5218.0 5219.5 5223.5 5232.0 5236.5 5257.5 5261.5 5264.5 5269.0 5273.0 5278.5 5281.0 5283.5 5306.5 5314.0 5330.0 4685.5 4716.5 4748.5 4773.5 4784.0 4805.0 4807.0 4830.5 4832.5 4841.0 4843.0 4862.0 4873.5 4911.0 4927.5 4967.5 4973.5 4987.0 5006.5 5028.5 5038.5 5057.0 5062.0 5065.5 5069.0 5075.0 5084.5 5107.5 5115.0 5120.0 5129.5 5138.0 5141.0 5148.0 5156.5 5164.0 5168.5 5177.5 5183.0 5189.5 5193.0 5220.5 5222.0 5226.0 5233.0 5237.0 5258.0 5262.0 5265.0 5269 5 5273 5 5279 0 5281 5 5284 0 5306 5 5314.0 5330.0 5331.5 5347.5 5351.5 5356.5 5363.0 5368.0 5372.5 5377.0 5381.0 5390.0 5399.0 5403.0 5407.0 5411.5 5414.0 5417.5 5419.0 5422.0 5424.5 5426.0 5428.0 5431.0 5447.0 5451.5 5460.5 5466.0 5473.0 5477.5 5488.5 5490.0 5493.5 5497.5 5503.5 5510.5 5518.0 5530.5 5540.5 5545.5 5549.5 5558.0 5569.5 5577.0 5601.0 5618.5 5627 0 5629 5 5634 5 5638 5 5662 5 5669 0 5674 0 5684.0 5688.0 5700.0 5707.0 5713.0 5718.0 5332.0 5347.5 5351.5 5356.5 5363.0 5368.0 5372.5 5377.0 5381.0 5394.0 5403.0 5407.5 5411.0 5415.0 5417.5 5421.0 5423.0 5426.0 5428.5 5430.0 5432.0 5434.5 5450.5 5455.0 5463.5 5470.5 5476.0 5479.5 5490.5 5492.5 5496.5 5499.5 5506.5 5512.5 5520.0 5532.5 5542.5 5547.5 5551.5 5558.0 5571.5 5579.0 5599.5 5617.5 5626.0 5628.5 5633.5 5637.5 5661.5 5668.0 5673.0 5683.5 5687.0 5699.0 5706.0 5712.0 5717.5 5723.0 5722.5 5729.0 5728.0 5736.5 5736.0 5740.0 5739.5 5744.0 5743.5 5760.0 5759.5 5764.0 5763.5 5770.5 5770.0 5773.5 5773.0 5779.5 5779.0 5786.0 5785.5 5790.5 5790.0 5813.5 5813.0 5816.5 5816.0 5835.0 5834.5 5838.0 5837.5 5869.5 5869.0 5874.0 5873.5 5878.5 5878.0 5882.0 5881.5 5885.5 5885.5 5892.5 5892.0 5910.0 5908.5 5939.0 5938.5 5986.0 5985.5 5994.5 5995.0 6013.5 6014.0 6017.5 6018.0 6022.0 6021.5 6053.5 6053.0 6056.0 6055.5 6060.5 6060.0 6064.5 6064.5 6069.5 6069.0 6076.5 6076.0 6122.0 6121.5 $ ~ERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 MWD 4 MWD 5 $ ~EMARKS: MERGED MAIN PASS. $ MERGE TOP 92.0 1846.0 2282.0 5409.0 5610.0 )ata Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN MERGE BASE 1846.0 2282.0 5409.0 5610.0 6122.0 Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD FT/H 4 1 68 MWD API 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 86.5 6122 ROP MWD FT/H 0 731.99 3R MWD API 15.55 236.64 RPX MWD OHMM 0.84 2000 RPS MWD OHMM 1.08 2000 RPM MWD OHMM 1.22 2000 RPD MWD OHMM 1.06 2000 FET MWD HOUR 0.0906 41.9768 Mean Nsam 3104.25 12072 211.984 11973 107.137 11961 15.2171 11966 24.2408 11966 57.3748 11966 82.921 11966 1.12976 11966 First Reading.. 86.5 136 86.5 94.5 94.5 94.5 94.5 94.5 Last Reading 6122 6122 6066.5 6077 6077 6077 6077 6077 First Reading For Entire File .......... 86.5 Last Reading For Entire File ............ 6122 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 )hysical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 ~omment Record ?ILE HEADER FILE NUMBER: 2 {AW MWD Curves and lo9 header data for each bit run in separate files. ~IT RUN NUMBER: 1 )EPTH INCREMENT: .5000 ?ILE SUMMARY VENDOR TOOL CODE START DEPTH GR 92.0 RPM 100.0 RPS 100.0 RPD 100.0 FET 100.0 RPX 100.0 ROP 141.5 $ hOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: STOP DEPTH 1801.5 1794.0 1794 o 0 1794.0 1794.0 1794.0 1845.5 25~FEB-00 Insite 5.46 Memory 1845.0 .0 2.8 TOOL NUMBER PB01426CGR8 PB01426CGR8 12.250 110.0 Water Based 10.00 105.0 9.3 35O 5.0 1.700 .000 3.300 2.400 70.0 80.0 70.0 70.0 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR'FREQUENCY (HZ): REMARKS: $ )ara Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 ~ame Service Order Units Size Nsam Rep )EPT FT 4 1 68 ~OP MWD010 FT/H 4 1 68 JR MWD010 API 4 1 68 ~PX MWD010 OHMM 4 1 68 ~PS MWD010 OHMM 4 1 68 ~PM MWD010 OHMM 4 1 68 ~PD MWD010 OPtMM 4 1 68 ?ET MWD010 HOUR- 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 ;ame Service Unit Min Max )EPT FT 92 1845.5 ~OP MWD010 FT/H 0 544.9 ;R MWD010 API 15.55 112.98 ~PX MWD010 OHMM 2.06 2000 ~PS MWD010 OHMM 2.17 1727.42 ~PM MWD010 OHMM 2.46 2000 ~PD MWD010 OHMM 2.79 2000 YET MWD010 HOUR 0.3049 2.6596 Mean 968.75 162.342 65.0865 39.021 64.9535 158.858 229.46 0.745993 Nsam 3508 3409 3420 3389 3389 3389 3389 3389 First Reading 92 141.5 92 100 100 100 100 100 Last Reading 1845.5 1845.5 1801.5 1794 1794 1794 1794 1794 First Reading For Entire File .......... 92 Jast Reading For Entire File ........... 1845.5 'ile Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 ~hysical EOF ?ile Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 ~omment Record ?ILE HEADER ?ILE NUMBER: 3 ~AW MWD Curves and log header data for each bit run in separate files. ~IT RUN NUMBER: 2 )EPTH INCREMENT: .5000 rILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 1794.5 2230.5 RPS 1794.5 2230.5 RPX 1794.5 2230.5 FET 1794.5 2230.5 RPD 1794.5 2230.5 GR 1802.0 2238.5 ROP 1846.0 2282.0 $ JOG HEADER DATA DATE LOGGED: 25-FEB-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2282.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .6 MAXIMUM ANGLE: .9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PB01426CGR8 PB01426CGR8 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 2281.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ )ara Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 'lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Water Based 10.20 70.0 8.7 200 5.0 1.700 .000 3.300 2.400 ~ame Service Order Units Size Nsam Rep )EPT FT 4 1 68 ~OP MWD020 FT/H 4 1 68 ~R MWD020 API 4 1 68 ~PX MWD020 OHMM 4 1 68 ~PS MWD020 OHMM 4 1 68 ~PM MWD020 OHMM 4 1 68 ~PD MWD020 OHMM 4 1 68 ?ET MWD020 HOUR 4 1 68 Code Offset 0 4 8 Channel 1 2 3 12 4 16 5 20 6 24 7 28 8 70.0 80.0 70.0 70.0 ~ame Service Unit Min Max )EPT FT 1794.5 2282 tOP MWD020 FT/H 0.26 409.57 )R MWD020 API 47.67 147.39 ~PX MWD020 OHMM 2.06 30.22 ~PS MWD020 OHMM 2.26 27.44 ~PM MWD020 OHMM 2.45 22.14 ~PD MWD020 OHMM 3.03 18.42 ?ET MWD020 HOUR 0.3383 7.006 Mean 2038.25 143.941 79.6803 6.83888 7.32137 7.56426 7.77702 1.45604 Nsam 976 873 874 873 873 873 873 873 First Reading 1794.5 1846 1802 1794.5 1794.5 1794.5 1794.5 1794.5 Last Reading 2282 2282 2238.5 2230.5 2230.5 2230.5 2230.5 2230.5 First Reading For Entire File .......... 1794.5 Last Reading For Entire File ........... 2282 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 ~hysical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 ~omment Record ?ILE HEADER ?ILE NUMBER: 4 ~AW MWD Curves and log header data for each bit run in separate files. ~IT RUN NUMBER: 3 )EPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2231.0 5364.0 RPD 2231.0 5364.0 RPM 2231.0 5364.0 RPS 2231.0 5364.0 RPX 2231.0 5364.0 GR 2239.0 5354.0 ROP .2282.5 5409.0 $ ,OG HEADER DATA DATE LOGGED: 28-FEB-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 65.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 5409.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: .1 1.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PB01430HGR6 PB01430HGR6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OMMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ )ata Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Water Based 9.20 48.0 9.5 300 6.5 1.300 .000 4.000 2.000 Iame Service Order Units Size Nsam Rep Code Offset Channel ~EPT FT 4 1 68 0 1 ~OP MWD030 FT/H 4 1 68 4 2 ;R MWD030 API 4 1 68 8 3 ~PX MWD030 OHMM 4 1 68 12 4 .PS MWD030 OHMM 4 1 68 16 5 .PM MWD030 OHMM 4 1 68 20 6 70.0 115.0 70.0 70,0 ~PD MWD030 OHMM 4 1 68 ?ET MWD030 HOUR 4 1 68 24 28 ~ame Service Unit Min Max )EPT FT 2231 5409 ~OP MWD030 FT/H 8.86 731.99 JR MWD030 API 36.91 236.64 {PX MWD030 OHMM 0.84 1808 ~PS MWD030 OHMM 1.08 2000 ~PM MWD030 OHMM 1.22 2000 ~PD MWD030 OHMM 1.06 2000 ?ET MWD030 HOUR 0.1636 41. 9768 Mean 3820 265.468 130.482 5.12524 8.19787 20.0376 30.1978 1. 09497 Nsam 6357 6254 6231 6267 6267 6267 6267 6267 First Reading 2231 2282.5 2239 2231 2231 2231 2231 2231 Last Reading 5409 5409 5354 5364 5364 5364 5364 5364 ?irst Reading For Entire File .......... 2231 ~ast Reading For Entire File ........... 5409 ?ile Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 ~hysical EOF ~ile Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 ~omment Record 'ILE HEADER 'ILE NUMBER: 5 AW MWD Curves and log header data for each bit run in separate files. ~IT RUN NUMBER: 4 ~EPTH INCREMENT: .5000 ILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5354.5 5587.0 RPM 5364.5 5597.5 RPS 5364.5 5597.5 RPD 5364.5 5597.5 FET 5364.5 RPX 5364.5 ROP 5409.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 5597.5 5597.5 5609.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTIONS(IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: ara Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 29-FEB-00 Insite 65.30 Memory 5607.0 .3 .8 TOOL NUMBER PB01430HGR6 PB01430HGR6 8.500 Water Based 9.50 44.0 9.1 250 4.6 2.000 2.000 2.700 2.200 65.0 111.0 65.0 65.0 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 .~ame DEPT IR .{PX .{PS .{PM ?ET Service Order Units Size Nsam Rep FT 4 1 68 MWD040 FT/H 4 1 68 MWD040 API 4 1 68 MWD 040 OHMM 4 1 68 MWD 040 OHMM 4 1 68 MWD 040 OHMM 4 1 68 MWD 040 OHMM 4 1 68 MWD 040 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 ~ame Service Unit Min Max )EPT FT 5354.5 5609.5 ~OP MWD040 FT/H 13.1 179.99 ]R MWD040 API 92.89 166.98 ~PX MWD040 OHMM 1.98 19.36 ~PS MWD040 OHMM 1.96 15.81 ~PM MWD040 OHMM 1.91 12.88 ~PD MWD040 OHMM 1.88 12.71 rET MWD040 HOUR 0.0906 14.0237 Mean 5482 60.7368 131.455 6.30824 6.26477 6.18428 6.22124 2.92319 Nsam 511 401 466 467 467 467 467 467 First Reading 5354.5 5409.5 5354.5 5364.5 5364.5 5364.5 5364.5 5364.5 Last Reading 5609.5 5609.5 5587 5597.5 5597.5 5597.5 5597.5 5597.5 First Reading For Entire File .......... 5354.5 Jast Reading For Entire File ........... 5609.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 ,hysical EOF 'ile Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 2omment Record FILE HEADER FILE NIIMBER: 6 ~AW MWD Curves and lo9 header data for each bit run in separate files. ~IT RUN NUMBER: 5 )EPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5587.5 6066.5 RPD 5598.0 6076.5 RPM 5598.0 6076.5 RPS 5598.0 6076.5 RPX 5598.0 6076.5 FET 5598.0 6076.5 ROP 5610.0 6121.5 $ 30G HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 02 -MAR- 00 Insite 65.30 Memory 6122.0 .2 .3 TOOL NUMBER PB01430HGR6 PB01430HGR6 8.500 Water Based 9.40 44.0 8.9 300 4.4 .750 .000 1.800 1.700 70.0 109.0 70.0 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 ~ame Service Order Units Size Nsam Rep )EPT FT 4 1 68 ~0P MWD050 FT/H 4 1 68 JR MWD050 API 4 1 68 ~PX MWD050 OHMM 4 1 68 ~PS MWD050 OHMM 4 1 68 ~PM MWD050 OHMM 4 1 68 ~PD MWD050 OHMM 4 1 68 rET MWD050 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 tame Service Unit Min Max )EPT FT 5587.5 6121.5 ~OP MWD050 FT/H 16.45 356.7 $R MWD050 API 79.79 198.4 ~PX MWD050 OHMM 1.73 23.12 ~PS MWD050 OHMM 1.81 20.9 ~PM MWD050 OHMM 1.9 18.38 .PD MWD050 OHMM 2.11 15.2 'ET MWD050 HOUR 0.3321 41.1145 Mean 5854.5 170.497 119.514 5.94556 5.77355 5.70077 5.81776 1.41338 Nsam 1069 1024 959 958 958 958 958 958 First Reading 5587.5 5610 5587.5 5598 5598 5598 5598 5598 Last Reading 6121.5 6121.5 6066.5 6076.5 6076.5 6076.5 6076.5 6076.5 irst Reading For Entire File .......... 5587.5 ast Reading For Entire File ........... 6121.5 ile Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF rape Trailer Service name ............. LISTPE Date ..................... 00/03/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/03/24 Origin ................... STS Reel Name ...... ~ .......... UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Techni-cal Technical Services Services Physical EOF Physical EOF End Of LIS File ARCO ALASKA INC. 700 G STREET ANCHORAGE, AK 99510 907-276-1215 To: AOGCC 3001 Porcupine Dr. Anchorage, AK 99501 Attn: Loft Taylor Date: April 20, 2000 From: Wayne Campaign ATO 1454 ARCO Alaska Inc. P.O.Box 100360 Anchorage, Alaska 99510-0360 ~00 Enclosed is the final well log data for Meltwater North #1 (API# 1 blueline and sepia each: Platform Express Array Induction - RXO 2" 5" Platform Express Neutron / Density 2" 5" Natural Gamma Ray Spectrometry Tool 5" Dipole Sonic Imager (Relabeled Data) 2" 5" Combinable Magnetic Resonance Tool 2" 5" Platform Express Caliper Log 2" Fullbore Formation Micro Imager 5" Mechanical Sidewall Coring Tool Repeat Formation Tester Packer Setting. Record 5" Ultrasonic Imager CCL/GR Perforating Record .- o I 501032032600) as listed below. 02MAR00 02MAR00 02MAR00 02MAR00 02MAR00 02MAR00 02MAR00 03MAR00 03MAR00 07MAR00 06MAR00 07MAR00 1 blueline each: DSI Relabel Quality Control (Geoframe Processed) 5" CMR Total Porosity (Geoframe Processed) 5" 05MAR00 13MAR00 1 CD Rom: Open Hole Edit containing Main & Repeat: PEX/AIT/CMtUNGT/DSI/FMI 02MAR00 Upon receipt, please sign and return to: Catherine Worley ATO 1355 P.O. Box 100360 Anchorage, AK 99510. Thank You R£CEIV[D APR 000 DATA SUBMITTAL COMPLIANCE REPORT 919/2002 Permit to Drill 2000'120 MD 6122 'I'VD Well Name/No. MELTWATER NORTH t Operator PHILLIPS ALASKA INC. . 6121 Completion Dar 4/26/2000 ~ Completion Statu P&A Current Status P&A APl No. 50-103-20326-00-00 UIC N REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Mud Log ~~~. Sample _~NO- ~,/~ Directional Survey (data taken from Logs Portion of Master Well Data Maint) Name Log Log Scale Media Run No Interval Start Stop 2200 6098 OH I Dataset CH Received Number Comments Open 4/20/2000 0~2~00-6098 DIR SRVY MUD 2 DGR/EWR-MD 2/5 FINAL DGPJEWR-TVD 2/5 FINAL 9480 1-5 9481 1 · la, B~FMI 5 FINAL PEX-CALIPER 2 FINAL PEX-AIT 2/5 FINAL PEX-NDT 2/5 FINAL NGR-SPEC 5 FINAL DSI-RELABELED 2/5 FINAL CMR 2/5 FINAL CMR TOTAL PORO 2 FINAL DSI-RELABEL QC 2 FINAL USIT 5 FINAL PERF 7 ~/~ ;}~ 5 FINAL PACKER SETTING 5 FINAL MSCT FINAL RFT FINAL 86 0 110 100 100 2200 2200 2200 2200 2200 2200 2200 5340 2250 50 5340 5080 5423 5460 6066 6122 6122 6122 6121 6097 6097 6097 6097 6097 6097 6039 6040 6050 6000 5780 5420 5603 5701 Open 5/4/2000 09480""1~-6066 OH 8/3/2000 SPERRY 0-6122. OH 5/4/2000 EPOCH BL(C) 110-6122 OH 5~/2000 100-6122 OH 5/4/2000 100-6121 OH 5/4/2000 94~ SPERRY DGR/EWR OH 4~0/2000 ~ SCHLUM PEX- AIT/CMPJNGPJDSI/FMI OH 4/20/2000 2200-6097 OH 4~0/2000 2200-6097 OH 4/20/2000 2200-6097 OH 4/20/2000 2200-6097 OH 4D0/2000 2200-6097 OH 4/20/2000 2200-6097 OH 4~0/2000 2200-6039 OH 4/20/2000 BL(C) 5340-6040 OH 4~0/2000 BL(C) 2250-6050 CH 4~0/2000 BL(C) 50-6000 CH 4~0/2000 5340-5780 CH 4/20/2000 5080-5420 OH 4~0/2000 5423-5603 OH 4~0/2000 5460-5701 Permit to Drill 2000120 MD 6122 / TVD L L DATA SUBMITTAL COMPLIANCE REPORT 91912002 Well Name/No. MELTWATER NORTH Operator PHILLIPS ALASKA INC. 6121 Completion Dat 4/26/2000 Completion Statu P&A Current Status P&A APl No. 50-t03-20326-00-00 UIC N CIBP & TBNG PNCH 5 FINAL 0 1753 CH 6/1/2000 0-1753 FMI IM/MSD DIPS 2 FINAL 5200 69070 OH 7/5/2000 BL(C) 5200-69070 Well Cores/Samples Information: Name Cuttings ~.- Core Chips Start 60 Interval Stop 6122 Dataset Sent Received Number Comments 1022 1022 ADDITIONAL INFORMATION Well Cored? {~)/N Received? (~ N Chips Analysis (~ N R~.ee. ive. d ? Daily History Received? d'~ N Formation Tops ~ Comments: Compliance Reviewed By: Date: Customer Project Field Structure Wellhead Profile Arco Alaska Inc. Alaska State Plane 4 North Slope Alaska Meltwater North Meltwater North # 1 Meltwater North #1 MD Incl. Azim. Sub-Sea TVD (ft) Deg. Deg. (ft) (ii) 0.000 0.000 -292.700 0.000 0.000 -184.700 0.370 346.980 -137.750 0.370 356.410 92.565 1.260 8.270 304.071 1.420 13.570 480.993 2.550 18.950 729.830 2.850 23.710 787.815 2.740 21.580 818.329 2.570 18.790 905.945 1.420 11.780 1035.424 1.060 333.980 1159.757 0.540 74.950 1283.139 0.610 69.830 1500.758 0.870 118.270 1915.907 0.770 120.150 2012.637 0.810 115.450 2477.493 0.650 99.200 2945.295 0.970 67.630 3433.258 0.070 172.590 3901.206 0.250 229.120 4368.034 0.670 252.800 4831.278 0.800 260.940 5080.048 0.250 230.850 5283.259 0.170 208.990 5380.748 0.250 263.810 5758.966 0.250 263.810 5828.505 0.000 108.000 154.950 385.270 596.800 773.770 1022.760 1080.810 1111.360 1199.070 1328.630 1452.990 1576.380 1794.010 2209.190 2305.930 2770.830 3238.670 3726.680 4194.650 4661.480 5124.740 5373.530 5576.750 5674.240 6052.460 6122.000 0.000 108.000 154.950 385.265 596.771 773.693 1022.530 1080.515 1111.029 1198.645 1328.124 1452.457 1575.839 1793.458 2208.607 2305.337 2770.193 3237.995 3725.958 4193.906 4660.734 5123.978 5372.748 5575.959 5673.448 6051.666 6121.205 Local N Coord (ft) 0.000 0.000 0.148 1.614 4.598 8.655 16.893 19.435 20.810 24.621 28.943 31.485 32.661 33.327 32.596 31.922 28.941 27.096 28.225 29.449 28.500 27.038 26.334 25.831 25.570 24.990 24.957 Creation Date Profile Type Your Ref Job Number Kelly Bushing Elev. Print Date 3/15/2000 ORIGINAL API-501032032600 AKMM90251 292.7 3/15/2000 5862239.800 0.000 0.000 5862239.800 0.000 0.000 5862239.948 0.788 0.150 5862241.416 0.026 1.610 5862244.397 0.426 4.600 5862248.448 0.114 8.650 5862256.667 0.459 16.890 5862259.203 0.645 19.440 5862260.573 0.495 20.810 5862264.374 0.243 24.620 5862268.686 0.906 28.940 5862271.229 0.702 31.480 5862272.405 1.036 32.660 5862273.056 0.040 33.330 5862272.289 0.157 32.600 5862271.606 0.107 31.920 5862268.583 0.016 28.940 5862266.696 0.056 27.100 5862267.778 0.110 28.230 5862268.974 0.212 29.450 5862268.030 0.047 28.500 5862266.593 0.098 27.040 5862265.912 0.067 26.330 5862265.422 0.294 25.830 5862265.163 0.115 25.570 5862264.591 0.054 24.990 5862264.560 0.000 24.960 0.000 0.000 -0.034 -0.248 0.044 0.838 3.361 4.360 4.934 6.339 7.602 7.412 7.473 9.551 14.401 15.610 21.279 26.884 33.437 37.136 36.403 33.052 29.947 28.202 27.967 26.875 ~ 26.573 .. 443729.910 443729.910 443729.877 443729.674 443729.987 443730.812 443733.395 443734.414 443734.998 443736.430 443737.725 443737.554 443737.624 443739.706 443744.551 443745.755 443751.402 443756.993 443763.554 443767.263 443766.523 443763.160 443760.050 443758.302 443758.065 443756.968 443756.667 Local E Coord Global E Coord Global N Coord Dogleg Vertical Section (ii) (ft) (ft) (°/lOOfl:) (ft) MEMORANDUM TO: /~laska Robert Christenson,~ Chairman THRU: FROM: Blair Wondzell, P. I. Supervisor Tom Maunder, ,~,~ff~x.~ Petroleum Engineer State of Alaska Oil and Gas Conservation Commission DATE: April 18, 2000 SUBJECT: Wellbore Plug Arco Meltwater North 1 oo- o I-z__ Confidential M,onday~ April 177 2000; I witnessed the successful cementing of the 9-5/8" x 7" annulus (DA) and an attempt to cement the perforations in Arco's exploratory well "Meltwater North 1". No rig was over the hole. I arrived and found wireline operations proceeding to place dummy valves in the mandrels in the completion string. A Dowell cementing unit was available for cementing and a Hot Oil truck for pressure testing. Keith Fergusson was the ARCO representative. Prior to my arrival, a combination of diesel and brine had been circulated into the inner annulus. After placing the fluid, the wireline unit successfully set the dummy to isolate the IA from the tubing. The IA was pressure tested to 1000 psi using the Hot Oil unit. Dowell pumped 140 sx of Arctic Set 1 to cement the upper 1000' of the DA. This operation was accomplished as planned. Dowell then attempted to cement the perforated interval with the intent of squeezing cement into the perforations and leaving cement up into the tubing string. This operation was not successful. Once the cement was in the tubing, the well went on vacuum. The cement was overdisplaced to keep the perforations clear for a further abandonment operation. The well was freeze protected during the displacement process. After talking with the ARCO representative, it was not surprising that cementing the interval proved difficult. ARCO had successfully pumped a large frac during the completion and also had performed an injectivity test. ARCO was making plans to continue the abandonment activities later in the week depending on equipment availability. SUMMARY: I witnessed the successful placement of the outer annulus wellbore plug and an unsuccessful attempt to squeeze the perforated interval on Arco's exploratory well "Meltwater North 1". Additional plugging activities are planned later this week. Attachments: None cc: Mike Zanghi/Paul Mazzolini (Kuparuk drilling) CONFIDENTIAL ANN CMT PLUG MELTVVATER NORTH STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Plu9 And Abandonment Report Operator: ARCO Alaska Operator Rep.: Keith Fergusson Lease No.: Well No.: MWN #1 Sec. T-R Total Depth: 11,030' M Date: Well Name: Meltwater North #1 PTD No.: 199-121 12N - 12E Meridian: Elevation: 53.5 Mud Wt.: UM 2/21/00 10.6 ppg. CASING DATA: Drive Pipe: Conductor: Intermediate: 20" O.D." Set 6: ft. With O.D." Set 6: 80' ft. Surface: 9-5/8" O.D." Set 6: ft. Prodctn: 7" Penetration O.D." Set 6: O.D." Set 6: PLUGGING DATA: 1. Open Hole Plugs: 2. Open Hole Isolation Plugs: 3. Perforation Plugs: 4. Annulus Plugs: 140 sx (23 bbls) AS I. Cement volume calculated to fill 9-5/8" x 7" annulus from surface to 1000'. 5. Casing Stub Plugs: 6. Surface Plug: Casing Removal: " Casing Cut @ Feet 20 .... Casing Cut @ -3 TL Feet 9-5/8 .... Casing Cut @ -3 TL Feet 7 .... Casing Cut @ -3 TL Feet REMARKS: 4/17--AOGCC inspector witnessed pumping of OA plug and unsuccessful attempt to squeeze perforations. Distribution: orig - Well File c ~ Operator c - DNPJDOG c ~ Database c - Rpt File c - Inspector FI-000 (Rev. 3/93) Inspector (s): 4/17--Tom Maunder P&A MWN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon RECEIVED CONFIDENTIAL 0ii & Gas Coas. Commission Suspend _ Operation Shutdown __ Re-enter suspended well_'~¢iG~i~-~'~ Alter casing_ Repair well _ Plugging __ Change approved program __ Pull tubing _ Time extension_ Stimulate_ Variance__ Perforate___ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development __ Exploratory ..X Stratigraphic __ Service 4. Location of well at surface: ASP NAD27 Coordinates X=443,730 & Y=5,862,240 2359' FNL, 1798' FWL, Sec. 20, T8N, R7E, UM At top of productive interval 2334' FNL, 1825' FWL, Sec. 20, T8N, R7E, UM At effective depth At total depth 2334' FNL, 1825' FWL, Sec. 20, T8N, R7E, UM 6. Datum elevation (DF or KB) 28' RKB, Pad 263' 7. Unit or Property name N/A 8. Well number Meltwater North #1 9. Permit number 200-012 10. APl number 50-103-20326-00 11. Field/Pool Exploration feet 12. Present well condition summary Total Depth: measured 6122 feet (approx) true vertical 6122 feet Effective depth: measured 6025 feet (approx) true vertical 6025 feet Casing Length Size Structural Conductor 80' 16" Surface 2243' 9.625" Intermediate na Production 6079' 7" Cemented 200 cu. Ft. 493 sx AS III LW & 230 sx Class G 65 sx Class G Lead plus 189 sx Class G Tail Measured depth 108' 2271' 6107' True vertical depth 108' 2271' 6107' Perforation depth: measured 5620'-5670' true vertical 5620'-5670' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 5337' MD/TVD Packers and SSSV (type and measured depth) Baker FB1 Pkr @ 5224' MD/TVD 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch Contact Paul Mazzolini at 263-4603 with any questions. LOT test, surface cement details and casing detail sheets _ 14. Estimated date for commencing operation 15. Status of well classification as: 4/4/00 Oil __ Gas' __ 16. If proposal was verbally approved Nameofapprover/~,/¢c;v~~'[j Date approved V/~"~/~..~ Service__ 17. I hereby certify that the foregoing is true and correct to the I~/eC'my knowledge. Signed '~'~"~~~ Title Exploration/Tarn/Tabasco Team Leader Paul Maz~.orini 263-4603 Suspended X Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_,,/ BOP Test ~ Location clearance Mechanical Integrity Test_ Subsequent form require 10- Approved by the order of the Commission Commissioner IIAppr°val I~00 _.09( Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Post Office Box 100360 Anchorage, Alaska 99510-0360 A March 30,2000 Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 CONFIDENTIAL Re: Sundry Notice for P&A of Meltwater North #1 Exploration Well- Surface Location: ASP NAD 27 Coordinates X=443,730 & Y=5,862,240 2359' FNL 1798' FWL Sec 20 TSN R7E, UM Target Location: 2334' FNL, 1825' FWL Sec. 20, TSN, R7E, UM Bottom Hole Location: 2334' FNL, 1825' FWL Sec. 20, TSN, R7E, UM Dear Blair, ARCO Alaska, Inc. hereby files this sundry for the plug and abandonment of the Meltwater North #1 exploration well. The well has been completed, perforated, and flow tested in the Bermuda sand interval. The proposed P&A work could commence as soon as 4/4/00 or when the AOGCC approves of the attached procedure. There is a possibility that an injectivity test could be performed prior to the P&A of this wellbore. A Sundry notice will be filed separately for this work. If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn / Tabasco Development Group Attachments cc: Meltwater North #1 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS CONFIDENTIAL 1. Type of Request: Abandon X Suspend_ Alter casing _ Repair well _ Change approved program m Operation Shutdown __ Re-enter suspended well _ Plugging __ Time extension _ Stimulate_ Pull tubing _ Vadance m Perforate m Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development -- Exploratory X Stratigraphic _ Service 4. Location of well at surface: ASP NAD27 Coordinates X=443,730 & Y= S,862,240 6. Datum elevation (DF or KB) 28' RKB, Pad 263' 7. Unit or Property name N/A 8. Well number feet 2359' FNL, 1798' FWL, sec. 20, TSN, R7E, UM At toP of productive interval 2334' FNL, 1825' FWL, Sec. 20, TSN, R7E, UM At effective depth At total depth 2334' FNL, 1825' FWL, Sec. 20, T8N, R7E, UM Meltwater North #1 9. Permit number 200-012 10. APl number 50-103-20326-00 11. Field/Pool Exploration 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical Casing Length Structural Conductor 80' Surface 2243' Intermediate na Production 6079' 6122 6122 6025 6025 Size 16" 9.625" 7" feet feet feet feet Cemented 200 cu. Ft. 493 sx AS III LW & 230 sx Class G 65 sx Class G Lead plus 189 sx Class G Tail Measured depth 108' 2271' 6107' True vertical depth 108' 2271' 6107' Perforation depth: measured 5620'-5670' true vertical 5620'-5670' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80@5337'MD/TVD Packers and SSSV (type and measured depth) Baker FB1Pkr @ 5224' MD/TVD 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch _ Contact Paul Mazzolini at 263-4603 with any questions. LOT test, surface cern ent details and casing detail sheets _ _ 14. Estimated date for commencing operation 4~4/O0 16. If proposal was verbally approved Name of approver 15. Status of well classification as: Oil Gas Suspended X Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of m Y knowledge. Signed Title Exploration/Tarn/Tabasco Team Leader Date Paul Mazzolini 263-4603 FOR COMMISSION USE ONLY !Conditions of approval' Notify Corn mission so representative may witnes~s Plug integrity~' BOP Test ,,--' Location clearance / Mechanical Integrity Test -- Subsequent form require 10- /-~O7 -- ~ N. Ch~n.~n . . . . . . . . Meltwater North #1 Final P&A CONFIDENTIAL Revised 3~30~00 Notify AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. Rig up slickline unit and set dummy valves in GLM's at 5280', 5249', and 2483'. Pull the dummy from the GLM above the packer at 5137'. RD slickline. Mobilize and rig up D/S for well P&A operation. Bullhead 9.3 ppg fluid to the tubing tail. Displace 3-1/2" x 7" annulus to 9.3 ppg fluid. RU wireline and set dummy Valve in GLM at 5137'. RD wireline unit. Rig up DIS to tree and establish injection rates into perforations. Mix approx. 35 bbls. cement (Class G with additives) and pump down tubing into the peforations. Pump enough slurry (25.5 bbl) to cover PBTD to tubing tail, leaving remaining slurry in tubing. Hesitate squeeze cement into perfs as required- do not displace top of cement past 5200' MD. Dipslace cement with 9.3 ppg fluid. Rig up SWS "eline" unit and RIH to tag top of cement plug to verify placement. Record and report results. Pressure test casing to 1500 psi. AOGCC may want to witness tag of cement and pressure test. Ct~:~'~ l'~a~,~ '~~ '~ ~.~3~w~,~c['~, RIH with 2.795 gauge ring to 350'. Set Baker 3-1/2" bridge plug at approx. 310'. Make up SWS tubing puncher and perforate tubing at approx. 300'. POOH and RD SWS "eline" unit. RU DIS and circulate surface cement plug (approx. 10.2 bbls. Arctic Set 1 ) down tubing into tubing/casing annulus to surface. NOTE: Notify Slope AOGCC Inspector before setting surface plug. RU cementing unit to 7" x 9-5~8" annulus. Establish injection rate down annulus with fresh water followed by approx. 23 bbls of Arctic Set cement slurry to fill annulus to 1000' MD. 10. Clear lines and shut down pumps. Rig down cementing unit and clean up. 11. Cut off wellhead and all casing strings at 3 feet below original ground level. Send casing head with stub to Materials for repair / re-dressing. 12. Weld cover plate over all casing strings with the following information bead welded into the top: ARCO ALASKA, INC Meltwater North #1 PTD # 200-012 APl # 50-103-20326-00 13. Remove cellar. Back fill cellar with gravel as needed. Back fill remaining hole to ground level with gravel. Clear ice pad location and demob all materials and equipment. TJB 3/30/00 FILE: MWN #1 Paul Mazzolini Date Exploration/Tam/Tabasco Team Leader TJB 3/30/00 Blair Wondzell w/AOGCC Date SENT BY' 3-30- 0 ; 2 :.59P~1 ; ARCO Ai.~SKA+ 907 276 7542;# 2/ 2 Calculations Charl ~"~_~; ~.~-~1,,;,~ ~ ~ ~~ i(':t~~' ~ ...!~'~' ~9 ~':; 7~- ~' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,~ Chairman DATE: March 5, 2000 THRU: Blair Wondzeil, d~~ SUBJECT: P. I. Supervisor FROM: John H Spaulding,:r~~. ~ Petroleum Inspect6r BOPE Test ARCO / Doyon 141 Meltwater N #1 wildcat On March 5, 2000, I traveled to ARCO's Meltwater North #1 wildcat well to witness the BOPE test. The AOGCC BOPE Test Report Form is attached for reference. As noted on the report form no failures were observed. I did not witness the gas alarm calibrations at this time as they had been performed 2 days prior to my arrival. SUMMARY: I witnessed the BOPE test on; Doyon 141, 0 failures, 4 hour test time Attachment: bop doyon 141 3-5-00js CONFIDENTIAL ( OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Doyon Operator: ARCO Well Name: Meltwater Norfh # '1 Casing Size: 9 5/8" Set @ Test: Initial Weekly · Rig No. 141 PTD # Rep.: Rig Rep.: 2,271 Location: Sec. X Other 200-012 DATE: 3/5/00 Rig Ph.# 1-907-263-3110 Jim Willingham Mike Whitely 20 T. 8N R. 7E Meridian Umiat Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: ok Well Sign yes Upper Kelly/IBOP Housekeeping: ok (Gan) Drl. Rig ok Lower Kelly / IBOP PTD On Location yes Hazard Sec. yes" Ball Type Standing Order Posted yes , Inside BOP Quan. Pressure P/F I 25O/5,0O0 P 250/5,000 P 250/5, 000 P 250/5,000 P BOP STACK: Quan. Test Press. P/F Test Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve I 250/2500 1 250/5,000 1 250/5,000 I 250/5,000 1 250/5, 000 2 250/5,000 1 250/5,000 n/a 250/5,000 MUD SYSTEM: Visual Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector P CHOKE MANIFOLD: P No. Valves P No. Flanges P Manual Chokes P Hydraulic Chokes P P Alarm Pressure P/F 14 250/5,000 P 33 250/5,000 P 1 P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 5 @ 2100AVG 3,000 P 1,850 ~ P minutes 49 minutes 1 X Remote: Psig. sec. sec. X Number of Failures: 0 ,Test Time: ~ 4,0_.~0~ours. Number of valves tested 20 Repair or Replacement ~f Failed Equipment will be made within' 'da.yeti. Notify the inspector and follow with ~n or Faxed verification to Ithe AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No, 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The mud system and gas detectors were not checked for calibration as they had been logged as done by the rig electrician 2 days prior to my witnessing the BOP test Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspel~t.(~,lL (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO YES 24 HOUR NOTICE GIVEN X NO Waived By: Witnessed By: 'n 141 3-5-00 js John H. Spaulding , [[x/dl Meltwater North #1 Water Injection Test] Subject: [Fwd: Meltwater North #1 Water Injection Test] Date: Wed, 05 Apr 2000 16:04:45-0800 From: Blair Wondzell <blair_wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Lamont Frazer <LFRAZER~mail.aai.arco.com> Lamont, Thanks for bringing over the USIT log and the FIT plot. I agree that the USIT indicated that the casing was very well cemented above and below the perforation zone, thus making it highly unlikely that any injection water would move up or down the borehole behind pipe. The FIT IS secondary to the USIT. Additional information is: the test is intended to be not over 5 days, approximately 1000 bwpd, and hoped for surface pressure of about 750 psig with 2000 psig maximum. Water is to be Kuparuk produced water. Lamont, we agree that this test is part of your overall reservoir data gathering program and as such does not need any special approval. Good Luck with the Test. Blair Wondzell, 4/5/00. Subject: Re: Meltwater North #1 Water Injection Test Date: Wed, 05 Apr 2000 13:56:41 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Lamont C Frazer <LFRAZER~mail.aai.arco.com> Lamont, I would like the USIT, or other log showing the intended injection interval is well cemented. Also a copy of the complete FIT. Thanks, Blair Lamont C Frazer wrote: Blair, As per our phone discussion on 4/4/00, AAI is seeking AOGCC approval to inject water into the Meltwater North #1 prior 'to abandoning the well. The purpose of the water injection test is to help evaluate potential formation damage impacts associated with water injection. A cement evaluation log (USIT) indicates that good cement bonding exists above and below the perforated Bermuda interval. In addition, an FIT was performed on the surface casing shoe indicating good isolation. The FIT was conducted with 9.2 ppg mud, which was pressured up to 800 psi (15.9 ppg equivalent). The pressure bleed down only 120 psi after 12 minutes. Please let me know if you have any questions, or would like additional information on this subject. Sincerely, Lamont Frazer AAI Tarn/Meltwater Reservoir Engineer of 2 4/5/00 4:05 PM ~R¢~ Meltwater North #1 Water Injection Test Subject: Re: Meltwater North #1 Water Injection Test Date: Wed, 05 Apr 2000 13:56:41 -0800 From: Blair Wondzcll <blair_wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Lamont C Frazer <LFRAZER~mail.aai.arco.com> Lamont, I would like the USIT, or other log showing the intended injection interval is well cemented. Also a copy of the complete FIT. Thanks, Blair Lamont C Frazer wrote: Blair, As per our phone discussion on 4/4/00, AAI is seeking AOGCC approval to inject water into the Meltwater North #1 prior to abandoning the well. The purpose of the water injection test is to help evaluate potential formation damage impacts associated with water injection. A cement evaluation log (USIT) indicates that good cement bonding exists above and below the perforated Bermuda interval. In addition, an FIT was performed on the surface casing shoe indicating good isolaEion. The FIT was conducted with 9.2 ppg mudr which was pressured up to 800 psi (15.9 ppg equivalent). The pressure bleed down only 120 psi after 12 minutes. Please let me know if you have any questions, or would like additional information on this subject. Sincerely, Lamont Frazer AAI Tarn/Meltwater Reservoir Engineer [ of 1 4/5/00 3:35 PM ,,,?- F,~OM ." I:::iRCO GEO ¢:::ITO :246"7 ~, TO. - - : _ 90? 276. _?S42,..,,- _ 2¢00,04-04, ,~"'~'~~02-' 02PM~ J["[~30 p. 01/0! l ansmb 13572_c~'gm~'41 i'0"705 l ansmb 4-Apr-2000 11 '0 ansmb ~2~" :,' ....... '-' ~i. :.,~.-~:2 ...i..: :; 7~.;i -.'.:_';~;~ ', ,,~, i-.'.. ,. .,,,.:_::~ ...... 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Post Office Box 100360 Anchorage, Alaska 99510-0360 A March 30,2000 Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 CONFIDENTIAL Re: Sundry Notice for P&A of Meltwater North #1 Exploration Well- Surface Location: ASP NAD 27 Coordinates X=443,730 Y--5,862,240 2359' FNL 1798' FWL Sec 20 T8N R7E, UM Target Location: 2334' FNL, 1825' FWL Sec. 20, T8N, R7E, UM Bottom Hole Location: 2334' FNL, 1825' FWL Sec. 20, T8N, R7E, UM Dear Blair, ARCO Alaska, Inc. hereby files this sundry for the plug and abandonment of the Meltwater North #1 exploration well. The well has been completed, perforated, and flow tested in the Bermuda sand interval. The proposed P&A work could commence as soon as 4/4/00 or when the AOGCC approves of the attached procedure. There is a possibility that an injectivity test could be performed prior to the P&A of this wellbore. A Sundry notice will be filed separately for this work. If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn / Tabasco Development Group Attachments cc: Meltwater North #1 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Meltwater North #1 Final P&A( CONFIDENTIAL Revised 3~30~00 Notify AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Rig up slickline unit and set dummy valves in GLM's at 5280', 5249', and 2483'. Pull the dummy from the GLM above the packer at 5137'. RD slickline. 3. Mobilize and rig up DIS for well P&A operation. 4. Bullhead 9.3 ppg fluid to the tubing tail. Displace 3-1/2" x 7" annulus to 9.3 ppg fluid. RU wireline and set dummy Valve in GLM at 5137'. RD wireline unit. . Rig up D/S to tree and establish injection rates into perforations. Mix approx. 35 bbls. cement (Class G with additives) and pump down tubing into the peforations. Pump enough slurry (25.5 bbl) to cover PBTD to tubing tail, leaving remaining slurry in tubing. Hesitate squeeze cement into perfs as required- do not displace top of cement past 5200' MD. Dipslace cement with 9.3 ppg fluid. . Rig up SWS "eline" unit and RIH to tag top of cement plug to verify placement. Record and report results. Pressure test casing to 1500 psi. AOGCC may want to witness tag of cement and pressure test. RIH with 2.795 gauge ring to 350'. Set Baker 3-1/2" bddge plug at approx. 310'. Make up SWS tubing puncher and perforate tubing at approx. 300'. POOH and RD SWS ~eline" unit. . RU DIS and circulate surface cement plug (approx. 10.2 bbls. Arctic Set 1 ) down tubing into tubing/casing annulus to surface. NOTE: Notify Slope AOGCC Inspector before setting surface plug. , RU cementing unit to 7" x 9-5~8" annulus. Establish injection rate down annulus with fresh water followed by approx. 23 bbls of Arctic Set cement slurry to fill annulus to 1000' MD. 10. Clear lines and shut down pumps. Rig down cementing unit and clean up. 11. Cut off wellhead and all casing strings at 3 feet below original ground level. Send casing head with stub to Materials for repair / re-dressing. 12. 13. Weld cover plate over all casing strings with the following information bead welded into the top: ARCO ALASKA, INC Meltwater North #1 PTD # 200-012 APl # 50-103-20326-00 Remove cellar. Back fill cellar with gravel as needed. Back fill remaining hoie to ~'~;'~ ~,, ........ ground level with gravel. Clear ice pad location and demob all materials and equipment. TJB 3/30/00 FILE: MWN #1 Paul Ma_~'olini Date Exploration/Tam/Tabasco Team Leader ~T~ 3/30/00 Blair Wondzell w/AOGCC Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS CONFIDENTIAL 1. Type of Request: Abandon X Suspend_ Alter casing _ Repair well _ Change approved program __ Operation Shutdown __ Re-enter suspended well _ Plugging __ Time extension _ Stimulate _ Pull tubing _ Variance__ Perforate__ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory X Stratigraphic _ Service 6. Datum elevation (DF or KB) 28' RKB, Pad 263' feet 7. unit or Property nam e N/A 4. Location of well at surface: ASP NAD27 Coordinates X=443,730 & Y= 5,862,240 2359' FNL, 1798' FWL, Sec. 20, T8N, R7E, UM At top of productive interval 2334' FNL, 1825' FWL, Sec. 20, T8N, R7E, UM At effective depth At total depth 2334' FNL, 1825' FWL, Sec. 20, T8N, R7E, UM 8. Well number Meltwater North #1 9. Permit number 20~012 10. APl number 5~103-20326-00 11. Field/Pool Exploration ~12. Present well condition summary Total Depth: measured 6122 feet (approx) true vertical 6122 feet Effective depth: measured 6025 feet (approx) true vertical 6025 feet Casing Length Size Cemented Structural Conductor 80' 16" 200 CU. Ft. Surface 2243' 9.625" 493 sx AS III LW & Intermediate na 230 sx Class G Production 6079' 7" 65 sx Class G Lead plus 189 sx Class G Tail Measured depth 108' 2271' 6107' True vertical depth 108' 2271' 6107' Perforation depth: measured 5620'-5670' true vertical 5620'-5670' Tubing (size, grade, an d measured depth) 3.5", 9.3#, L-80 @ 5337' MD/TVD Packers and SSSV (type and measured depth) Baker FB1 Pkr @ 5224' MD/TVD DUPLICATE 13. Attachments Description summary of proposal X Detailed operation program BOP sketch __ Contact Paul Mazzolini at 263-4603 with any questions. LOT test, surface cern ent details and casing detail sheets _ _ 14. Estimated date for commencing operation 4/4/00 15. Status of well classification as: Oil~ Gas __ Suspended 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of m y knowledge. Signed Title Exploration/Tarn/Tabasco Team Leader Date Paul Mazzolini 263-4603 FOR COMMISSION USE ONLY Conditions of approval: N,.otify Com mission so representative may witness Plug integrity v/ BOP Test v/' Location clearance Mechanical Inte-~rity Test_ -- Subsequent form require 10- ORIGINAL 81GNEDSY Robert N. Christenson I ApprovQ) ~07 27§ 7'5~2 ;~'#' 2/2 ! : i ' ' .=or....:.or.,o,..-Alaska From: Core Laboratories 600 W. 58th Ave., Unit D Anchorage, Alaska 99518 To: Alaska Oil & Gas Conservation Commissio~ 3001 Porcupine Drive Anchorage, Alaska 99501 Date: Mar 14 2000 Well Name: Arco Alaska Inc. Meltwater North ~l#1 Number of Samples: 150 Contact: Mark Myers Description of Material: Core Chip Samples Depths: Core #1 5607 to 5726.7 Core #2 5728.5 to 5758.6 Sent .By: TIM LAWLOR Core Laboratodes Received By: RECEIVED Re: MWN #1 Projected Depth Subject: Re: MWN #1 Projected Depth Date: Wed, 01 Mar 2000 16:51:13 -0900 From: Jack Hartz <jaek_hartz~admin.state.ak.us> Internal Organization: Alaska Oil & Gas Conservation Commission To: Tom J Brassfield <TBRASS~mail.aai.arco.eom> CC: Thomas E Maunder <tom_maunder~admin. state.ak.us>, Blair Wondzell <blair_wondzell@admin. state.ak.us> Tom, I have noted your request to drill as deep as 6500' in the subject well. This message confirms the verbal approval I indicated at about 4:00 pm. I understand this change will not affect casing design, only the depths it is run. Jack Hartz Tom J Brassfield wrote: > Jack, here is the info which was forwarded to Maunder. Thanks for helping out ~ with this request. Will advise status tomorrow. > Tom ~265-6377. > Forwarded by Tom J Brassfield/AAI/ARCO on 03/01/2000 > 03:51 PM > > Tom J Brassfield > 03/01/2000 02:45 PM > > To: tom maunder~admin.state.ak, us > cc: > Subject: MWN #1 Projected Depth > > Tom, there is a remote possibility that we may need to drill deeper than the > 6300' MD submitted in the Sundry last week. The Geologists are looking for the > C-35 marker which might go as deep as 6193' MD (originally picked at 5777' MD). > We would then like an additional 200' for logging tools and rathole. We have > cored from 5607' to 5757' MD and the rig is currently POOH to pick up a drilling > assembly and drill to TD. We would like permission to go as deep as 6500' MD if > required. > Thanks, Tom Sr. Petroleum Reservoir Engineer Alaska Oil and Gas Conservation Commission cASING. TEST and FORMATION INTEGRITY TEST Well Name: _Tt:;.T~.,.. ;...~,' Date: 2/27/0D Supervisor; MIKE WHITELEY G) Initial Casing Shoe Test Reason(s) for test:-~ C! Formation Aclequancy for Annular injection ?~ [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size agd Description: 9 5/6" 53.M~ L.80 BTC Casing'Seffir~ Dept~.i? 2~.TI' TMD Mud Weight: 9.2 ppg Length of Open Hole: EMW= L~ak-off ..... 0.052;x 'T'VD + Mud Weigh't = 800 ps/ + 9.2 ppg · O.l~J2 x 2,~0~ Pump output = o.1 ~ EMW = t5.9 ppg lime Depth: 2,301' TMD 2,300' 'rVD 30' Pun-q~ed =.8 I:~1 ~I/ALUE! back = r~'ll Z.t~O pM -- LINE -- ONE M~IUTE TICKS -e--LEAK-OFF TF_~T LOT SHUT IN TIME C~INO TEST SHUT IN TIME N~TE: ,~T~OKEG TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MIHUTB6 FOR PiPE Ostks · 4 etlC~ ! .......... .Set.ks ........... 8 arks ~ p~i sea 800 psi , i~:: .......... , '.'"m' -...nm o.o ____ ~_ ,~ '-J~- ~3.0 mi~ ' j 760 ~ ~ - '7~,~' ........ ] .... ~.0 min ~ 700 7.0 mi. ~ CASING TEST DATA 1 10 Irllm 16 sti~ PRilIIIIIE .!,~20 psi .!,FTo_9.p_~ ..t.2860 Psi NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE ~Re: Meltwater North #1 Subject: Re: Meltwater North #1 Date: Thu, 24 Feb 2000 11:48:17 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Tom J Brassfield <TBRASS@mail.aai.arco.com> Tom, Your proposal sounds good. With the first well finished, you have new information available to guide your decisions on the depths. If you 'are sending over a 403, ~ou can cover both issues on the same form. Give me a call if you need anything further. Tom Maunder Tom J Brassfield wrote: > Tom, per our telephone conversation today ARCO is making the follo~ng requests: > We would like the option of setting the surface casing as deep as 2400' MD at > MWN #1. Our permitted depth is 2150' MD/TVD. Based on the logs from Meltwater > North #2 vve feel that we should be setting in a better shale at a slightly > deeper depth. We have a Geologist on location and our target is between 2200' > to 2300' ND. This depth is targeted below the Base of the West Sak and above > the C-80 marker as outlined in our permit to drill. > In addition we are requesting that the TD of the well be extended to 6300' > MD. The permited depth is 5968' MD. Based on the logs and formation tops at > MWN #2 the Geologists have lowered the base of the Bermuda from 5663' MD (in > the permit) to 5767' ND. The 6300' MD gives us some flexibility in case the > Base of the Bermuda is deeper. > Because the potential TD is slightly deeper than discussed we will send over a > Sundry Form 10-403. Thanks for your assistance in this matter. Tom Tom Maunder <tom maunder~,admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission ~f 1 2/24/00 12:33 PM APPLICATION FOR SUNDRY APPROVALS CONFIDENTIAL 1. Type of Request: Abandon Alter casing _ Change approved program X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2359' FNL, 1798' FWL, Sec. 20, T8N, R7E, UM At top of productive interval 2359' FNL, 1798' FWL, Sec. 20, T8N, R7E, UM At effective depth At total depth 2359' FNL, 1798' FWL, Sec. 20, T8N, R7E, UM Suspend_ Operation Shutdown Re-enter suspended well Repair well_ Plugging__ Time extension Stimulate Pull tubing _ Variance __ P~'rforate ~ -- Other _ 5. Type of Well: Development __ Exploratory X Stratigraphic ~ Service 6. Datum elevation (DF or KB) 28' RKB Pad 265' 7. Unit or Property name Exploration 8. Well number Meltwater North #1 9. Permit number 200-012 10. APl number 50-103-20326-00 11. Field/Pool Exploration feet 12. Present well condition summary Total Depth: measured drilling @700 (approx) true vertical 700 Effective depth: measured 700 (approx) true vertical 700 Casing Structural Conductor Surface Intermediate Production Liner Length Size 77' 16" 9.625" feet feet Plugs (measured) (See attached proposal) feet Junk (measured) feet Cemented 200 cf Measured depth True vertical depth ORiGiI AL Perforation depth: measured N/A N/A true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A CONFIDENTIAL RECEIVED ~.;B 2 5 2000 Ala~a Oil & Gas Cons. Commis~n 13. Attachments Description summary of proposal X Detailed operation program BOP sketch Contact Paul Mazzolini at 263-4603 or Tom Brassfield @ 2-~5--6377with any questions. LOT test, su~ cement details and casi~ detail sheets 14. Estimated date for commencing operation 2~24~00 .~ _ 16. If proposal was verbally apprOved Name of approver Tom Maunder 2/24/00 Date approved i 15. Status of well classification as: I Oil Gas Suspended,,X S~ervice I17. I hereb~:t,~fy th~ th)~/~:g:l:~,~t~r,u~_~nd correct to the best of my knowledge. Signed /-cc~.~_.v._ / - [~,,-~,-----~ Title Exploration/Tarn Team Leader Paul Maz~olini 263-4603 FOR COMMISSION. USE ONLY Date Conditions of approval: Notify Commission so representative may witness JApproval NO~ Plug integrity _ BOP Test Location clearance __ I ""' -. Mechanical Integrity' Test Subseque~'[orm require 10- the order of the Commission ORIG!NAL S!~NED BY o,~e~ O°~3'~Jcommissioner:. Date c~ '"'~ ~'JO~ Approved by Form 10-403 Rev 06/15/88 Robert N. Chdstenson P,~)~)~e~.~e~°O~y~ __ SUBMIT IN TRIPLICATE Meltwater North # 1 Revised 2/24/00 Proposed Changes to Permit #200-012: Based on information gathered from the Meltwater North #2 well, ARCO is requesting the following changes to the approved Permit to Drill for Meltwater North # 1: Surface Casing setting depth be allowed to a depth of 2400' MD. The permitted depth is 2150' MD. Based on the logs from Meltwater North #2 we feel the 2400' MD will allow the surface casing to be set in a better shale section. The target setting depth is between 2200' to 2300' MD and will be picked by an onsite Geologist. The new targeted depth will be below the Base of the West Sak and above the C-80 marker as outlined in the permit to drill. The total depth of Meltwater North #1 be changed from 5968' (permitted) to 6300' MD. Once again, based on the logs from MWN #2 which is approximately 2miles away, the Geologists have lowered the projected base of the Bermuda from 5663' MD (in the permit) to 5767' MD. The 6300' MD gives ARCO some flexibility to drill deeper in case the Base of the Bermuda is deeper than prognosed and allows for rathole in the completion program on a success leg. See attached changes to predicted formation depths. The above request was verbally approved by Tom Maunder with the AOGCC on 2/24/00. CONFIDENTIAL TJB 2/24/00 FILE: MWN # 1 ALASI~A OIL AND GAS CONSERVATION COPl~IlSSION Paul Mazzolini Exploratim~Farn Drilling Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501 -,3192 :- PHONE: (907) 279-1433 FAX: (907) 276-7542 Meltwater North # 1 ARCO Alaska. Inc. Permit No: 200-012 Sur. Loc. 2359'FNL, 1798'FWL, Sec. 20, ISN, R7E. UM Btmhole Loc. 2359'FNL, 1798'FWL, Sec. 20, T8N, R7E. UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed bv a valid Formation Integrity Test (FIT). Cementing records. FIT data, and any CQLs must be subnfitted to the Commission on form 10- 403 prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Camill60echsli Taylor Commissioner BY ORDER OF THE COJVIMISSION DATED this ] ~7~ day of February, 2000 dlf/Enclosures CC: Department of Fish & Gmne. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1200 2100 27OO 420O 45CX} 46OO 5100 540O 57OO 6OOO 7 Ca~ing AR, CO Alaska, Inc. Structure: Meltwater North #1 Slot: slot #1 Field: Exploration Location: North Slope, Alaska Est|mated RKB Elevation: 293' ui, iDENTIAL B/Prrnfmt - T/W Sak Ba~e West Sak L 9 5/8 Ca~ing C-80 PROFILE COMMENT DATA Point MD B/ Prmfrst - T/W Sa 1 lg3,00 Bose West Sak 144.3.00 C-80 2318.00 C-40 3483.00 Top Cairn 5173.00 Tgt - T/ Bermuda 5318.00 Mid Bermudc 5495,00 Base Bermuda 5663.00 TD 5968.00 Itq~ I~t~3 RECEIVED FEB to3 ~000 Oil & Ga, Cons. Anchorage Top Cairn Tgt- T/Bermuda Mid Bermuda Ba~e Bermuda L m 63OO Tom Maunder <tom_maunder(~admin.state,ak,us> on 0212412000 10:48:17 AM To: Tom J Brassfleld/AAI/ARCO cc: Subject: Re: Meltwater North #1 CONFIDENTIAL Tom · Your proposal sounds good. Nith the first well finished, you have new information available to guide your decisions on the depths. If you are sending over a 403, you can cover both issues on the same form. Give me a call if you need anything further. Tom Maunder Tom J Brassfield wrote: > Tom, per our telephone conversation today ARCO is making the following requests: > We would like the option of setting the surface casing as deep as 2400' MD at > MWN #1. Our permitted depth is 2150' MD/TVD. Based on the logs from Meltwater > North #2 we feel that we should be setting in a better shale at a slightly > deeper depth. We have a Geologist on location and our target is between 2200' > to 2300' MD. This depth is targeted below the Base of the West Sak and above > the C-80 marker as outlined in our permit to drill. > In addition we are requesting that the TD of the well be extended to 6300' > MD. The permited depth is 5968' MD. Based on the logs and formation tops at > MWN #2 the Geologists have lowered the base of the Bermuda from 5663' MD (in > the permit) to 5767' MD. The 6300' MD gives us some flexibility in case the > Base of the Bermuda is deeper. > Because the potential TD is slightly deeper than discussed we will send over a > Sundry Form 10-403. > > Thanks for your assistance in this matter. > Tom I~ - tom_maunder, vcf ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 1, 2000 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill ARCO Meltwater North #1 Surface Location: 2359' FNL, 1798' FWL, Sec. 20, TSN, R7E, UM or ASP4, NAD 27 coordinates of X=443730 & Y=5862240 Target & BHL: 2359' FNL, 1798' FWL, Sec. 20, TSN, R7E, UM CONFIDENTIAL Dear Commissioner Christenson: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well, the Meltwater North #1, located approximately 12 miles south of the Kuparuk River Unit's 2N Pad. This well will be accessed via ice road originating near 2N Pad, drilled using Doyon Rig #141, tested and permanently abandoned prior to spring breakup. Attached is the information required by 20 ACC 25.005 (c) for your review. There are no shallow hazards expected at Meltwater North #1 (see attached graphs). The nearest offset wells indicate no overpressured intervals or lost circulation zones. There will be no reserve pit for this well. Waste drilling mud will be hauled to a KRU Class II disposal well. If a production casing string is set in this well ARCO requests that Meltwater North #1 be permitted for annular disposal of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As in the past ARCO would submit a 10-403 Form to the Commission with the appropriate technical information. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. If this well is tested, the produced fluids will either be hauled to Kuparuk for recycling or injection into an appropriate disposal well or the produced fluids will be reinjected into the MWN #1 wellbore. Please note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well, However, there will be H2S monitoring equipment operating, as is the usual case while drilling wells in and near the Kuparuk River Field. If you have any questions or require any further information, please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely, . Paul Mazzolini Drilling Team Leader Exploration/Tarn Team Leader Attachments cc: Meltwater North #1 Well File RECEIVED FEB G5 2000 Oil & Gas Cons. Commission Anchorage ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company ALA ' ^ OIL AND GAS CONSERVATION COM 31ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory X Stratigraphic Test [] Developm~'~t Oil Re-Entry [~ Deepen [~] Service r-] Development Gas [~ Single Zone Multiple Zone X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 265' feet 3. Address 6. Property Designation Tarn Expl. P. O. Box 100360, Anchorage, AK 99510-0360 ADL 389058 ALK 4998 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 2'5.O25) ASP4, NAD27 coordinates X=443,730 & Y=5862240 or N/A Statewide 2359' FNL, 1798' FWL, Sec. 20, T8N, R7E, UM At top of productive interval (@ TARGET ) 8. Well number Number 2359' FNL, 1798' FWL, Sec. 20, T8N, R7E, UM Meltwater North #1 #U-630610 At total depth 9. Approximate spud date Amount 2359' FNL, 1798' FWL, Sec. 20 , T8N, R7E, UM 2/18/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line Cirque #2 MD 5968' 2359' @ TD feet 7.3 Miles feet 5607 TVD 5968' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth N/A feet Maximum hole angle 0o Maximum surface 1217 psig At total depth (TVD) 3290 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" Welded 80' 28' 28' 118' 118' +/- 200cf 12W' 9-5/8" 53.5 L-80 BTC 2122' 28' 28' 2150' 2150' 450 sx AS3 plus 340 sx CIG PPf 8Y2" 7" 29 ppf L-80 BTC-M 5940' 28' 28' 5968' 5968' 350 sx Cl G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: true measured vertical feet feet Plugs(measured) 0RI.. -- INAL - Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented ~.?asured depth True Vertical depth Structural t) Conductor RECEIVE Surface Intermediate Production Liner FEB 63 2000 Perforation depth: measured true vertical Naska 0il & Gas Cons. Commission Anchora.oe 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot X RefractiOn analysis X Seabed report r'~ 20 AAC 25.050"requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~,/ ~?.,~~ Title Exploration/Tarn Drilling Team Date Commission Use Only permit Number I APl ~amm~s i~e~d(~)~~ No~ Appr°val date¢;~ '"'/4~-'t~ ISee cOver letter fOr other requirements Conditions of approval requ Mud log required ~s r"] No Hydrogen sulfide measures ~ Yes r-] No Directional survey required [] Yes ~, No ._,~_(~,~ ~3/v~,.~. ~'~,-v¢~ ~/~ ~ Required workingpressuref0rBOiSE' E 2M [--~ 3M ~ 5.~M E~ 1OM r"] 15M J Other: Form 10-401 Rev. 7-24-89 Submit in triplicate 600 9O0 1200 1500 1800 2100 ~Q' 2700 4200 45oo 48O0 5100 54OO 57OO 6OOO 7 Cosing ARCO Alaska, Inc. Structure: Meltwater North #1 Reid: Exploration Slot: slot #1 Location: North Slope, ,, Estimated RKB Elevation: 293' B/Prmfrst - T/W Sak Base West S~k 5/8 Casing C-~ C-¢0 PROFILE COMMENT DATA Point MD B/ Prmfrst - T/W Sa 1195.00 Base West Sak 1445.00 C-80 2518.00 C-40 3485.00 Top Cairn 5175.00 Tgt - T/ Bermuda 5318.00 Mid Bermuda 5495.00 Base Bermuda 5665.00 TD 5968.00 Top Cairn Tgt- T/Bermuda Mid Bermuda Base Bermuda RECEIVED FEB 65 [~000 Naska Oil & Gas Cons. Commission Anchorage Created by jones For: T Brassfield Dote plotted: 28-Jon-2000 Plot Reference is Meltwater North 1~1 Vera. bi1. Coordinates ore in feel: reference slot i~11. True Vertlco, Depths ore r~st|mated RKB.I GENERAL DRILLING PROCEDURE ARCO Meltwater North #1 1. Move in and rig up Doyon #141 over pre-installed 16" conductor casing. 2. Install diverter system. 3. Drill 12-1/4" hole to 9-5/8" surface casing point (2150' MD) according to directional plan. . Run and cement 9-5/8" 53.5 ppf L-80 BTC Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 9-5/8" casing at approx. 1000' TMD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. 5. Install and test BOPE to 5,000 psi. Test casing to 2,500 psi. , Drill out cement and 20' of new hole. Perform formation .integrity test not to exceed 16.0 ppg EMW. These test results must demonstrate that the integrity of the casing shoe will be sufficient to contain the anticipated wellbore pressures. 7. Drill 8-1/2" hole to TD (5968' MD), coring as necessary, according to directional plan (if applicable). 8. Run open hole evaluation logs. 9. If the well is to be tested, run 7", 29 ppf L-80, BTC-M production casing. Go to step 10. Pressure test casing to 3500 psi. If the well will not be tested, P&A it per AOGCC regulations. Go to step 14 10. Complete the well with 3-1/2", 9.3#, L-80, EUE 8rd tubing. ND BOPE. NU upper tree and test to 5,000 psi. 11. Shut in and secure well. RDMO Doyon #141. 12. Hook up well for flow testing to surface tanks. Produced fluids to be trucked to Kuparuk production facilities or reinjected into the MWN #1 wellbore. 13. Test zones as appropriate. When complete, plug and abandon the well as per AOGCC regulations. 14. Thoroughly clean location and block off access ice road. RECEIVED TJB 1/31/00 FEB 03 2000 Naska 0il & Gas Cons. Commission Anchorage Meltwater North #t After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 2500 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the ,&Al LOT form (you can locate on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' to 50' of new hole below the casing shoe. , Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. , On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If 16.0 ppg EMW is reached, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a LOT At leak off pump 3 bbls of mud into formation prior to shutting down the pump. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in l-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered. Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. TJB 1/28/00 ARCO Meltwater North #1 PRESSURE INFORMATION AND CASING DESIGN (Per 20 AAC 25.005 (c) (4) DISCUSSION The following presents the data used for calculation of the anticipated surface pressures (ASP) used for the design and drilling of Meltwater North #2. Casing i Fracture Pressure Pore ASP Drilling Size i Gradient Gradient Pressure ................... '~"6" ................. i ........................... ~['~I"8'TVDT'"~I"~I"8'"'MD .......................... i ............. ~l"~l":'0""iS'JS'{J ............................ 8':'5'"'i5'~{j .................................. 52'"'i5§i ................... i ............................. Iq/A; ............................. ........... '9':'578" ........... i .................... '2'~'5'O"TVD'T2"~'5'0'"'MD ..................... i ............. ~"370'"'i5'j5'~ ............................ 9':"0'"'i5'i5'i~ ............................. ~f'0'O¥'iS'§i ............. i .................. ~r2"~-7"-i5§i ................... Expected Maximum Mud Weights: 12-1/4" Surface Hole to 2150' TVD / 2150' MD: 10.0 ppg 8-1/2" Production Hole to 5968' TVD / 5968' MD: 11.2 ppg Procedure for calculating Anticipated Surface Pressure (ASP): ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052)- 0.11] D Where: ASP = FG = 0.052 = 0.11 = D= Anticipated Surface Pressure in psi Fracture Gradient at the casing seat in lb/gal Conversion factor from lb/gal to psi/ft Gas gradient in psi/ft True vertical depth of casing seat in ft. RKB OR 2) ASP = FPP- (0.11 xD) Where: FPP - Formation Pore Pressure at the next casing point -1- ~1..:' Meltwater North #1 PRESSURE INFORMATION AND CASING DESIGN ASP Calculations: 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) -0.11] D = [(11 x 0.052)- 0.11] x 118 = 54 psi OR ASP = FPP - (0.11 x D) = 1006 - (0.11 x 2150) = 770 psi 2. Drilling below surface casing (9-5/8") ASP = [(FG x 0.052)- 0.11]D = [(13.0 x 0.052) - 0.11] x 2150; = 1217 psi OR ASP = FPP - (0.11 x D) = 3290 - (0.11 x 5968) = 2634 psi Casing Performance Properties ~ Internal Size Weight i Grade Connection Yield Collapse ............. .................... "f6'"' ................... i .......... 6275'8'"'jSiSf .......... ! ..................... B .................................................... PEB .................................................................................................... 'C'Si~E'~atSi;"C~'ifi~' ....................................................................... ............. 9::518" ............. ~ ............. 53'75'"i5'i5'f ............ i ............... E"8'0 ............................................. BTC .............................. [ ........... 7;93'0'"i5'§'i ........... 7 .......... 6';62'0""i5§i ............ i'"'"'~l'286"i~l'""T'""~f2;4'~'"'M ..... Casing Setting Depth Rationale 16"-118' RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 9-5/8"-2150' TVD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to next casing setting point. 7"-5968' TVD RKB Production casing to cover all open hole and all previously set casing to allow comprehensive testing of the well. This casing will not be set if logs indicate the well is a dry hole. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into the Meltwater North #t approved annulus or hauled to the nearest permitted Class I! disposal well. The cement rinsate will not be injected down the dedicated disposal well but will be recycled or held for the Meltwater North #1 open annulus or injected down another Kuparuk well open annulus. The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The Meltwater North #1 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. -2- Meltwater North #1 PRESSURE INFORMATION AND CASING DESIGN We request that Meltwater North #1 be permitted for annular pumping of fluids (if production casing is set) occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 50' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) *, (2150;) + 1,500 psi Max Pressure - 2842 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the casing performance properties above. Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). -3- ARCO Meltwater North #1 PRESSURE ANALYSIS AND PREDICTION (Per 20 ACC 25.005 (c) (7) and 20 ACC 25.033 (e)) DISCUSSION: An analysis and prediction of overpressured strata was performed for the ARCO Meltwater North #1 well as required by AOGCC regulations. ARCO does not expect to encounter abnormal pressure from any zones. The prediction is based on an evaluation of offset wells Ruby State #1, Cirque #2, and Meltwater South #1. Attached are the following: · Mud weight versus depth graph for these wells. · Seismic analysis for Meltwater North #1. Pore pressure, frac pressure and anticipated mud weight graph. · The pore pressure plots form the seismic data for Meltwater North #1 have a corrected depth scale to match the text in the original report dated 1/18/99 by Ray Wydrinski. (See attached report) · The Base of the Permafrost has been marked on the depth seismic cross section #1L5336. The colored anomaly which occurs directly underneath 850 feet MSL is believed to correspond to a velocity inversion associated with base of the permafrost. This is a commonly observed effect associated with predictive pore pressure analysis on the North Slope and is not normally indicative of abnormal pressure · The half pound increase at 2000' 'I'VD on the fracture gradient plot is not believed to be indicative of abnormal pressure based on surrounding wells. We have investigated surrounding offset data from the nearest wells and we see this inversion on some seismic plots but have not seen abnormal pressures while drilling. For example, the Meltwater South #1 well had a similar response, but nothing was seen while drilling. We will also have data from the Meltwater North #2 well to compare before drilling.,,..._ Meltwater North #1. · A discussion of the potential for shallow gas hazards will be included in the well plan. Also, as required by our internal SOP's a pre spud meeting with the crews will be held prior to spudding and the shallow gas hazard potential discussed. · The 10 ppg planned drilling mud weight for this interval will also exceed the predicted pore pressure prediction of approxiamtely 9.6 ppg. DRILLING FLUIDS PROGRAM ARCO Meltwater North #1 i'""D~i~'§i't"~)' ....................................................................................................................................................... '~!"0 ............................................................................. i'""PV ....................................................................................................................................................................... '2'0:2'6' ............................................................................ i'"Y'P .................................................................................................................................................................. '~'5:'25' ....................................................................... ~1'5"'2"0 ?Vi§"~(S'§i'ii~ ....................................................................................................................................... 5'0:70 ............................................................................ i'""li;iifi~ii"G'~l ........................................................................................................................................ 571'5 ......................................................................................... ~;':6 ........................................... i'"'"~l'0:l~li'fi:-G~l .......................................................................................................................... ~'5:'~'0 ..................................................................................... 6:;9' ........................................... ..... 'A'Pl'Fil't'i:~tb' ............................................................................................................................ ~1"0:"~I2' ................................................................................ '8:'~1"0 ........................................ ?'"'~FI ....................................................................................................................................................................... '9':5:~1"0 ........................................................................ '9:'5:4"0 .................................. t-%'"'S'6li~l'§ ....................................................................................................................................... '~"~I'0%' .............................................................................. ~:7'% ...................................... Drilling Fluid System: 3 - Derrick FIo-Line Cleaners Pioneer Model S2-12 Desander Tri-FIo 'Low Profile' Desilter Alpha-Laval Model DMNX 418 Centrifuge Pit Level Indicator (wi visual and audible alarms) Trip Tank Fluid Flow Sensor 8 - Brandt pit stirrers Drilling Area Risks: Examination of the three nearest offset wells, Ruby State #1, Cirque #2, and Meltwater South #1 reveal no subsurface hazards such as abnormal pressure or lost circulation zones. The MWN #2 well information will also be available as a data point prior to spudding the MWN #1 wellbore. For the well, MWN #1, seismic analysis is plotted and pore pressure and fracture gradient curves derived. Again, no indications of abnormal pressure or weak formations were seen particularly at shallow depths. The mud weights planned for MWN #1 are conservatively based on those used during drilling of the offsets. Prudent and precautionary drilling/tripping techniques will be emphasized while drilling this well with specific regards to the potential shallow gas hazards which have been encountered in the Tarn wells twelve (12) miles to the north and in other exploration activities. The 9-5/8" surface casing shoe will be tested to a maximum 16 ppg EMW formation integrity test or leak-off (whichever is least) after drilling 20 feet of new formation. MWN #1 I MIRU ] Depth vs Time Build Ice Rev. 11/4/99 Road I Spud o 'c:-': -: ',-',-: ~', ":-:- -1000-1 --;-- !'-i "J I' Drrill 1:~-1/4" : ; : : : : :[ Set~-§/8 cs~l: : : =~ -3000 ~ -4000 -6000 o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o Days MWN Time-Cost Graph.xls, Time Chart jt 2/1/00 10.7 10.5 10.3 10.1 9.5 9.3 :1 I I I I I I ' I ! I .I I I I I ! I I - I ! I I I I I I MELTWATER SOUTH oFFsET WELLS ' MUD WEIGHT AT DEPTH I I I .- I I I I ' I I I .... I. ___1_.___ I I .. ! ! I I I I I ! I I I I I I I I I I 1 I I ! _ _ - -.; ..... .! I I I . I. -. I . I ---;I- ........ -4 I I' I I I -- "I'---- - I I I I I ' ' {.. .... I I I I ! I I ! I ! ! I I ! I I I I I I I I . I I I. _ _ _ _ -- .... I -- .... I I I I I I I I I ' I I I I I I '1 I I I I' I I I I I I I I .I ' ! · .r' I ! I I I I I I II - : I I I I ~------ I- .... --'-----4-- I I I I I I I I I I I I I ! ! I I I : '1 I I I I I I .I I ' I II I I , I I . I__-- ------ --I--'---- -------- I I I I · I I ! I I I I ARCO CIRQUE #2 ~- : , ! '1 I I I I . I I I I I I I 1' I I ! I I I I I I I I . ! I ! I___ --------iI- I JNOCAL RUBY STATE #1 · ! : I I · I I I I I I : TEXACO WOLFBUTTON # 32-7-8 I I I I I _ -- -- -I. .... I- .... ___----t _----I- ........ -4 .... -- I II I I I I I I I I I I I I I I I I I I .... _{~. .... I I I ! * --------1'-~- I I' =r' ........ --t ..... I I I I II I I I I I I I I I I I I - I .... ~ " .. ~ .... ! - - ? .... I I -- I I ---- I ' - I .... ~-- .------ I I · l I . I I I I I I ~ ~ I . L .... I . I .... ~ .... .... I- .... I I I. I I 5000 6oOO 7o00 8ooo ~000 I I ;1_ _' .... I I .I I I I I I .[ .... I I I : I I ! I .. I I I I I I I ,, I I I ,, I ,, I ,, I I I' ,, I I 9000 10000 116" set e 108'I DRILLING TIME AND MUD WEIGHT CURVE ~ 10.8 10o0 7O0O MWS #1 - ; - -i ' ' ~ ' ', ' ' ~ ..i.. ~ - .i. - ~ - ., _ . ~ -.,.. ,. _ . .'.. '...'.. ' . , , , , D~II ~1/2' H~e ..,.. ~ -.,.. ~ . . .i.. · . -, - - ~ - _ .'. . : . _'_ _ : . - : . _'_ _ , , , , , , - -,- . ; - -,- . ,- - ; - -,- . .., - . · - -,.. · - Rotary Assy for Core Point _ .'. . : . .'_ . : . . . : . .'. . : , , , i , , , ' - -,- . ; - -,- . ; - . . ; - -,- - ; . . ~ - -, - . ~ - -, - . - -, - . g - -, - . g - 1OOOO · . Spud 1/25/99 . _i . . i...i . . i . . . i. .i . . i . i . . , i , , i , , , , , , , , , - -! - - r - -, - ' r - - - ' ·' ', ' ' r - -, .... , - - r '-i ' - , ....................... 10.4 ~ ~ ..,.. ~ . _, .... ,.. ~ . .i.. ~ - _ .,. . . .'._; - .; ; , , , , ! ! ) , , , , : ....... , , , , 10.2 - -,- . ~ - -,- . ,- - -!- . ,- - -,- . ,- - -, .... ,- . ,- - -,- . ; - · _.,.. · - -, .... i - ' r' ', ' - r - -, - - r - -, - - r ..,.. ~ ..,.. ~ . . . ~ .., . . ~-.,.. ..,.. ~ ..,. ¸10 9.8 ' Cored Bermuda from 7278' to 7407' in 2 runs , , ,. . ; .; ..'.. ; ..'.. ..'.. '. ' , , ,. _ , , , , , . . . . ., _ . g ., . - g - ~ -', ' ' r - ', '' . .1.. ~ .i.. ~ - - -~ - -' - - ~ - .i. - . .,...'.. ,...'. - ..; . .'.. ; .... · , . i , ' 'r - ',' 'r - ' ' . .& ..i.. ~ , , , , - -, - - ~- - -, ' ' r . _l.. L .., - - ~ P&A Well 5 10 15 ,. . .'. . '. . .'. _ '. . , i , i , ' . ' 'i "' '' - ' _l r · TIME TO DRILL (DAYS) 9.6 ~. 9.2 35 8.6 Rig Release 2/11/99 8.4 8.2 prepared by TJB 5/24/99 '1 ARCO Exploration ,,nd Produc§on Technology Date: Subject: From: Telephone: To: Internal Correspondence January 18, 1999 Pore Pressure Prediction for Meltwater.~!~ ~2, #4, #6 and #6R Seismic In-Lines 5120, 5265, 5336, 5812, 5823 and one traverse line R. Wydrinski PRC-Dl139 509-4325 M. Mabry ATO-1486 J. Trantham ATO-1204 This memo is to review the pore pressure prediction for above Meltwater wells. These wells are normal pressure with no apparent shallow hazard problems. Due to the seismic reference point was 500' above Mean Sea Level, the depths on the seismic pore pressure plots with depth are about 500' too shallow. Seismic ProcesSing: The accuracy of Geopressure prediction is highly dependent upon the accuracy of the seismic stacking velocity field that is used as input. This velocity field is generated by picking velocities at every fourth CDP location with an automated high resolution velocity analysis program 0.II-ICI process developed by AEPT). This process produces a very accurate and densely sampled velocity field to cover each CDP location. The RMS velocities that are output have been smoothed over 300 ms vertically and 150 CDPs horizontally to normalize any instabilities in the velocity field that might result from noise, lack of signal, or variations in CDP fold. Pressure Prediction Procedure: ARCO's PPFG software was used to calculate the pore pressures. From pore pressure prediction studies done in Alpine and Tarn areas, the following procedure was used for the pressure prediction: 1) A Normal Compaction Trend Line 0WCTL) was determined for each seismic line. The slope of this line was 4.54 with an intercept of ranging from 160 to 173. The variation for the intercept is due to ground level or formation top changes. 2) A comparison was made between the NCTL and the Seismic Integrated Travel Time (ITt). This difference is AAT. 3) From the Alpine and Tam study, a Translational Trend model was developed to convert the AAT to equivalent mud weight (PP). This equation is: PP = C2 * AAT 2 + C1 * AAT + CO where C2 = -2.5769 e-04; C1 = .119231; CO = 8.94231 4) The frach~e gradient was determined using the Eaton Method where the inputs are the bulk density (used from Cirque #2) and Poisons Ratio (from a West Cameron model). Seismic IL5265 Meltwater #1 (CDP 10465) Figure #1 is the pore pressure prediction across Seismic Inline 5265 with depth. The warmer the colors, the higher the mud weight (or pore pressure). Figure g2 is the pore pressure plot with time. Figure #3 is a plot of the pore pressure at the Meltwater location ( CDP 10465 ). The left track is the Integrated Travel Time (blaCk curve) and the Normal Compaction Trend Line (NCTL, red line). The right track has the pore pressure prediction (blue curve) and the fracture gradient (red curve). Labeled are the Leak Off Tests from Wolfbutton #1 and Cirque #2. There is good agreement with the LOT and the fracture gradient. Due to the reference point of the seismic was not at Mean Sea Level (MSL), the seismic pore pressure prediction with depth (Figure #1) is 500' shallower than the prediction at Meltwater #1 (Figure #3). There is no apparent shallow hazard at this location. Seismic IL5336 Meltwater ~g2 (CDP 10427) Figure #4 is the pore pressure prediction across Seismic Inline 5336 with ~iepth. Figure #5 is the pore pressure with time. Figure #6 is the pore pressure prediction at CDP 10428, which is the location of Meltwater #2. The presentation is the same as in Meltwater #1. The fracture gradient comparison with the LOTs from Cirque g2 and Wolfbutton #1 are in good agreement. The seismic'pore pressure with depth is 500' shallower than Meltwater #2 (Figure #6), due to the reference point of the seismic was not at Mean Sea Level but 500' above MSL. There is no apparent shallow hazard at this location. Seismic IL5120 Meltwater ~ (CDP 10578) Figure #7 is the predicted pore pressure for Seismic Inline 5120 with depth. Figure #8 is the pore pressure with time. Figure #9 is the pore pressure for Meltwater #4 at CDP 10578. The presentation is the same as Meltwater #1. There is good agreement between the fracture gradient and the known LOTs. The seismic pore pressure with depth is 500' shallower than Meltwater #4 (Figure ~)), due to the reference point of the seismic was not at Mean Sea Level but 500' above MSL. There is no apparent shallow hazard at this location. Seismic IL5825 Meltwater #6R (CDP 10461) Figure #10 is the predicted pore pressure for Seismic Inline 5823 with depth. Figure #11 is the pore pressure with time. Figure #12 is the pore pressure for Meltwater #6R at CDP 10461. The presentation is the same as Meltwater #1. There is good agreement between the fracture gradient and the known LOTs. The seismic pore pressure with depth is 500' shallower than Meltwater #6R (Figure #12), due to the reference point of the seismic was not at Mean Sea Level but 500' above MSL. There is no apparent shallow hazard at this location. Seismic Traverse Line - Meltwater #6 (CDP 10499) Figure #13 is the predicted pore pressure for this Traverse Line with depth. The borehole trajectory shows the surface location, at CDP 10499 and the bottom hole location at 10478. The well does not appear to encounter any apparent shallow hazards. Figure #14 is the pore pressure with time. Figure #15 is the pore pressure for Meltwater #6 at CDP 10499. The presentation is the same as Meltwater #1. There is good agreement between the fracture gradient and the known LOTs. The seismic pore pressure prediction with depth is 500' shallower than the prediction at Meltwater #6. This is due to the reference point of the seismic was not at Mean Sea Level but 500' above MSL. There is no apparent shallow hazard at this location. Conclusions: 1. There are no apparent shallow hazards for Meltwater #1, #2, ~1, #6R and #6. 2) The seismic reference point is 500' above Mean Sea Level. This caused the seismic plots in depth to be 500' too shallow. 3) There is good agreement between the know Leak Off Tests and the calculated fracture gradient. 4) The slope and intercept for the Normal Compaction Trend Line from the Alpine and Tarn study is the same as this Meltwater study. If there are any further questions, please call me at the above number. Ray Wydrinski ARCO Exploration and Production Technology Pore Pressure and Fracture Gradient Pre-drill 12/23/98 Ray Wydrinski Scale: Vertical 1' = 1753 ft, Horizontal 1 in = 88 cdp Project: Meltwater Cross Section: 115336 Depths Updated 1/13/2000 MSL Base Permafrost 1000.( Meltwater North #1 0 5000' I Scale :'..'i :.. ~1'::: :' ::.'t.'...:' ..' :.-J 1 O, 000' I D E P T H (ft) 8000 9000 00011301A00 MSL T I M E (ms) ARCO Exploration and Production Technology Pore Pressure and Fracture Gradient Pre-drill .. 12/21/98 Ray Wydrinski .Scale .'..Vertical 1' = 614 msec, Horizontal .1 in-= 87.cdp Depths Updated 1/13/2000 Meltwater North ttl t11! 1 0000 0 O0 0 0000 O0 000 0 0000 0 0 000 11 I I t 22 2 2222 2.3 3 33 3 3'344 4 4 444 34 56 8 0 1 2 4567 90 234 6 8.9 0 I 2 4 6'78 I 1 I1 000 555 012 0tt Project: Meltwater Cross Section: IL5336 0 5000' 1:0,000' I I I 1 11 It It I ti I I 0 O0 O0 O0 000 0 0 5 55 5::5 - 66' 6 66 6 7 4 67 89 12 4 56 . 8 0 Scale I I 1 11 0 0000 0 7'7777 7 2' 4567 9 , PPg 8.00 8.50 9.50 ;10.~0 :11.00 II.50 '12.00 12.50 13.00 13.30 I4,00 14.50 15.00 15.50 t6.00 -- 16.50 17.00 17.50 18.00 I8.50 19.00 3400 00011301 BOO ARCO Exploration and Production Technology Pore Pressure and Fracture Gradient Pre-drill 12/24/98 Ray Wydrinski Project: Meltwater Well Meltwater North #1 NCTL:: 165_45S Well Name Updated 1/13/2000 DF_.,PT~ (Datum set to ~KB, 530 fi above MSL) 3O FEET NCTL Intercept at GL = 165 Logarithmic Slope = -4..%q75 120 140 ~, Cmng Depth + Rq)cat Formmion Test '" Stuck Pil~ Lotion X Freeform Kiok/Flow Drill Stem Test Lcak~ff Test Formation Top 9 J0 l t 12 13 14 15 16 17 PPG 165_-4 5SPLE,_PPG 65_45WC_~ (Sonic NCTL: 165_458, Poissoa Model: W'~I'_CAMERON) 1000 19 20 00011301 CO0 ARCO Alaska, Inc. Doyon 141 Diverter Schematic Flowline 21%" 2,000 psi WP DRILLING SPOOL wi 16" Outlet 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 14'1 13-518" 5,000 PSI BOP COMPONENTS L~ I 3" 5,000 psi WP OCT MANUAL GATE VALVE~ [__l KILL LINE WP Shaffer GATE VALVE L_~ 3" 5,000 psi w/hydraulic actuator / DSA 13-5/8" 5,000 psi WP x 11" 5,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE w/hydraulic actuator ~-~ CHOKE LINE ~ ~ 3" 5,.0.0.0. psi WP OCT [_a ~ MANUAL GATE VALVE 13-5/8" 5,000 psi WP DRILLING SPOOL ~ wi two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP wi pipe rams ARCO..AMS~ka,/nc. {~ 'P:.O. Box.:-:t~02776 An:c:bo[.age~ AK 995 t 0.-2 776 PAY' TO THE ORDER OF; STATE OF ALASKA ALASKA OIL & GAS..CONSERYATION COMMI:' ::.-.30:01' PORCUPINE. DRi~/E c,-,,o, .,,,,.,,v,,,,,~ 2.0'509319~8 JANUARY '21, 200:0 **.* VOID: AFTER '90 DAYS 73-426 839 0997579 EXACTLY' **:******.***100. DOLLARS AND 'O0 CENTS $***********100.00 The First National Bank of Chicago-0710 Chicago, Illinois Pa'/able Through Republic Bank Shelbyville, Kentucky .. TRACE NUMBER: 205093198 0 q:~i- ? 5. ?.:el,' WELL PERMIT CHECKLISTf COMPANY "/~/~(L.~ "/ ' " , WELL NAME/~Z~'~TT~~PROGRAM: exp V/ dev~ FIELD & POOL ~ ~. INIT C~SS ~!: !~ ~C~//~ GEOL AR~ ~: ADMINIS I RATION 1. Permit Joe a~ached ....................... DATE EN~INEERIN~ (~ DATE r r · ~ GEOLOGY DATE ANNULAR DISPOSAL APPR DATE redrll ~ serv ~ wellbore seg · UNIT# ...... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............ 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ann. disposal para req ON/OFF SHORE (""~/..-/. ~N N (~N N N 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to 2.~) ~(~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable. ................ Y...._(~ ~,~ ~,-,o.~ ~,c~N~.t,,.~.?..~'-, '~ ~,~ ~.~,"~-,\~. ~P..~%~'~% ~%,~,.~3<~<_~ '~J ~..~,.~,~>. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y 31. Data presented on potential overPressure zone~. ...... Y 32. Seismic analysis of shallow gas zones~(. ........... Y I~~,'"~o 33. Seabed cond~bon survey 0f off-shore) ............ ,~, · .,,Y,.. N ~ ~"~'?-~; ,,~-~z-~//.<",(~,~, r,-~.~ /,~-/,~./-~//--,4 ~.~'_~, ' .~.z./..~,~cg.., 34. Contact name/phone for weekly progress reports [exploratory only] fY With ....... ~ ,¢j/~ z~,~d'~ .~_~ ';Z..-C,~.-,D~: (_.)/Y'i~_./?~./~r4~"'/"/~ ~u/~/~r'lce., o'.~' · J 35. proper cemen[ing recoras, tnls plan ,~..Z~r~~/~4'~_7,-~ ,..~.._.-. ~ /~,,-,.-~..,.~ ~.,.,~. '~,~-<..~ ~__c_~,..~_~r- ~¢"-\'-'-' .............. ' i+ r--~...o ~u~-3~-c~,',.,' (A) will contain waste in a suitable receiving zone; ....... Y N . 2 Q.,~ ~.1~ ~'. - (B) wdl not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: RPC( ENGINEERING: UIC/Annular BE, ,W~ ~/¢, [~L/VM I~/~ ~"J J~,~' JDH ~_~~ ~ ' ' TEM~/~ COMMISSION: ~r-~ DWJ Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 09~27~99)